The URL can be used to link to this page

Home My WebLink About218-158Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# IRU 41-01 50283200880000 192109 9/17/2023 HALLIBURTON Coilflag KBU 32-06 50133206580000 216137 9/8/2023 HALLIBURTON PPROF LRU C-02 50283201900000 223057 9/13/2023 HALLIBURTON RBT MPU E-37 50029236160000 218158 9/24/2023 READ Caliper Survey MPU F-53A 50029225780100 213136 9/27/2023 READ Caliper Survey MPU F-79 50029228130000 197180 9/26/2023 READ Caliper Survey MPU L-57 50029236090000 218072 9/26/2023 READ Caliper Survey MPU S-06 50029231630000 203109 9/29/2023 READ Caliper Survey MPU B-32 50029235700000 216151 9/12/2023 HALLIBURTON Perf TBU K-09 50733201100000 1068038 10/1/2023 READ Caliper Survey Please include current contact information if different from above. T38028 T38029 T38030 T38031 T38032 T38033 T38034 T38035 T38036 T38037 10/4/2023 MPU E-37 50029236160000 218158 9/24/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.04 13:03:04 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Jet Pump 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,944'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Pre Drill 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng BOT SLZXP LTP and N/A 7,899 MD/ 4,400 TVD and N/A Taylor Wellman twellman@hilcorp.com 777-8449 Perforation Depth MD (ft): 13,942' See Schematic See Schematic 2-+7/8" 107' 20" 9-5/8" 7-5/8" 8,056' 6-5/8"6,043' 7,896' MD N/A 6,090psi 5,750psi 6,890psi 4,403' 4,403' 4,363' 8,056' 7,896' Length Size Proposed Pools: 107' 107' 6.5# / L-80 / EUE 8rd TVD Burst 7,758' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518, ADL0047437 218-158 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23616-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/5/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT E-37 MILNE POINT SCHRADER BLUFF OIL N/A 4,364' 13,937' 4,364' 1,247 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Operations Manager By Grace Christianson at 11:28 am, Sep 22, 2023 323-525 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2023.09.19 15:15:46 - 08'00' David Haakinson (3533) Convert to Jet Pump DSR-9/25/23MGR25SEP23 10-404* BOPE pressure test to 2500 psi. Annular to 2500 psi. * Approved for reverse circulation jet pump * IA SSV high pressure trip pressure not to exceed 10% of maximum steady state power fluid injection pressure. * IA SSV low pressure trip pressure not to be lower than 50% of maximum steady state power fluid injection pressure. * Production tubing SSV low pressure trip not to be lower than 100 psi. * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. * Biennial MIT-IA to maximum power fluid injection pressure. SFD 9/22/2023*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.28 09:34:17 -08'00'09/28/23 RBDMS JSB 092823 Well: MPU E-37 PTD: 218-158 API: 50-029-23616-00-00 Well Name:MPU E-37 API Number:50-029-23616-00-00 Current Status:SI Producer – Dead ESP Rig:ASR Estimated Start Date:10/05/2023 Estimated Duration:10 days Regulatory Contact:Tom Fouts Permit to Drill Number:218-158 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Current Bottom Hole Pressure: 1,677 psi @ 4,299’ TVD MPU E-38 DH Gauge (offset Schrader) |7.50 PPGE Max Proposed Surface Pressure: 1,247 psi Gas Column Gradient (0.1 psi/ft) Reaches 70deg:6,575’ MD Max Dogleg:8.13° @ 6,469’ MD Brief Well Summary: MPU E-37 was drilled as a Schrader OA lateral completed with pre-drilled liner and an ESP upper completion in January 2019. The well has been a steady producer since this time. In April 2023 the water source well on E Pad failed and E-37 has been without injection polymer support for ~5 months. The GOR increased on E-37 and the ESP failed. Another well has recently been converted to a water supply well and polymer injection has resumed to support E-37. Objectives: Pull failed ESP completion / Test 7-5/8” casing to 3,600psi / Run 4-1/2” jet pump completion Notes Regarding Wellbore Condition: Last 7-5/8”x9-5/8” casing test was 1,662 psi on 9/16/2023. Pre-Rig Procedure (Non-sundried steps) Slickline & Pumping 1. MIT-OA to 1,500 psi. 2. MIRU SL unit and pressure test PCE to 250 / 1,500 psi. 3. Run SBHP survey to confirm BHP. 4. Pull / set DGLV at 128’ MD. 5. Pull DGLV from 6,372’ MD. Pumping & Well Support 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 9. Pressure test lines to 3,000 psi. 10. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 11. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 12. RD Little Red Services and reverse out skid. Well: MPU E-37 PTD: 218-158 API: 50-029-23616-00-00 13. Set BPV. ND tree. Brief RWO Procedure (Approved Sundry Required) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. NU BOPE. 4. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 6. Call out Centrilift for ESP pull. 7. RU spoolers to handle ESP cable, and dual 3/8” capillary string. a. Use extreme care in spooling the capillary string to promote reuse of the string. 8. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Expected PU ~45kips – 2019 Innovation recorded 80kips PU (including 35kips blocks) prior to landing hanger and SOF = 52kips. 9. Confirm hanger free, lay down tubing hanger. 10. POOH and lay down the 2-7/8” tubing. Number all joints. a. Contact OE for caliper results and determination of joints to be kept for re-use vs. scrapping. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Look for over-torqued connections from previous tubing runs. e. Recover the following amount of clamps from the completion: i. Cross Collar Clamps: 262 ii. Motor Clamps: 3 iii. Seal Clamps: 2 iv. Pump Clamps: 8 11. Lay Down ESP. 12. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 13. PU 3-1/2” workstring, 7-5/8” casing scraper, and muleshoe. RIH to 7,910’ MD. a. Scrape casing interval from 6,380’ to 6,480’ MD. Planned packer set depth is 6,420’ MD. Well: MPU E-37 PTD: 218-158 API: 50-029-23616-00-00 14. POOH while filling hole with 2x pipe displacement. 15. PU and RIH w/ 7-5/8” test packer to ±6,450’ and pressure test to 3,600psi. 16. RIH with 4.5” JP completion to 7,910’ and obtain string weights. a. Note PU and SO weights on tally Nom. Size ~Length Item Lb/ft Material Notes 4-1/2”41 4-1/2" WLEG – Beveled Mule Shoe 12.6 L-80 ±7,910’ MD Stung into liner 4-1/2” 41 4-1/2" TXP 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 3.725” XN Nipple (RHC Plug Installed)12.6 L-80 ±6,460’ 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”7 Hydraulic Set Packer 7" x 4-1/2"L-80 ±6,400’ 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 Baker Zenith Gauge Carrier L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 3.813” X Nipple 12.6 L-80 No plug 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”5 4-1/2" Sliding Sleeve - 3.813” X L-80 Blanked Port 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 4-1/2" TXP Joints 12.6 L-80 4-1/2” Hanger Pup 12.6 L-80 4-1/2” Tubing Hanger 12.6 L-80 b. Clamp I-wire every other joint 17. Space out and make up tubing hanger. Terminate I-wire cap string to hanger. Test I-wire. RILDS. 18. Pump 5 barrels 1% KCL with corrosion inhibitor down the annulus, followed by 100 barrels KCL, and 65 barrels of freeze protect fluid taking returns up the tubing. a. This is to protect the area between the packer and sliding sleeve from corrosion. b. Coordinate with Wells Foreman if the IA freeze protect is needed with the expected time to bring well online. Well: MPU E-37 PTD: 218-158 API: 50-029-23616-00-00 19. Drop ball & rod, and load tubing with FP while pumping ball and rod down to seat. Take returns to formation. Pressure up and set packer per vendor instructions. 20. Perform 30 minute charted MIT-T to 3,000 psi. 21. Perform 30 minute charted MIT-IA to 3,650 psi. 22. Set BPV. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline 1. RU SL and test PCE to 3,000 psi. 2. RIH and Retrieve Ball and Rod and RHC Plug. 3. Open sliding sleeve. 4. RIH W/ 9B Jet Pump and set. 5. RD SL Unit. 6. Turn Well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Edited By: CJD 2/26/2019 SCHEMATIC Milne Point Unit Well: MPU E-37 Last Completed: 2/1/19 PTD: 218-158 TD =13,944’ (MD) / TD =4,364’(TVD) 20” Orig. KB Elev.: 26.7’(Innovation) 7-5/8” 3 7 8 & 9 10 13 11 12 9-5/8” 1 2 Dual 3/8” SS Capstring PBTD = 13,937’(MD) / PBTD =4,364’(TVD) 5& 6 4 ES Cementer @ 2,433’ MD Min ID= 2.205” @ ±5,350’ 14 16, 17 & 18 15 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor - / X-52 / Welded N/A Surface 107' 9-5/8" Surface 40 / L-80 / TXP 8.835 Surface 8,056’ 7-5/8" Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 7,896’ 6-5/8” PreDrilled Liner 20 / L-80 / Hyd 563 6.049 7,899’ 13,942’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,758’ 3/8” Dual Capstring SS N/A Surface 7,758’ JEWELRY DETAIL No Depth Item 1 128’Sta #2:GLM- 1” Side Pocket KBMM w/ Orifice 2 6,372’Sta #1: GLM- 1” w/ Dummy 3 6,450’ 2-7/8” XN-Nipple (2.205 No-go ID) 4 7,668’ Discharge Head: FPDIS 5 7,670’ Upper Tandem Pump: 134 STG FLEX 17.5 6 7,693’ Lower Tandem Pump: 134 STG FLEX 17.5 7 7,717’ Gas Separator: GRS FER N AR 8 7,722’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 7,729’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 7,736’ Motor: CL5 XP – 250hp / 2505V / 61A 11 7,753’ Sensor, Zenith S/N ZTB5876W 12 7,756’ Centralizer 13 7,899’ BOT SLZXP Liner Top Pkr w/BD Slips, 7" x 9 5/8" 14 7,921’ Crossover Sub, 7" H563 x 6.625" Hyd 563 15 13,901’ Crossover Sub, 6.625” Hyd 563 x 4.5” 16 13,906’ 4-1/2” Drillable Packoff Sub 17 13,937’ WIV Valve with 1” Ball on Seat 18 13,940’ Round Nose Float Shoe: WELL INCLINATION DETAIL KOP @ 102’ Max Hole Angle = 95.7 deg. @ 10,728’ GENERAL WELL INFO API: 50-029-23616-00-00 Drilled, Cased and Completed by Innovation - 2/1/19 TREE & WELLHEAD Tree 5K Cameron 2-9/16” Wellhead FMC Gen 5 CEMENT DETAIL 20” ~270 ft3 5.5 sx dumped down backside 9-5/8"Stg 1 L – 763 sx, T – 398 sx Stg 2 L – 400 sx, T – 289 sx 6-5/8” Predrilled Liner Detail 6-5/8” Predrilled Liner, 78 holes/foot, 3/8” holes, 1x 6.625”x7.75” free floating cent/jnt _____________________________________________________________________________________ Edited By: TTW 9/14/2023 PROPOSED Milne Point Unit Well: MPU E-37 Last Completed: 2/1/19 PTD: 218-158 TD = 13,944’ (MD) / TD =4,364’(TVD) 20” Orig. KB Elev.: 26.7’(Innovation) 7-5/8” 3 6 12 9-5/8” 1 2 PBTD =13,937’(MD) /PBTD =4,364’(TVD) 5 4 ES Cementer @ 2,433’ MD Min ID= 2.205” @ ±5,350’ 7 9, 10 &11 8 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor - / X-52 / Welded N/A Surface 107' 9-5/8" Surface 40 / L-80 / TXP 8.835 Surface 8,056’ 7-5/8" Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 7,896’ 6-5/8” PreDrilled Liner 20 / L-80 / Hyd 563 6.049 7,899’ 13,942’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 7,910’ JEWELRY DETAIL No Depth Item 1 ±X,XXX’ Sliding Sleeve 2 ±X,XXX’ DH Gauge Mandrel 3 ±X,XXX’ 4-1/2” x 7-5/8” Packer 4 ±X,XXX’ X Nipple (Min ID = 3.813) 5 ±X,XXX’ WLEG 6 7,899’ BOT SLZXP Liner Top Pkr w/BD Slips, 7" x 9 5/8" 7 7,921’ Crossover Sub, 7" H563 x 6.625" Hyd 563 8 13,901’ Crossover Sub, 6.625” Hyd 563 x 4.5” 9 13,906’ 4-1/2” Drillable Packoff Sub 10 13,937’ WIV Valve with 1” Ball on Seat 11 13,940’ Round Nose Float Shoe: WELL INCLINATION DETAIL KOP @ 102’ Max Hole Angle = 95.7 deg. @ 10,728’ GENERAL WELL INFO API: 50-029-23616-00-00 Drilled, Cased and Completed by Innovation - 2/1/19 TREE & WELLHEAD Tree 5K Cameron 2-9/16” Wellhead FMC Gen 5 CEMENT DETAIL 20” ~270 ft3 5.5 sx dumped down backside 9-5/8"Stg 1 L – 763 sx, T – 398 sx Stg 2 L – 400 sx, T – 289 sx 6-5/8” Predrilled Liner Detail 6-5/8” Predrilled Liner, 78 holes/foot, 3/8” holes, 1x 6.625”x7.75” free floating cent/jnt Well: MPU E-37 PTD: 218-158 API: 50-029-23616-00-00 BOPE Schematic DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2181580 Well Name/No. MILNE PT UNIT E-37 I U 1 o Operator HILCORP ALASKA LLC MD 13944 TVD 4364 Completion Date 2/1/2019 Completion Status 1 -OIL Current Status 1 -OIL API No. 50-029-23616-00-00 UIC No REQUIRED INFORMATION / / Mud Log No 1 Samples No ✓ Directional Survey Yes ✓� DATAINFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MD, ABG/DGR/EWE/ADR 2"/5" TVD (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30518 Digital Data 100 13944 3/28/2019 Electronic Data Set, Filename: MPU E-37 DGR ABG EWR ADR.Ias ED C 30518 Digital Data 8045 13906 3/28/2019 Electronic Data Set, Filename: MPU E-37 ADR Quadrants All Curves.las ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD MD Final.cgm ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD TVD Final.cgm ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37—Definitive Survey Report.pdf ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37_Definitive survey report.txt ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD MD Final.emf ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD TVD Final.emf ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 Geosteering.dlis ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 Geosteering.ver ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD MO Final.pdf ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD TVD Final.pdf ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD MD Final.tif ED C 30518 Digital Data 3/28/2019 Electronic File: MPU E-37 LWD TVD Final.tif ED C 30518 Digital Data 3/28/2019 Electronic File: EMFView3_1.zip ED C 30518 Digital Data 3/28/2019 Electronic File: Readme.txt Log C 30518 Log Header Scans 0 0 2181580 MILNE PT UNIT E-37 LOG HEADERS Log C 30519 Log Header Scans 0 0 2181580 MILNE PT UNIT E-37 PB1 LOG HEADERS AOGCC Pagel of3 Monday, May l3, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2161 580 Well Name/No. MILNE PT UNIT E-37 Operator HILCORP ALASKA LLC MD 13944 TVD 4364 Completion Date 2/1/2019 ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data ED C 30519 Digital Data Well Cores/Samples Information: Interval Name Start Stop INFORMATION RECEIVED Completion Status 1-011- 100 -OIL 100 11052 8045 11014 API No. 50-029-23616-00-00 Current Status 1-0I1- UIC No 3/28/2019 Electronic Data Set, Filename: MPU E-37 P61 DGR ABG EWR ADR.Ias 3/28/2019 Electronic Data Set, Filename: MPU E-37 PB1 ADR Quadrants All Curves.las 3/28/2019 Electronic File: MPU E-37 PB1 LWD MD Final.cgm 3/28/2019 Electronic File: MPU E-37 PB1 LWD TVD Final.cgm 3/28/2019 Electronic File: MPU E-37PB1_Definitive Survey Report.pdf 3/28/2019 Electronic File: MPU E-37PB1_Definitive survey report.txt 3/28/2019 Electronic File: MPU E-37 P81 LWD MD Final.emf 3/28/2019 Electronic File: MPU E-37 P81 LWD TVD Final.emf 328/2019 Electronic File: MPU E-37 PB1 Geosteedng.dlis 3/28/2019 Electronic File: MPU E-37 PBt Geosteering.ver 3/28/2019 Electronic File: MPU E-37 PBt LWD MD Final.pdf 328/2019 Electronic File: MPU E-37 PBt LWD TVD Final.pdf 3/28/2019 Electronic File: MPU E-37 PB1 LWD MD Final.tif 3/28/2019 Electronic File: MPU E-37 PBI LWD TVD Final.tif 3/28/2019 Electronic File: EMFView3_1.zip 3/28/2019 Electronic File: Readme.txt Sample Set Sent Received Number Comments AOGCC Page 2 of 3 Monday, May 13, 2019 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2019 Permit to Drill 2181580 Well Name/No. MILNE PT UNIT E-37 MD 13944 TVD 4364 Completion Report O Production Test Informatior(D NA Geologic Markersrrops oY COMPLIANCE HISTORY Completion Date: 2/1/2019 Release Date: 12/6/2018 Description Comments: Compliance Reviewed By: Operator HILCORP ALASKA LLC API No. 50-029-23616-00-00 Completion Date 2/1/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No Directional / Inclination Data O Mud Logs, Image Files, Digital Data Y /9 Core Chips Y / Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files); Core Photographs Y / v Daily Operations SummaryY Cuttings Samples Y(/ NA Laboratory Analyses Y / Date Comments Date: AOGCC Page 3 of 3 Monday, May 13, 2019 DATE: 3/26/2019 218158 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 30 5 18 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-37 PTD 218-158 MPU E-37 PB1 ROP DGR ABG EWR ADR MD & TVD CD: HALLIBURTON 03 FEB 2019 _Log Viewers 3/26/2019 9:52 AM CGM 3/26/2019 9:52 AM Definitive Survey 3/26/2019 9:53 AM EMF 3/26/2019 9:53 AM LAS 3/26/2019 9:53 AM PDF 3/26/2019 453 AM TIFF 3/26/2019 9:53 AM RECEIVED MAR 2 8 2019 AOGCC File folder File folder File folder File folder File folder File folder File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: 1\\ \ ✓ Yi /) 1,p I Date: DATE: 3/26/2019 218158 Debra Oudean Hilcorp Alaska, LLC 30 5 19 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU E-37 PTD 218-158 MPU E-37 PB1 ROP DGR ABG EWR ADR MD & TVD CD: HALLIBURTON 03 FEB 2019 Log Viewers CGM Definitive Survey EMF LAS PDF TIFF 3126/2019 9:52 AM 3/26/2019 9:52 AM 3/2612019 9:53 AM 3/26/2019 9:53 AM 3,/2612019 9:53 AM 26/2019 9:53 AM 3/26.,12019 9:53 AM RECEIVED MAR 2 8 2019 AOGCC File folder Fife folder File fol der Fife folder Filefolder File folder File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 STATE OF ALASKA ( MAR 0 1 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A 1a. Well Status: Oil ❑✓ Gas F] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: _ 1 tb. Well Class: Development El Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 2/1/2019 14. Permit to Drill Number / Sundry: 218-158 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: January 2, 2019 15. API Number: 50-029-23616-00-00 4a. Location of Well (Governmental Section): Surface: 3641' FSL, 1757' FEL, Sec 25, T1 3N, R1 OE, UM, AK Top of Productive Interval: 2121' FNL, 2444' FEL, Sec 24, T13N, R10E, UM, AK Total Depth: 394' FSL, 2506' FEL, Sec 14, T13N, R10E, UM, AK • 8. Date TD Reached: January 23, 2019 16. Well Name and Number: MPU E-37 9. Ref Elevations: KB: 48.5 GL: 21.7' BF: 21.7' ' � 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool 10. Plug Back Depth MD/TVD: 13,937' MD / 4,364' TVD 18. Property Designation: ADL025518 / ADL047437 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569388 ' y- 6016180 Zone- 4 TPI: x- 568655 y- 6020970 Zone- 4 Total Depth: x- 563290 y- 6023438 Zone- 4 11. Total Depth MD/TVD: , X3,944' MD / 4,364' TVD 19. DNR Approval Number: LONS 94-017 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: ' 2,240' MD / 1,814' TVD " 5. Directional or Inclination Survey: Yes v (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/ VD: 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 275" MD / PBi-'� ABG/DGR/EWR/ADR 2"/5" TVD / PB1 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM HOLE SIZE 20" - X-52 Surface 107' Surface 107' 42" —270ff3 9-5/8" 40# L-80 Surface 8,056' Surface 4,403' 12-1/4" Stg 1 L - 763 sx / T - 398 sx Stg 2 L - 400 sx / T - 289 sx 240 bbls 7-5/8" 29.7# L-80 Surface 7,896' Surface 4,403' Tieback Tieback Assy. 6-5/8" 20# L-80 7,899' 13,942' 4,403' 4,363' 8-1/2" Cementless PreDrilled 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): 7,966'- 13,901' MD 14,403' - 4,364' TVD 6-5/8" Predrilled Liner, 78 holes/foot, 3/8" holes, Installed on 1/27/19 COMPLETION Z / /E O(y 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-7/8" 7,758' LTP 7,899'/ 4,403' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 2/6/2019 Method of Operation (Flowing, gas lift, etc.): ESP Date of Test: 2/20/2019 Hours Tested: 24 Production for Test Period Oil -Bbl: 245 Gas -MCF: 534 Water -Bbl: 8.2 Choke Size: N/A Gas -Oil Ratio: 2179 Flow Tubing Press. 234 Casing Press: 440 Calculated 24 -Hour Rate 0� Oil -Bbl: 245 Gas -MCF: 534 Water -Bbl: 8.2 Oil Gravity - API (corr): 17.6 Form 10-407 Revised 5/2017 CONTINUE ON PAGE 2 Submit ORIGINAL on ,, Y i b' "ry �y y%jry RMSIL MAR 0 61019 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, Fromffo), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top , Permafrost - Base 2,240' 1,814' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7,966' SB OA 4,403' information, including reports, per 20 AAC 25.071. SV5 2,069' 1,712' SV1 3,440' 2,497' Ugnu LA3 5,741' 3,824' SB NA 7,242' 4,332' SB OA 7,842' 4,394' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Survey, Csg and Cmt Report. 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: Cdift of hilcor .Com Authorized Contact Phone: 777-8389 p re: Signatu'- Date: 2, z O ' Cl INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 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 512017 Submit ORIGINAL Only K IGlcoru Alaska, UC Urig. KB Elev.: 26.7(Innovation) TD=13,944' (MD) / TD = 4,364'(TVD) PBTD=13,937(MD) / PBTD= 4,364! (TVD) SCHEMATIC Milne Point Unit Well: MPU E-37 Last Completed: 2/1/19 PTD: 218-158 TREE & WELLHEAD Tree 5K Cameron 2-9/16- li Wellhead FMC Gen5 CEMENT DETAIL 20" -270 ft35.5 sx dumped down backside Wt/Grade/Conn Stg 1 L-763 sx, T-398 sx Top Stg2 L-400 sx, T-289 sx 9-5/8" Conductor -/X-52/Welded N/A CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor -/X-52/Welded N/A Surface 107' 9-5/8" Surface 40/L-80/TXP 8.835 Surface 8,056' 7-5/8" Tieback 29.7/L-80/Hyd 521 6.875 Surface 7,896' 6-5/8" PreDrilled Liner 20/L-80/Hyd 563 6.049 7,899' 13,942' TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 7,758' 3/8" Dual Capstring SS N/A Surface 7,758' WELL INCLINATION DETAIL KOP @ 102' Max Hole Angle = 95.7 deg. @ 10,728' JEWELRY DETAIL No Depth Item 1 128' Sta #2: GLM -1" Side Pocket KBMM w/ Orifice 2 6,372' Sta #1: GLM -1" w/ Dummy 3 6,450' 2-7/8" XN-Nipple (2.205 No-go )D) 4 7,668' Discharge Head: FPDIS 5 7,670' Upper Tandem Pump: 134 STG FLEX 17.5 6 7,693' Lower Tandem Pump: 134 STG FLEX 17.5 7 7,717' Gas Separator: GRS FER N AR 8 7,722' Upper Tandem Seal: GSB3DBUTSB/SB PFSA 9 7,729' Lower Tandem Seal: G5133DBUT SB/SB PFSA 30 7,736' Motor: CLS XP- 250hp / 2505V / 61A 11 7,753' Sensor, Zenith S/N ZT85876W 12 7,756' Centralizer 13 7,899' BOT SLZXP Liner Top Pkr w/BD Slips, 7" x 9 5/8" 14 7,921' Crossover Sub, 7" H563 x 6.625" Hyd 563 15 13,901' Crossover Sub, 6.625" Hyd 563 x 4.5" 16 13,906' 4-1/2" Drillable Packoff Sub 17 13,937' W IV Valve with 1" Ball on Seat 18 13,940' Round Nose Float Shoe: GENERAL WELL INFO API: 50-029-23616-00-00 Drilled, Cased and Completed by Innovation - 2/1/19 6-5/8" Predrilled Liner Detail 6-5/8" Predrilled Liner, 78 boles/foot, 3/8" holes, Ix 6.625'x7.75" free floating cent/int Edited By: CID 2/26/2019 Hilcorp Energy Company Composite Report Well Name: MP E-37 Field: Milne Point County/State: ,Alaska i (LAT/LONG): evation (RKB): API #: Spud Date: 1/3/2019 Job Name: 1813044D MPE-37 Drilling Contractor AFE #: AFE $: as itj Date Ops Summary 12/30/2018 PJSM Roads and Pads prep E-37. RIO and Crane off Top Drive radiator and Glycol Tank from Sub roof. Stage in welding shop. Check cross head clearance on MP #1 and #2. Clean out MP #2 suction manifold. Pull and C/O discharge seats and valves on MP #2.;Weld mounting hardware for exhaust fan and duct work in Pits. Install duct work. Set liner and Rig Matta for E-37. Stage Well Head and completion Equip behind E-37. Install Starter Head and Diverter Tee. Attemptto walk Sub off E-35. Not enough clearance with new Tree.;Install now, hitch to Sub, raise Sub W/tires. Remove one side Tie Rod. Pull Sub over Tree W/ Cat. Set down and install Tie Rod, Walk Sub from E-35 to E-37.;PJSM Cont. to walk Sub from E-35 to E-37. Spot Sub over E-37. Start spotting Catwalk Sub.;Hauled 0 bbls Fluid to MP G&I total = 0 bbls Hauled 0 bbls fluid to B-50 total = 0 bbls Hauled 0 bbls H2O from L -Pad Lake total = 0 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls 12/31/2018 Re- Spot Cat Walk. Spot Pipe Shed, Pump Mod and Gen Mod. Assemble Interconnects.;Remove Gen Jeep. Set down Gen Mod. R/U Steam, water and air. Roll steam through rig . R/U Mez Mud Lines at interconnects. Plug in lines to Plug Board. Swap from cold start to Gen Power. Spot and R/U Enviro Vac and Break Room. Work on rig acceptance check list. Rig on high line power at 16:30.;Set Sub out riggers. R/D and move Co Rep/ Tool Pusher office. Spot and berm Cutting Box. Roll water and air through rig. PJSM Prep Derrick and scope up Derrick. R/U weight buckets and Geronimo Line. Perform full Derrick inspection and bridle down. Thaw out suction sumps as needed.;Spot Surface BHA in Pipe Shed. Circ. hot water through lines in Pits. Two 290 bbl Vac Trucks on location with 8.8 ppg Spud Mud. Geology, MWD, DD and Geo Steering on Iocabon.;Work on rig acceptance check list. Cont. thawing out suction sumps in Pits. Cont. loading surface BHA in Pipe Shed, Roll hot water through Mud Pumps. Dress Shakers. PJSM Crane Radiator and Tank to top of Sub. Set Divertor Stack on Tee. Install Knife Valve. String new line for Man Rider.;Rig Accepted @ 06:00 hrs.;Hauled 0 bbls Fluid to MP G&I total = 0 bbls Hauled 0 bbls fluid to BSO total = 0 bbls Hauled 0 bbls H2O from L -Pad Lake total = 0 bbls Hauled 0 bbls H2O from Lake 2: 0 bible Lost 0 bbls to formation total fluid lost = 0 bbls 1/1/2019 Ria accepted at 06:00. Cont. installing Knife Valve. Assemble Diverter line. Flush and fill Glycol system for Top Drive. Clean cellar area. C/O Saver Sub and replace Die Blocks. Work on PM'S.;Cont. Prep and install Diverter line. Take on 290 this 8.7 ppg Spud Mud to Pits. Fix and install Grabber die plates to Die Block. Open Centrifuge coffins and inspect. Install speed sleeve and C/O seals on Glycol pump for Top Drive. R/U and flush Glycol through Top Drive.;PJSM M/U Saver Sub to Top Drive TRQ 48K, install torque ring and safety wire bobs. Press. up Koomey and check for leaks. Install 4" Ball Valves on Conductor. Hang and R/U Tongs. Install riser on Stack. Function test Centrifuges. Service and grease Top Drive, Blocks and Spinners.;Calibmte Drum/ Blocks position sensor. Top off Glycol for Top Drive. Clean and clear rig floor.;Function test Top Drive. Perform Top Drive operating limits. Calibrate Blocks.;PJSM. Test Diverter/annular system. Witness waived by AOGCC Rep Brian Bixby 1-1-19 06:25. Knife open 4 sec, bag close 10 sec. Initial System pressure 2,900 PSI, final charge 1,950 PSI, 200 PSI charge 17 Sec, full charge 57 sec. 6 bottles Nitrogen average 2,308 PSI average.;Test PVT and flow paddle. Total length diverter = 177', closest Ignition 801. Press. test surface lines to 3,500 PSI.;PJSM with all personnel for picking up 5" D.P. Check Crown Saver. PIU M/U 5" D.P. 19.5# NC -50 5-135 from Pipe Shed and rack back in Derrick. P/U M/U 28 stands in Derrick.;Hauled 0 bbls Fluid to MP G&I total = 0 bbls Hauled 0 bbls fluid to B-50 total = 0 bbls Hauled 130 bbis H2O from L -Pad Lake total = 780 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 0 bbls to formation total fluid lost = 0 bbls 1,12/2019 Continue P/U and rack back 5" dp. Drift = 2.83". Rack back a total of 44 stds 5", NC50, 19.5#, 5-135.;Unable to make tongs bit on dp. C/O dies with no change. Decision made to C/O tongs to 3' DD. C/O weight buckets for tongs. Inspect and repair positional switch on elevators. Function test elevators (test l good).;Continue PA1 M/U 5" DP from shed. P/U and rack back a total of 114 stds of 5", NC50, 19.5#, 5-135.;CIO Cobra Head pig tails and Lock -O -Loy on driller Y and off driller side.;Continue P/U remaining 5" DP from shed. PIU and rack back a total of 124 stds of 5", NC50, 19.5#, 5-135. PJSM Lay out and process HWDP. P/U M/U 5" NC -50 HWDP from Pipe Shed racking back in Derrick total 3 stands.;PJSM P/U MN 5" NC -50 HWDP from Pipe Shed racking back in Derrick total 9 stands W/ Jars.;Service Top Drive and grease Crown.;PJSM for picking up BHA with all personnel. P/U M/U 12.25" Hughes Hybrid Bit, 31.91'8" SperryDrill 1.5° Motor, 3.11' 8" X/O and 1 stand 5" HW DP.;Tag up at 45' MD. Start cleaning out 20" Conductor with water 425 GPM, 390 PSI, 26 RPM, TRQ, 1,400, WOB 1-2K to 107' MO. Start drilling to 130' MD and displace water W/ 8.7 ppg Spud Mud. Pull back into Conductor and work the flow line due to gravel.;Cont. jetting and air flow line. Also use bleeder to maintain flow down flow line. Cont drill no ahead 12 114" hole F/ 130'to 188' MD 325 GPM, 330 PSI, 44 RPM, TRQ 1,400 f ilb, WOB 1-2K.. Bit Firs.33. P/U 45K, SLK 44K, ROT 46K.;Hauled 57 bbls Fluid to MP G&I total = 57 bbls Hauled 0 bbls fluid to 8-50 total = 0 bbls Hauled 130 bbls H2O from L -Pad Lake total = 910 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 0 blots to formation total fluid lost = 0 bbls 1/3/2019 Drill 12.25" rat hole w/ dumb iron F/ 188'- T/ 220' MD. 300 gpm, 380 psi, 60% flow, 25-40 rpm, 1.3k tq, .5-1k WOB. CBU. Heavy gravel to 150'then transitioned to more sandy material w/ smaller gravel. Jet towline between connections @ 10-12 BPM. B/D TDS.;POOH F/ 220'- T/ surface. Pulled 40k over @ 135MD. Work past with minimum pumps and rot. Saw no sign of packing off while pulling up or slacking off. Indicates mechanical obstruction @ or around conductor shoe w/ top of mud motor (conductor shoe @+/-107' MD). Racked back HWDP.;P/U and inspect bit (no damage). M/U MWD tools and scribe same (RFO= 384/813' 360 = 170.03') RFO witnessed by Shane Barber. M/U and orient UBHO to HS. Upload MWD. PJSM and R/U Gyro while uploading MWD.;M/U bottleneck XO and Kelly up. Shallow pulse test MWD (good). M/U Flex DC's and RIH to 130' MO where we tagged up. Attempt to work past with no pump or rot (no go). Rack back flex DCs and Kelly up w/ std of HW DP. Work past obstruction several times before we were able to trip past clean.;Rack back stand of HWDP and M/U flex DC's. Attempt to trip back in but tagged up again @ 130' MD. Made several attempts to work past (no go). UD Flex DC's. M/U bottleneck XO to single jt flex DC and work past obstruction w/ pump & rot. MIU 2nd flex DC and TIH w/ HWDP to 220' MD.;PJSM Drill and slide 12.25" hole F/ 220' to 328' (327 TVD) 108' Total (54' AROP) 400 GPM, 640 PSI, 40 RPM, TRQ 2K, WOB 1-61k. P/U 53K, SLK 53K, ROT 53K. Perform Gyro surveys F/ 205' to 309' MD. First clean MWD survey was at 291' MD. Hold Halliburton on stand by.;Drill and slide F/ 328' to 889' MO. ( 877' TVD) 561' Total (93.5' AROP) 480 GPM, 1,020 PSI, 50 RPM, TRQ 2.4K, WOB 12K. P/U 70K, SLK 70K, ROT 70K. Closest approach CC to E-17 was at 598' MD at 25.63'. At 787' MD CC close approach 45.60'.;At 850' MD CC close approach 60.72'. Still getting clean MWD surveys with no interference. Reduce Spud Mud Vis with more clay and sand at Shakers.;Drill and slide F/ 889'to 953' MD. 500 GPM, 1,020 PSI, 80 RPM, TRQ 4.3K, WOB 12K. P/U 74K, SLK 73K, ROT 73K.;PJSM W/ all parties for UD Halliburton. UD Halliburton tools and Equip. Released at 01:OO.;Drill and slide F/ 953'to 1,510' MD. (1,378' TVD) 557' Total (111' AROP) 550 GPM, 1,500 PSI, 80 RPM, TRQ 5K, WOB 12.6K. P/U 78K, SLK 74K, ROT 76K. Slide Hrs 4.04, Rot His 2.42, Bit Hrs 6.46 , Jar Hrs 6.46.;Distance to WP #911.78', 7.66 Low, 8.96 Right.;Running both Centrifuges and water at 50 bph.;Hauled 400 bbls Fluid to MP G&I total = 457 bbls Hauled 0 bbis fluid to BSO total = 0 bbls Hauled 650 bbls H2O from L-Pad Lake total = 1,560 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 0 bbls to formation total fluid lost = 0 bbls 1/4/2019 Drill and slide 12.25" hole F/ 1510'. T/ 2,103' MD. 593' Total (99' AROP) 550 GPM, 1,600 PSI, 80 RPM, TRQ 5K, WOB 5K. P/U 87K, S/0 74K, ROT 76K. 12.1 ECD's. Added 50 bph H2O and screened up to 120's across shakers. Mostly clay with minimal gas.;Drill and slide 12.25" hole F/ 2,103' - T/ 2,781' MD 12,122' TVD. 678' Total (113' AROP) 600 GPM, 1,720 PSI, 80 RPM, TRQ 5K, WOB 5K. P/U 104K, S/O 69K, ROT 85K. 12.3 ECD's. Logged base of permafrost @ 2240' MD / 1814' TVD. Backream stands as needed to assist in hole cleaning.;Saw significant drop tendencies (3'/100) while rotating 2200'- 2500' MD.;Drill and slide 12.25" hole F/ 2,781' to 3,543' MD. ( 2,552' i VD) 762' Total (127' AROP) 500-600 GPM, 1,650 PSI, 60-80 RPM, TRQ 5-7.5K, WOB 34K, 9.8 ppg ECD. P/U l l5K, SLK 77K, ROT 93K. Max Gas 297U. Screened up to 170's on #2 Shaker.;Fine silt and sand at Shakers. Running both Centrifuges and water at 50 bph. At 3,100' MD added 2 drums of drill-n-slide.;Drill and slide 12.25" hole F13,543' to 4,172' MD. (2,926 TVD) 629' Total (105' AROP) 500-600 GPM, 2,044 PSI, 60-80 RPM, TRQ 9-10K, WOB 9K, 10.0 ppg ECD. P/U 128K, SLK 84K, ROT 100K. Max Gas 1,577U. Slide Hrs 3.85, Rot Hrs 9.14, Bit Hrs 19.45 , Jar Hrs 19.45.;Reduced ROP and drill rate to 400 GPM at 150 FPH ROP due screens blinding off. Had to screen back down Shaker #2 to 1201120/170/170 due blinding off of fine silt and sand.;Started seeing increase in Gas at 3,760'to 3,770' MD peaked at 1,577U and dropping to 570U BGG. Running Degasser.;Distance to WP #9 6.06, 3.14 High, 5.18 Right.;Hauled 1,197 bbls Fluid to MP G&I total = 1,654 bbls Hauled 0 bbls fluid to 8-50 total = 0 bbls Hauled 1,170 bbls H2O from L-Pad Lake total = 2,730 bbls Hauled 0 bbls H2O from Lake 2:0 bbls Lost 0 bbls to formation total fluid lost = 0 bbls 1/5/2019 Drill and slide 12.25" hole F/ 4172' to 4,614' MD. 442' Total (111' AROP) 500-600 GPM, 2100 PSI, 60-80 RPM, TRQ 9-10K, WOB 9K, 10.0 ppg ECD. P/U 133K, S/O 87K, ROT 101 K. Max Gas 549U. His vis sweep @ 424V MD, 75 bits early with minimal increase in cutflngs.;Rack back one stand and change out wash pipe. Service handling equipment.;Drill and slide 12.25" hole F/ 4614'to 4700' MD. 500-600 GPM, 2100 PSI, 60-80 RPM, TRQ 9-10K, WOB 9K, 10.0 ppg ECD. P/U 133K, S/O 87K, ROT 101 K. 100-200u BGG ;Drill and slide 12.25" hole F/ 4700' to 5,310' MD. (3,581' TVD) 606' Total (101' AROP) 500600 GPM, 2320 PSI, 80 RPM, TRQ 13K, WOB 12K, 10.0 ppg ECD. P/U 156K, S/O 85K, ROT 111K. 100u BGG. Start build and tum @ 4929' MD.;Drill and slide 12.25" hole F/ 5,310'to 5,815' MD. (3,850' TVD) 505' Total (84' AROP) 500-600 GPM, 2,250 PSI, 80 RPM, TRQ 14K, TRQ off 11-16K, WOB 10-12K, 10.01 ppg ECD. P/U 158K, S/O 92K, ROT 116K. Max Gas 457U.;Running both Centrifuges and water at 50 bph.;Drill and slide 12.25" hole F/ 5,815' to 6,318' MO. (4,095' TVD) 503' Total (84' AROP) 600 GPM, 2,275 PSI, 80 RPM, TRQ 13.8K, TRQ off 16K. WOB 7K, 10.1 ppg ECD. P/U INK, S/O 85K, ROT 119K. Max Gas 754U. BGG 150-350U. Slide Hrs 6.25, Rot Hrs 5.51, Bit Hrs 31.21 , Jar Hrs 31.21.;Start increasing mud weight from 9.15 ppg to 9.3 ppg at 5,850' MD.;Distance to WP #9 21.73', 12.21 High, 17.97 Right.;Hauled 1,031 bbls Fluid to MP G&I total = 2,685 bbls Hauled 0 bbls fluid to B-50 total = 0 bbls Hauled 1,300 bbls H2O from L-Pad Lake total = 4,030 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 0 bbis to formation total fluid lost = 0 bbls 1/6/2019 Drill and slide 12.25" hole F/ 6318' - T/ 6507' MD. (4,167' TVD) 189' Total (63' AROP) 600 GPM, 2,300 PSI, 80 RPM, TRQ 17K, TRQ off 16K. WOB 11 K, 10.1 ppg ECD. P/U 178K, S/O 84K, ROT 116K. Max Gas 754U. BGG 150-350U.;Shot survey @6468! MD. 8.13" DL. Rack back and attempt to reduce dogleg working pipe F/ 650T - T/ 6439' MD. Reshoot svy with minimal change. Discuss with drilling engineer and continue drilling ahead.;Drill and slide 12.25" hole F/ 6507' - T/ 6600' MD. (4,201' ND) 93' Total (4T AROP) 600 GPM, 2,300 PSI, 80 RPM, TRQ 17K, TRQ off 16K, F/O 61 %, WOB 11 K, 10.1 ppg ECD. P/U 178K, S/O 87K, ROT 116K. Max Gas 754U. BGG 150-350U.;Drill and slide 12.25" hole F/ 6,600' To 7,100' MD. (4,316' TVD) 500' Total (83' AROP) 600 GPM, 2,200 PSI, 80 RPM, TRQ 17.5K, TRQ off 18-21 K, F/061%, WOB 6K, 10.21 ppg ECD. P/U 180K, S/0 81 K, ROT 120K. Max Gas 402U. BGG 100-4000.;Drill and slide 12.25" hole F/7,1001 To 7,265' MD. (4,331' TVD) 165' Total (47 AROP) 600 GPM, 2,200 PSI, 80-90 RPM, TRQ 16-18K, TRQ off 14-18K, F/O 61 %, WOB 6K, 10.26 ppg ECD. P/U 185K, SID 80K, ROT 120K. Max Gas 402U. BGG 100-4000. Increasing mud weight F/ 9.4 to 9.5 ppg.;Maintaining 2% Lubes. Both Centrifuges running, water 50 bph. Encountered high stick slip and torque while rotating. Adjusted drilling parameters flow rate and RPM with little effect. May have encountered a fault in the Schrader Bluff NA Sand as per onsite Geologist.;Pumped 20 bbl HiVis and 20 bbl low Vis low weight tandem sweep. Sweep came back as calculated with minimal increase is cuttings. Max Gas during BU 845U.;DnII and slide 12.25" hole F/ 7,265' To 7,331' MD. (4,336' TVD) 66' Total (66' AROP) 600 GPM, 2,200 PSI, 100 RPM, TRQ 16-18K, TRQ off 14-18K, F/O 61 %, WOB 6K, 10.15 ppg ECD. PIU 185K, S/O 80K, ROT 120K. Max Gas 331U. BGG 100-4000. At about 7,310' MD drilling stick slip and TRQ smoothed out.;Drill and slide 12.25" hole F/ 7,331' To 7,644' MD. (4,375' TVD) 313' Total (52' AROP) 600 GPM, 2,329 PSI, 80 RPM, TRQ 17-18K, TRQ off 16-18K, F/O 61 %, WOB 18K, 10.26 ppg ECD. P/U 185K, S/O 80K, ROT 120K. Max Gas 390U. BGG 100-4000. Slide Hrs 7.75, Rot Hrs 5.85, Bit His 44.81 , Jar Hrs 44.81.;Distance to WP #914.08', 0.28 High, 14.08 Right.;Hauled 570 bbls Fluid to MP G&I total = 3,255 bbls Hauled 0 bbls fluid to B-50 total = 0 bbls Hauled 1,040 bbls H2O from L-Pad Lake total - 5,070 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 0 bbls to formation total fluid lost = 0 bbls 1/7/2019 Drill and slide 12.25" hole F/ 7,644' - T/ 7,931' MD. 287' Total (48' AROP) 600 GPM, 2,320 PSI, 80 RPM, TRQ on 19.5K, TRQ off 17.51K, F/O 61 %, WOB 18K, 10.25 ppg ECD. P/U 183K, SID 80K, ROT 120K. Max Gas 479u. BGG 100-400u. Control drill as per Geo.;DnII and slide 12.25" hole F/ 7,931' - T/ TD@ 8,066' MD 14403' TVD (TO. 135' Total (54' AROP) 600 GPM, 2,180 PSI, 80 RPM, TRQ on 19.5K, TRQ off 17.51K, F/O 61 %, WOB 18K, 10.25 ppg ECD. P/U 181 K, S/O 78K, ROT 117K. Max Gas 690u. BGG 100-400u. Observed drilling break @ 7,883' MD.;OA2 sand @ 7,929 MD / 4402' TVD. Obtained final svy w/ 90° Inc @ bit. 12' right of plan and landed in zone (OA2). Monitor well (static). Slide Hrs 1.49, Rot Hrs 4.25, Bit Hrs 50.55 , Jar Hrs 50.55.;BROOH F/ 8,066 to 7,820' MD 600 GPM, 2,280 PSI, 80 RPM, TRQ 18-24K. Max Gas 603U. Encountered a couple fight spots and torque stalls W/ 24K TRQ.;Reciprocate F/ 7,831' to 7,764' MD Pump 25 bbis 10.6 ppg 316 Vis, 25 bbl 8.6 ppg 42 Vis tandem sweeps. CBU 3X at 600 GPM, 2,150 PSI, 80 RPM, TRQ 15 to 21 K. Max Gas 692U. Sweeps came back 63 bbls early W/ 10% increase at Shakers.;PJSM Greased swivel packing on Top Drive due to leak. C/O swivel packing. Tested good. Monitor hole on trip tank, well static.;RIH on elevators F/ 7,76,V to 8,066' MD. Observed about 5-8K drag but no fill on bottom.;BROOH F/ 8,066'to 6,763' MD. 60a GPM, 2,050 PSI, 80 RPM, TRQ 16-24K, 5-20 ft/min. Worked multiple fight spots encountering torque stalls at 24K but not packing off F/ 7,179 to 6,949 MD. Tight spots appeared to be through the slide sections when we were drilling.;Slowed back reaming through fight spots and reamed back through without issue. Max Gas 195U.;BROOH F/ 6,763' to 5,280' MD. 600 GPM, 1,985 PSI, 80 RPM, TRQ 16-20K, 5-10 ft/min. Max Gas 171 U. Worked tight spot at 6,309' MD due to 24K stalling. Work through and wash back down. Ream back through with out issue. Cont. BROOH with out issues. No Iosses.;Distance to WP #9 31.38', 28.57 High, 12.98 Left.;Hauled 513 bible Fluid to MP G&I total = 3,768 bible Hauled 0 bbls fluid to B-50 total = 0 bible Hauled 880 bbls H2O from L -Pad Lake total = 5,070 bbls Hauled 0 bible H2O from Lake 2: 0 bible Lost 0 bbis to formation total fluid lost = 0 bbis 1/8/2019 Cont BROOH F/ 5289 - T/ 4238' MD. Saw moderate tq spikes with slight packing off issues. Backream @ 2-15 fpm as hole dictates. Reduce rate to 2 fpm F/ 4959 - T/ 4800' (tangent section). Circulate tandem sweep. B/R @ 620 gpm, 1790, 80 rpm, 14k tq. ECD's 10.2 - 10.1;Cont BROOH F/ 4,238'- T/ 2,550' MD. 600 gpm, 1450 psi, 80 rpm, 9k tq. Pull rate varied F/ 2-15 fpm as hole dictates. Continue seeing slight packoffs and stalls. Able to slowly work thm tight spots without issue. Pits GIL showed a total of 57 bbl loss to hole since beginning backream operations;Change out swivel packing while monitoring well on trip tank- static.;Continue to BROOH from 2550'to 1460' at 600 gpm 1370 psi, 80 rpms, 6-13Kft-lbs ECD's 9.9 -10.2 ppg. Slow pulling speed to 2 fpm at 2400' to 2275' (2 stands below permafrost) getting 2 x annular volume prior to permafrost. Continue backreaming 2-14 fpm as hole dictates with several TO stalls.;Continue to BROOH from 1469 to 364', 600 gpm 1100psi 80 rpms 3-6.5Kft-lbs. pulling 2 -14 fpm based on hole conditions, slowing speed for higher torque and ECO's. Observe hole unload sand and clay at 1076-1000', slow pulling speed and allow shaker to clean up.;Rack back Jars and HWDP. PJSM UD Drill collars to BU.;Hauled 575 bible Fluid to MP G&I total = 4,343 bbis Hauled 0 bible fluid to B-50 total = 0 bbis Hauled 780 bbis H2O from L -Pad Lake total = 6730 bbis Hauled 0 bbis H2O from Lake 2: 0 bbls Lost 112 bible to formation total fluid lost= 112 bbls 1/9/2019 L/D Flex DC's. Download MWD. B/O and UD MWD tools. Drain mtr, B/O bit and UD same. Significant damage on mtr sleeve (See pics "O" drive, well file) Bit grade - 3,3,CT,A,F,3/16",BT, TD.;Clean and clear rig floor. UD tools from floor.;Change out swivel packing and test same. Test 1000 psi (test good). Service Top Drive and traveling equipment.;Bring Weatherford casing equipment to rig floor. Tarp and heat double stack 9-5/8" power tongs. R/U Volant CRT, 9-5/8" 2507 side doors. Hookup hydraulics and function same (good). Verify shoe track is clear (good).;PJSM, discuss operational limits and considerations for extreme cold environments (-38° F), MN 9-5/8" shoe track as per detail. Bakerlok shoe track connections. Circulate thru shoe track and check floats (Steam Hyd IBOP to make function). B/D TOS and chip ice from handling equipment.;Run 9-5/8", TXP BTC, 40#, L-80 casing F/ surface - T/ 1,035' as per detail. Install bow spring centralizers as per detail and record displacement every 5 jts. 21 k ft/lbs make up tq (optimum). Set down at 1,035' attempt to work past unsuccessful, attempt to wash through at 4 bpm/80 psi, unable to;establish rotary 5-10 rpms/5-SKft-lbs wash and ream down to 1,057'. Continue washing down at 4 bpm/80 psi to 1,405' with 5-15K drag, reaming tight spot at 1,155'-1,210' with 5 rpms. Loss rate 2 bph.;Continue to wash casing down from 1,405' to 2,350' at 3-4 bpm/90 psi with 0-15K drag progressively getting better. RIH no pumps to 2550'.;Circulate annular volume staging pumps up to 6 bpm/120 psi, loss rate 5 bph.;Confinue to RIH with 9-5/8" TXP BTC, 40#, L-80 casing from 2550' to 2699'. PUW 135K, SOW 76K.;Hauled 632 bbis Fluid to MP G&I total = 4,975 bbis Hauled 0 bbis fluid to B-50 total = 0 bbis Hauled 390 bbls H2O from L -Pad Lake total = 7120 bible Hauled 0 bbis H2O from Lake 2: 0 bible Lost 34 bbis to formation total fluid lost= 146 bible 1/10/2019 Cont Run 9-5/8" TXP BTC, L-80, 40# casing F/ 2,699'- T/ 2,850' MD. -Record disp every 5 jts.138k up, 78k dn. 21k tq cennectionsJong valve handle had to be replaced along with failed psi sensor gauge line. Replace and function test (good).;Confinue run 9-5/8" casing F/2,850' - T14,531'. 40 fpm max running speed. Consistently showed around 2 bph loss rate regardless of running speed. 230k up, 85k dn.;Volant CRT had mud leak at sealing element on tool (cup). No significant damage but showed a little wear. Replaced cup and continued running casing with no more Ieak.;Continue run 9-518" casing F/4,531' - T/ 4,89T MD. 40 fpm max running speed. Record displacement every 5 jts. 284k up, 84k dn.;Circulate and condition mud reciprocating pipe F/4,897' - 714,937' MD. Stage pumps up to 8 bpm, 255 psi, 53% flow w/ minimal losses while circulating. Circulated 1.5x Btms up. Saw slight to moderate cuttings @ shakers. Mostly sand w/ a trace of smaller pieces of wood. Gas remained negligible.;Confinue run 9-5/8" casing in lower build and turn section F/ 4937'- T16,534' MD. 40 fpm max running speed. Record displacement every 5 jts. Casing showed steady down wt with no issues running in on elevators 82k dn, 307k up.;Circulate annular volume staging pumps up to 7.5 bpm/250 psi reciprocating pipe PUW 330K, SOW 100K with minimal Iosses.;Continue run 9-5/8" casing F/ 6,534' - T/ 8,056' MD. 40 fpm max running speed. Record displacement every 5Its. 84k dn. Wash last joint to bottom 2 bpm/300 psi.;Circulate holestaging pumps up to 8 bpm/300 psi initial PUW 380K w/o breaking overwork pipe while staging pumps up and observe hole cleanup with 320K up weight, 85K slackoff weight. Prep pits for, build spacer for ES cementer, lower pit volume. RID casing tongs, bail ext.;Blow air through cement line and clear out ice plug. Clear ice plug in'T' on Volanttool. B/D Top drive. Rig up cement Iines.;HES pump 9 bbls water. PT lines 700/4000 psi good. Pump 38 bible 10 ppg spacer at 2 bpm/150 psi. Drop bottom plug. Currently 150 bbis into lead 5 bpm/350 psi. Reciprocating pipe. For full cement details see next report date 1/12119.;Hauled 404 bbls Fluid to MP G&I total= 5,379 bible Hauled 0 bbls fluid to B-50 total = 0 bbis Hauled 260 bible H2O from L -Pad Lake total = 7380 bible Hauled 0 bible H2O from Lake 2: 0 bible Lost 38 bbls to formation total fluid lost = 184 bible ov"7� a`�/4?`f 1/11/2019 PJSM, 1 stg surface cmt: Clear cmt line to cmt unit. Flood lines w/ 9 blols water. PIF lines 750/4000 psi (good). 60 bbls 10# Tuned Spacer III at 4 bpm/320 psi wl 4# red dye first 10 bbls. Drop bypass plug.;Mix and pump 763 sxs, (320 bbls/2.355 yld) Type VII at 12 ppg at 5.5 bpm/475 psi. Mix and pump 398 sxs (82 bbis) Premium G Tail Cement at 15.8 ppg at 2.5 bpm/244 psi. Drop Shut off Plug.;Disp cmt w/ 20 blots FW(HES). Rig Pump 377 bbls 9.5# mud 8bpm /440psi/43%. 40 blots 10# water spacer FW @ 6 bpm/635psi/45%. 168 bbls 9.5 spud mud @ 3 bpm/FCP 850 psi. Bumped @ 9426 sties (3bbls over calculated). Psi up 1443 w/ 5 min hold. Bled back 2.5 bbls. Floats held.;Full returns throughout job. CIP @ 09:11 his. Recip pipe 286 bbis into disp, 330k up, 80k dn. Parked string @ 200k in tension for remaining disp. Psi up to 1400 psi min hold), 1650 psi (5 min hold), 1900 (5 min hold), 2150 (5 min hold). Psi up 2165 Inflate Packer, Psi up 2360 Open Stg tool.;Establish circulation thru ES cementer. Stage up to 7 bpm, 2115 psi with full returns. Saw significant psi drop from 2115 to 535 psi. Circ ports assumed to have only partially opened when initially establishing circulation and now full Open. Circ 4x Btms up. Saw spacer and 8 bbis cmt returns.;Clean cuttings box, Offload excess mud from pits and offload at G&I for disposal. Spot trucks for 2nd stage cmt lob. Top rinse pits and ready for 2nd cmtjob. Fill water tank and heat to 80"F for cmtjob.;PJSM 2nd stage cement HES pump 9 bbis water, 53 bbis 10# clean spacer at 4 bpm/320 psi w/ 4# red dye first 10 bbis. Mix and pump 308 bbis (400 sxs) 11.1 ppg PermaFrost L lead cement at 6.5 bpm/780 psi. Pump lead cement until cement returns observed at surface.;Mix and pump 60 bbls (289 sxs) 15.8 ppg Class G tail cement at 2.4 bpm/300 psi. Drop closing plug. Displace with 20 bbls H2O followed by 165 bbis of 9.5 ppg drilling fluid at 4.5 bpm/670 psi.;Slow rate to 3 bpm last 20 bbis with FCP 580 psi. Pressure up to 2000 psi to close ES cementer, positive indication of closure observed. Held pressure for 5 minute. Bleed back and confirm ES cement closed closed (bled back 2 bbl 240 blots of cement returned to surface. No d. losses. CIP at 20:10.;Clean and clear rig floor and cellar. Filled stat with ac water and function bag twice. ig down volant tool.;5ecure stack with bridge crane remove chains. RID diverter pipe from'T'. 4-bolt diverter T to stack. Split stack above starter head and lift. Center landing joint. Install slips with 150K hookload. Slack off and set 60K on slips. Offload mud and start cleaning pits. Begin loading pipe shed.;Rough cut landing joint: cut length 28.51'. Set stack back on stump and 4-bolt. Change out leaking air boot on stack. Change out elevators and pick up stack washing tool. Flush stack with black water. Blow down top drive. Continue cleaning pits and loading pipe in shed. N/D diverter Iine.;Drain stack and clean out cellar box. N/D knife valve, diverter T and spacer spool.;Hauled 1731 bbis Fluid to MP G&I total = 7,110 bbls Hauled 0 bbis fluid to B-50 total = 0 bbls Hauled 1170 bbls H2O from L-Pad Lake total = 8550 bbis Hauled 0 bbis H2O from Lake 2: 0 bbis Lost 35 bbls to formation total fluid lost = 219 bbls 1/1212019 Make final 9-5/8" casing cut Cgs 21.5" above "E" slips. Bevel and dress stump. Install 11" Slip Lock Wellhead and test same. 500/2400 psi w/ 5/15 min hold (test good). Install multibowl and N/U same as per wellhead rep James Craycroft. Clean and prep pits, Load 220 jts 5" dp in shed.;PJSM install 13-5/8" 5K BOPE stack and torque bolts.;PJSM install test plug. close blind rams, bleed accumulator. Rig down annular cap pull element and adapter ring. Observe burrs and scarring on ring. File down burrs and rough surfaces. Install new orings and piston seals. Reinstall adapter ring with new seals. Install new element, and top cap.;Torque bolts. Hook up accumulator lines and Re-energize, bleed air from unit and fill with hydraulic oil. Function test accumulator. SimOps: Pull fluid ends on mud pumps for inspection. C/O two suction valves and seats and 2 discharge valve and seats.;Install bell nipple. Change out air boots. Tighten choke and kill lines flanges. Install riser, hole fill line. Hook up turnbuckles to stack. Rig up hydraulic elevators.;R/U to test BOPE. Pickup testjoint and makeup art, TIW and pump in sub.;Hauled 592 bbls Fluid to MP G&I total = 7,630 bbis Hauled 0 bbis fluid to B-50 total = 0 bbls Hauled 520 bbls H2O from L-Pad Lake total = 9070 bbls Hauled 0 bbls H2O from Lake 2: 0 bbls Lost 35 bbls to formation total fluid lost= 219 bbis 1/13/2019 R/U BOP test equipment. M/U TIW, Dart w/ 5" test jt. Purge air from system. Found Kelly Hose frozen from previous operations (cmt job). Disconnect Kelly hose from TDS and steam ice plug from line. Attempt to shell test 250/3000 (fail). Mezzanine kill valve was leaking. Svc and retest (fail).;Rebuild Mezzanine Kill vatve.;Shell test 250/3000 (test good). Begin testing BOP's as per guideline. AOGCC rep Matt Herrera onsite to witness test. Test PVT levels, G/L alarms and flow paddle (test good). Test gas alarms - H2S 10120, LEL 20/40(test good) Tested w/ 3.5" and 5" test jt. F/P on;superchoke. Function and flush. Accumulator drawdown: starting pressure 2900 psi, final 1500 psi; 200 psi recharge in 24 seconds full recharge 90 seconds. (6) N2 at 2292 psi average.;PJSM rig down testing equipment. Break down test joint. Pull test plug. Set 9" ID wear bushing.;Continue working on thawing Kelly hose. Disconnect from stand pipe and lower into shed to thaw out. Reconnect Kelly hose. Install mousehole. Clean and clear rig floor. Load mud motor into pits, bring bit to floor.;PJSM pick up and make up 8.5" Cleanout BHA. M/U 8.5" tricone XR+XP Smith bit, SperryDrill Lobe 6(7 motor with 1.5 bend, (6) joints HWDP, Jars, It 1) joints HWDP.;Drift, pick up and single in the hole with 5" drill pipe from 586.66! to 2428'. Tag up on cement with 8K.;Establish parameters 300 gpm/560 psi, 15 rpms/5.8 ft-lbs, PUW 97K, SOW 68K, ROTW 75K. Drill up cement from 2428' to 2434' and ES cementer from 2434'to 2440'300-350 ppm/600-680 psi. 15rpms/6-7Kft-lbs, WOB 2-7K ;Work through multiple fimes with pumps/rotary and no pumps/rotary - clean. Wash and ream to 2471'.;Hauled 35 bbls Fluid to MP G&I total = 7,665 bbls Hauled 230 bbis H2O from L-Pad Lake total = 9300 bbls Lost 0 bbls to formation total fluid lost = 219 bbls 1/14/2019 Single in 8.5" mtr cleanout assy on 5", 19.5# NC50 drill pipe F/ 2,471'- T/ 6,575' MD. Drift - 3.250".;TIH out of derrick F/ 6,575 - T/ 7,870' MD. Tagged 7k @ 7870' MD.;Pick up and establish circulation. Wash and ream down thru cmt stringers F17,879 - T/ 7,898' MD. 300 gpm, 1000 psi, 30 rpm, 21k tq, 190k up, 60k dn, 112k rot. Cmt took 14k WOB to drill.;Rack back 1 std. Circulate and condition mud. Stg up to 7 bpm, 800 psi, 52%flow. 9.5In/Out ;B/D TDS. R/U csg test equipment. Pressure test 9-518", 40#, L-80 casing to 2,500 psi. 6.5 bbls pumped, 5.25 bbis bled back. Test good. Chart and record same.;PJSM, Cut and slip Vy 88' drilling line. Inspect brakes and adjust same. Svc traveling equipment, grease and svc floor handling equipment.;PJSM Drill cement, shoe track and 20' of new hole from 7898' to 8086, tag up on baffle adapter on depth at 7934', float collar at 7973' and shoe at 8054'. 350 gpm/835 psi, 30 rpms/21 Kft-lbs, WOB 2$K. Pl1W 190K, SOW 60K, ROTW 112K.;Displace wellbore from spud mud to 9.3 ppg Baraddl-N, pump 40 bbis spacer followed by new mud at 350 gpm/740 psi, 30 rpms/17Kft-lbs reciprocating pipe. Circulate and condition for FIT even MW 9.3 ppg in/out.;PJSM Blow down top drive. Rig up and perform FIT. Purge air from lines. Difficulties getting pump primed, trouble shoot and bleed air, switch to MP 1 and pit. Performed FIT to 12 opg to 638 psi. Pumped 2.2 bbls bled back 1.2 bbis. Rig down and blow down Iines.;Obtain SPR blow down. POOH with cleanout assembly from 8022'to 7693' checking for swabbing.. Pump dryjob. Continue to POOH to 6989'. PUW 200K, SOW 75K.;Hauled 1067 bbls Fluid to MP G&I total = 8,732 bbis Hauled 450 bbis H2O from L-Pad Lake total = 9750 bbls Lost 0 bbis to formation total fluid lost = 219 bbls 1/15/2019 Continue to POOH with 8.5" cleanout assembly from 6989' to 394'.;Continue to POOH from 394' to surface. UD excess HWDP, LID BHA. Clean and clear rig floor.;Bring BHA components to rig floor. PJSM W/ all essential personnel. Make up BHA #3 as per Halliburton Reps, PIU M/U 8.5" SK616-J1 D Bit, 8.5" NOV NRP, Geo-Pilot 7600, ADR/HCIP collar, 8-3/8" ILS, DGR, PWD, DM, TM, Float Sub with solid float, 3 ea NM Flex Collars,;5" HWDP, Jars and 5" HWDP to 268' MD. Shallow pulse test MWD - good.;RIH with 8-1/2" Drilling assembly from 269 to 4980' filling pipe every 2500'. Break in Geo-Pilot seals as per DD.;PJSM change out rig tongs and weight buckets. Clean and clear rig floor.;Continue to RIH with 8-1/2" drilling assembly from 4980' to 5795'. PUW 162K, SOW 82K.;Hauled 115 bbis Fluid to MP G&I total = 8,847 bbls Hauled 200 bbis H2O from L-Pad Lake total = 9950 bbls I,S 1/16/2019 Continue to RIH with 8.5" drilling assembly from 5796 to 7950' filling pipe every 2500'. PUW 186K, SOW 77K.;Circulate annular volume at 500 gpm/1180 psi ECD 10.1.;Geologists and DD's sent to Doyon 14 to assist. Continue circulating at 350 gpm/790 psi to maintain MWD battery. Process 6-5/8" predrilled liner in pipe shed. Clean and organize rig. Work on weekly and monthly inspections. Pressure wash windwalls. Inventoryparts. Check electric J box on TD;for oil - clean. Install teflon wear pads on catwalk. Remove old annular element from cellar. Take manual elevators and T tongs to shop and paint. Clean cellarwalls, catch pan. Service Skate. Install plumbing in pits to dump trip tank to drag chain.;Hauled 115 blots Fluid to MP G&I total = 8,962 bbls Hauled 130 bots H2O from L-Pad Lake total = 10080 bbls Lost 0 bbls to formation total fluid lost = 219 bbls 1/172019 Geologists and DD's sent to Doyon 14 to assist. Continue circulating at 350 gpm/865 psi ECD 9.87 ppg to maintain MWD battery. Continue to clean and pressure wash BOP's, cellar, mezzanine. Continue to prep and paint manual etevatoWrig tongs. Finish installing teflon wear pads on catwalk.;Disassemble hole fill pump and inspect impellar, good. Start prepping to replace drag chaing paddles.;Geologists and DD's sent to Doyon 14 to assist. Weekly and monthly inspections. While cleaning cellar observe bubbling on top of'E' slips. Use hand held monitor, 100% LEL at between slip dies, all other areas 0 LEL, 4-gas monitor indicates methane. Rig up venturi air blower for proper;ventitation. Discuss options with town and HES. Build 200 bbls of brine for ASR. Grease TD, Crown, Spinners. Install plywood on catwalk. Replace paddles on drag chain.;Continue to wait on Geologist. Continuous monitoring in cellar, remains the same. Inspect and lubricate bridge crane. Monthly inspections on tuggers. Spill Champion walk around. Clean out all duckponds and containment of snow. Pressure wash/clean pits and hopper house. Clean paddles from drag chain.;Hauled 57 bbls Fluid to MP G&I total = 9,019 bbls Hauled 260 blols H2O from L-Pad Lake total = 10340 bbls Lost 0 blots to formation total fluid lost = 219 bbis 1/18/2019 Continue to wait on Geos. Geologists and DD's sent to Doyon 14 to assist. Continue circulating 375 gpm/865 psi to maintain MWD battery. Continue to monitor small amount of gas detectable just above casing slips, no gas detected in other parts of cellar. Continue with housekeeping and inventory.;Discuss options regarding cellar with Halliburton cement and start mobilizing equipment. Heat water in trip tank and flush 30 bbls through conductor valves and out through top of slips to prep for cement.;Continue with house keeping and maintenance. Continue monitoring cellar. Replace drag chain beargings, repair steam leak in utilidoor. Install heat in cellar, rig up air and water lines for cementem. Spot in cementers. Build contamination pill for cement.;PJSM with cementem. Blend 85 gallons of 14.8 ppg cement with microbond and 15% Welllok. Pump through 4" conductor valves, shut in discharge valve once good cement was observed and sample caught. Continue pumping cement bring it out the top of casing 'E' slips CIP 21:50 Clean and clear cellar.;Continue to monitor cellar. Continue with housekeeping, Rig PM program. Sling inventory. Continue replacing drag chain bearings. Remove and repair pipe skate buggy foot.;Continue to monitor cellar, LEL readings above casing slips continue to get better until 04:00 when they went to 0 LEL. Clean and organize drilling conneXs. Continue priming and painting rig tongs and elevators. Update JSA's and procedures. Work on EAM's.;Hauled 170 bbls Fluid to MP G&I total = 9,189 bbls Hauled 260 bbls H2O from L-Pad Lake total = 10340 bbls Lost 0 bbls to formation total fluid lost = 219 bbls 1/19/2019 Continue to wait on Geos. Geologists and DD's sent to Doyon 14 to assist. Continue circulating 375 gpm/865 psi to maintain MWD battery. Continue priming and painting tongs and elevators. Update/revise JSA's and procedures. Working on EAM's. Install lockable pin on mud mod. Clean cellar;and cattle chute. Cont changing drag chain bearings. Inspect floor equipment.;RIH to 8,086, washing and ream last 30' 450gpm/1200 psi, 80rpms118.8Kft-Ibs.;Drill ahead 8.5" Hole F/8086'to 8166' MD. 80'total (80' AROP) 450 gpm/1175psi, 80 rpms/17Kft-lbs, 2-5K WOB, PUW 192K, SOW 68K, ROTW 115K. ECD 10.24 ppg, Max Gas 1,014U , MW 9.3 ppg.;Attempt to send downlink to Geo-Pilot, not receiving timing out. Troubleshoot communication error. Change out nozzle on Geo-Span and GeoPilot responds correctly.;Drill ahead 8.5" Hole F/8166' to 8322' MD. 156'total (104' AROP) 450 gpm/1215psi, 80 rpms/16.3Kft-lbs, 4-5K WOB, PUW 192K, SOW 68K, ROTW 115K. ECD 10.24 ppg, Max Gas 1,014U, MW 9.3 ppg.;Circulate hole 450gpm/1200 psi. Discuss discrepancy between short collar surveys from surface hole and long collar with HES and Hilcorp town. Three surveys on surface were flagged as suspect, re-evaluate survey s.;Drill ahead 8.5" Hole F/8,322'to 8,529' MD. 20T total (138' AROP) increase flow to 550 gpm/1671 psi rotary 120rpmsr17.7Kft-lbs for hole cleaning. WOB 4-8K. ECD 10.47 ppg EMW with 9.3 ppg mud. Max gas 1817U.;Ddll ahead 8.5" Hole F/8,529'to 9,165' MD. 636'total (106 AROP) flow 500/1530psi to 550 gpm/1671 psi as shakers allow rotary 140rpms20.5Kft-Ibs . WOB 6-10K. ECD 10.42 ppg EMW with 9.3 ppg mud. Max gas 2403U. PUW 180K, SOW 69K, ROTW 113K.;Pump tandem sweep at 8910% on time with 25% increase in cuttings.;4 concretions drilled for a total of 13', 1.3% of lateral 1 fault crossed at 8,110' with T throw 804' Drilled so far in OA-1 Distance to WP#9 22.2'; 22.2' low, 1.1' right;Hauled 93 bbls Fluid to MP G&I total = 9,282 bbls Hauled 220 bbls H2O from L-Pad Lake total = 10560 bbls Lost 0 bbls to formation total fluid lost production = 0 bbls 1202019 Drill ahead 8.5" Hole F/9165'to 9,634' MD. 469'total (78' AROP) flow 515/1575psi to 550 gpm/1671 psi, 125rpms/19k ft-Ibs . WOB 6-8K. ECD 10.36 ppg EMW with 9.3 ppg mud. Max gas 1930U. PUW 171 K, SOW 72K, ROTW 113K.;Start increasing lubes to 3% @ 9439'. See crude oil on shakers @ 9559.;Drill ahead 8.5" Hole F/9634'to 10,360' MD. 726'total (121' AROP) flow 425/1400psi to 500 gpm/1600psi, 140rpms/20.8k ft-Ibs . WOB 4K. ECD 10.5 ppg EMW i with 9.4 ppg mud. Max gas 2128U. PUW 174K, SOW 66K, ROTW 111 K. Pump tandem sweep at 9.882', 25% increase on time.;At 10,130' observe losses with It'\/initial rate at 70 bpm, slow pump rate to 400 gpm, start increasing background LCM to 25 ppb, pump 25 bbls sweep with 40 ppb calcium carbonate. Losses decrease to 25 bph.;Drill ahead 8.5" Hole F110,360'to 10,801' MD. 441'total (73.5 AROP) flow 40011200psi to 450 gpm/1431 psi, 120-140rpms22k ft-Ibs . C WOB 6-110K. ECD 10.5 ppg EMW with 9.4 ppg mud. Max gas 1846U. PUW 171K, SOW 56K, ROTW 111 K. Pumped tandem sweep at 10752' with 100% increase on time.;Loss rate 25 bph. Crossed a fault at 10,717' with 11'throw into the OA-2 sands ;Drill ahead 8.5" Hole F/10,801'to 11,051' MD. 250'total (100' +7' AROP) flow 500gpm/1600psi, 130rpms22k ft-lbs. WOB 6-10K. ECD 10.65 ppg EMW with 9.4 ppg mud. Max gas 1567U. PUW 176K, SOW 61 K, ROTW 111 K. Entered OA-1 sands at 10,944 and exited at 11,02T. OA-1 sands appear to be thinner than;expected with the dip possibly flattened out. Loss rate 20 )�A bph.;Circulate hole clean 500gpm/1600psi, 130 rpms/22Kft-Ibs reciprocating pipe Discuss sidetrack options. Pump out of hole to 10,900'.;Sidetrack hole from 10,900'to 10,956' S50gpm/1900psi, 150rpms/22Kft-Ibs, WOB 1-7K, initial ROP 30 fph building to 1401ph as we gain separation. Initial deflection 100% at 161'. Observe immediate departure of wellbore based on ABI. Work through sidetrack x3 with no issues going into new hole.;Loss rate 15-20 bph.;17 concretions drilled for a total of 120', 4.0% of lateral 3 fault crossed; 8110% 9864', 10,717' 804' Drilled so far in OA-1, 423' in OA-2, 1,461' in OA-1 PB1 from 10,909to 11,051' Distance to WP#9 14.35'; 14.3' low, 1.2' right;Hauled 693 bbls Fluid to MP G&I total = 9,975 bbls Hauled 520 bbls H2O from L-Pad Lake total = 11080 bbls Lost 195 blots to formation total fluid lost = 195 bbls 1/21/2019 06118.5" Production Hole F/10,956'to 11,428' MD. 472'total (79' AROP) flow 510/1735psi, 130rpms/22k ft -lbs . WOE 8-12K. ECD 10.68 ppg EMW with 9.4 ppg mud. Max gas 1647U. PUW 155K, SOW 63K, ROTW 107K.;Drill 8.5" Production Hole F/11,428! to 11,998' MD. 570'total (114' AROP) flow 490/1730psi, 140rpms/22.7k ft -lbs . WOB 6-8K. ECD 10.9 ppg EMW with 9.4 ppg mud. Max gas 1802U. PUW 163K, SOW 55K, ROTW 108K. Pump tandem sweep at 11,510' with 50% increase in cuttings back on time.;Pump tandem sweep (25% on time) and circulate hole clean 520 gpm/1910psi, 140 rpms/22Kft-lbs ECO's lower from 10.9 ppg to 10.72 ppg.;Drill 8.5" Production Hole F/11,998'to 12,127' MD. 129'total (86' AROP) flow 520/1600psi, 140rpms/23k ft -lbs . WOB 6-8K. ECD 10.7 ppg EMW with 9.4 ppg mud. Max gas 844U. PUW 163K, SOW 55K, ROTW 108K. Pump tandem sweep at 11,510' wfth 50% increase in cuttings back on time.;Observe 350 psi loss in pump pressure, trouble shoot surface equipment, MWD pulser lost RPM, slow pump rates 60 psi lower. Continue circulating annular volume at 500 gpm ICP 1340 psi, FCP 1280 80 rpms/18Kft-Ibs.;Blow down top drive. Monitor well, slight flow going static in 15 minutes. Pump out of the hole at 2bpm/220 psi to 10,948' with 5-15K drag. Continue POOH on elevators to 10,828' observe washout in drill pipe. UD bad joint and replace.;Establish circulation and work up to 500 gpm/1740psi - same pressure/rate at this depth while drilling. PUW165K, SOW 74K.;PJSM. RIH from 10,828' to 12,127 with 5-10K drag no issues. Wash last stand to bottom at 3bpm/400 psi.;Drill 8.5" Production Hole F/12,127' to 12,351' MD. 224'total (56' AROP) flow 510/1880psi, 140rpms/22K ft -lbs . WOB 6-15K. ECD 10.9 ppg EMW with 9.4 ppg mud. Max gas 1640U. PUW 165K, SOW 60K, ROTW 109K. Pump tandem sweep at 12,185' (0% increase 15 bbls late).;Slow ROP to 125 fph and backream allowing sweep to exit the hole. Loss rate 12-15 bph.;22 concretions drilled for a total of 148', 3.5% of lateral 3 fault crossed; 8110% 9864', 10,71 T 1731' Drilled so far in OA -1, 803' in OA -2, 1564' in OA -3 PB1 from 10,900'to 11,051' Distance to WP#9 14.64'; 10.73' low, 9.96' right;Hauled 346 bbis Fluid to MP G&I total = 10,321 bbls Hauled 740 bbls H2O from L -Pad Lake total = 11820 bbls Lost 155 bbls to formation total fluid lost = 350 bbls 122/2019 Drill 8.5" Production Hole F/12,351'to 12,755' MD. 404'total (6T AROP) flow 510/1930psi, 140rpms/24K ft -lbs. WOB 6-10K. ECD 11.04 ppg EMW with 9.4 ppg mud. Max gas 2087U. PUW 163K, SOW 0, ROTW 109K.;Drill 8.5" Production Hole F/12,775'to 13,105' MD. 330'total (73' AROP) flow 510/1930psi, 140rpms/24K Nibs. WOE 4-81(. ECD 11.0 ppg EMW with 9.4 ppg mud. Max gas 1415U. PUW 167K, SOW 0, ROTW 108K. Pump tandem sweep at 12,762'. (Back on time w25% increase).;At 13,030' see 1 DO psi pressure loss. Drill ahead while inspecting surface equipment.;CBU while working pipe f/13,073' - 13,010'. 450 gpm/1460 psi, 60 rpm/18.8 Tq, ECD 10.8, BU gas @ 900u ;PJSM Monitor well, initial flow rate 22.5 bph, static after 20 Min. Pump out of hole F/ 13,073'tD 12,751' MD. 30 FPM, 85 GPM, 310 PSI, locate hole at 12,78T MD (Std 199) UD Jnt. P/U 175K, SLK 63K.;Break Circ. at 12,751' MD and compare previous pump Press. Pumped at 550 GPM, 1,975 PSI, 60 RPM, TRQ 15K, P/J 165K, SLK 35K, ROT 108K.;Wash and ream F/ 12,751'to 13,105' MD 510 GPM,1,965 PSI, 80 RPM, TRQ 14.7K.;Drill 8.5" Production hole F/ 13,105'to 13,389' MD ( 4,360' TVD) 284' Total (113' AROP) 450-510 GPM, 2,040 PSI, 140 RPM, TRQ 25K, WOE 5-10K, ECD 11.1 ppg. P/U 162K, SLK 40K, ROT 108K. Loss rate 20 bph. Total lost for tour 174 bbls. Max Gas 1,963U.;SPR at 13,105'(4.366 TVD) W/ 9.4 ppg MW MP#1 32-385 PSI, 48-430 PSI MP #2 32-360 PSI, 48-435 PSI.;Drill 8.5' Production hole F/ 13,389 to 13,845' MD ( 4,363' TVD) 456' Total (76' AROP) 450-510 GPM, 1,795 PSI, 140 RPM, TRQ 26K, WOB 8-14K, ECD 11.0 ppg. P/U 164K, SLK 36K, ROT 110K. Loss rate —24 bph. Max Gas 2,222U.;SPR at 13,639' (4,639' TVD) W/ 9.4 ppg MW MP#1 32-345 PSI, 48-425 PSI MP#2 32-345 PSI, 48-420 PSI.;Distance to WP#9 16.52'; 16.2' low, 3.21' right.;41 concretions in the mother bore for a total thickness of 252' (4.4% of the lateral). 4 fault crossed; 8110', 9864', 10,717', 13,360' 1840' Drilled so far in OA -1, 978' in OA -2,740' in OA -3 PBI from 10,900'to 11,051';Hauled 231 bbls Fluid to MP G&I total = 10,552 bbls Hauled 450 bbls H2O from L -Pad Lake total = 12,270 bbls Lost 348 bbls to formation total fluid lost = 698 bbls 123/2019 Drill 8.5" Production hole F/ 13,846 to 13,890' MD 4,363' TVD) 45' Total (90' AROP) 470 GPM, 1,790 PSI, 120 RPM, TRQ 27K, WOB 8K, ECD 10.89 ppg. PIU 164K, SILK 36K, ROT 110K. Loss rate —2-4 bph. Max Gas 1,780U.;Blow down Top Drive and C/O air boot on riser.;Drill 8.5" Production hole F/ 13,899to 13,944' MD ( 4,364' TVD) 54' Total (54' AROP) 450 GPM, 1,685 PSI, 120 RPM, TRQ 26.51K, WOB 8-10K, ECD 10.89 ppg. P/U 164K, SLK 36K, ROT 110K. Loss rate —2-4 bph. Max Gas 1,887U.;SPR @ 13,944' MD (4,364' TVD) MW 9.6 ppg MP #132-320 PSI, 48-390 PSI MP #2 32315 PSI, 48-385 PSI.;CBU 3X increase mud weight to 9.65 ppg. 550 GMP, 2,300 PSI, 140 RPM TRQ 24K, P/U 164K, SLK 60K, ROT 110K. Max Gas 3501-1. ECD 11.0 ppg. Shut down and monitor well, static. Losses for tour 25 bbls.;PJSM BROOH F/ 13,944'to 11,811' MD 510 GPM, 1,755 PSI, 120 RPM, TRQ 18-21 K, Max Gas 607U. P/U 155K, SLK 63K, ROT 109K. Max pulling speed 40 FPM.;PJSM BROOH F/ 11,81 V to 9,223' MD 510 GPM, 1,645 PSI, 120 RPM, TRQ 10.41K, Max Gas 141 U. P/U 140K, SLK 84K, ROT 107K. Max pulling speed 40 FPM.;PJSM BROOH F/ 9,223'to 8,013' MD 510 GPM, 1,645 PSI, 120 RPM, TRQ 9.51K, Max Gas 292U. PN 140K, SLK 84K, ROT 111 K. Max pulling speed 40 FPM. Observed no over pull going through shoe, very clean. Dynamic loss rate —8 bph. Lost 36 bbls.;Rotate and reciprocate F/ 8,013'to 7,952' MD Pump Hi Vis Sweep 300 Vis and CBU 2X. 510 GPM, 1,628 PSI, 120 RPM, TRQ 8.1 K. P/U 142K, SLK 97K, ROT I 08 Sweep back on time with no Increase at Shakers. Dynamic loss rate 2 BPH.;Distance to W P#9 29.26'; 29.02' low, 3.71' right.;47 concretions in the mother bore for a total thickness of 275' (4.7% of the lateral). 4 fault crossed; 8110', 9864', 10,717', 13,360'. 1840' Drilled so far in OA -1, 978' in OA -2,889' in OA -3. P61 from 10,900'to 11,051'.;Hauled 231 bbls Fluid to MP G&I total = 10,783 bbls Hauled 360 bbls H2O from L -Pad Lake total = 12,630 bbls Lost 108 bbls to formation total fluid lost = 806 bbls n Well Name: MP E-37 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): 26.2 API 9: Hilcorp Energy Company Composite Report Spud Date: 1/3/2019 Job Name: 1813044C MPE-37 Completion Contractor Innovation AFE #: AFE $: e W .... - Ops Summary 1/24/2019PJSM Slip and cut drilling line. Cut 50'. Check brakes.,PJSM Monitor well for 15 Min. 0.75 BPH static loss. POOH on elevators racking back in Derrick F/ 8,013' to 5,893' MD. Pull 5 stands W/ no swabbing. Pump 25 bbl 11.1 ppg Dry Job. Drop 2.39" Rabbit down D.P.,Safety stand down to discuss incident at Doyon 14. PJSM for laying down 5" D.P ... POCH UD 5" D.P. F/ 5,893' to 4,729' MD. Calculated displacement 9.2 bbls, actual 16.5 bbls. Lost 7 bbis. Losses for tour 48 bbls.,Safety stand down to discuss incident at Doyon 14. Perform hazard hunt throughout the rig.,PJSM POOH UD 5" D.P. F/ 4,729' to 299' MD. Calculated displacement 39 bbls, actual 56.4 bbls. Lost 24.3 bbis. Static loss rate 1 BPH.,PJSM for UD BHA. UD BHA #3 as per MWD and DD. Down load Halliburton tool. 8.5" Bit in gauge. Grade 1 -1 -NO-A-X-I-NO-TD. Static loss 2 BPH. Lost 53 bbls for tour.,Service Rig, grease Crown, Blocks, Top Drive and Wash Pipe.,PJSM W/ all parties for R/U and running 6 5/8" Liner. P/U R/U Power Tongs, 145 Centralizers, P/U M/U Safety Joint W/ Triple Connect. Fix broken safety wire on Grabber Box. Static loss 2 BPH.,Hauled 58 bbis Fluid to MP G&I total = 10,841 bbis Hauled 130 bbis H2O from L -Pad Lake total = 12,760 bbis Lost 101 bbls to formation total fluid lost = 907 bbls 1/25/2019 PJSM. Make up shoe track; round nose float shoe, WIV, drillable packoff. RIH with 6-518" 20# L-80 Wedge 563 pre -drilled liner to 6014" as per tally installing centralizers on every joint. PUW 120K, SOW 76K. Cale. Dis. 10.8 bbis, Actual 6.6 bbls. Lost 4.2 bbls.,Rig up False rotary and 3.5" Handling Equip. Change safety joint for 3-1/2" inner string with triple connect. Remove excess equipment from Rig Floor. Static loss rate 1.2 BPH.,Wait on Baker to expedite False Bowl Plate from Deadhorse. Plate onsite slightly to small for a secured use, it was a 16" and needed to be 18".,PJSM P/U M/U Slick Stinger Assy W/ No -Go as per BOT onsite. RIH W/ 3.5" EUE 9.3#, L-80 Tubing to 5,036' MD. P/U 67K, SLK 52K. M/U Torque 3,200 ft/Ib. Calc. Disp. 16, actual 4.3 bbis. Lost 40 bbis for tour.,PJSM RIH W/ 3.5" EUE 9.39, L-80 Tubing to 5,974' MD. P/U 67K, SLK 52K. M/U Torque 3,20011/16. Calc. Disp. 16, actual 4.3 bbls.,Pick up Jnt 184 and tag No -Go 27.5'. UD Joint 184, PIU 2 as 10' Pups for space out. Putting Slick Stinger 7.5' in Pao Ofl.,PJSM W/ all parties for P/U Packer. P/U WU SLZXP to 3.5" Tubing W/ P/U 77K. R/D false table and UD 3.5" Weatherford Power Tongs. P/U 6 5/8" Power Tongs. M/U SLZXP to 6 5/8" Liner. RIH SLZXP Packer and 6 518" Liner W/ 1 stand 5" D.P. Pump through inner string 60 bbls at 5 bpm, 590 PSI. P/U 152, SLK 107K.,RIH 6 5/8" Liner W/ 5" D.P. from Derrick F/ 6,053'to 6,369' MD. Static loss 2 BPH -Hauled 57 bbis Fluid to MP G&I total = 10,898 bbls Hauled 0 bbls H2O from L -Pad Lake total = 12,760 bbis Lost 54 bbis to formation total fluid lost = 961 bbls 1/26/2019 RIH on elevators with 6 5/8" Liner on 5" D.P. from Derrick F/ 6,369' to 8,000' MD.,CBU @ the Shoe, stage pumps to 8 bpm/1120 psi. Pumped 313 bbls and lost 7.3 bbls on circulation. Obtain parameters @ 4 bpm/515 psi, 10 rpm/12k Tq, 157k PUW, 97k SOW, 123k Rot.,RIH on elevators with 6 5/8" Liner on 5" D.P. from Derrick F/ 8000' to 9525' MD, filling pipe and breaking circulation every 20 stats DP. No issues running to 9525'. PUW 168k, SOW 92k., PJSM RIH on elevators with 6 5/8" Liner on 5" D.P. from Derrick F/ 9525' to 10,650' MD, filling pipe and breaking circulation every 20 stele DP, 85 GPM, 345 PSI. Rabbit D.P. out of Derrick W/ 2.75" Drift. P/U 170K, SLK 72K.,CBU Reciprocate F/ 10,605'to 10,650' MD. Stage pumps up to 6.5 GPM, 970 PSI, Obtain rotation parameter at 8 RPM, TRQ 15K while working pipe. Max Gas 270U. Blow Down Top Dnve.,RIH on elevators with 6 5/8" Liner on 5" D.P. from Derrick F/ 10,650' to 12,17T MD, filling pipe and breaking circulation every 20 stds DP, 85 GPM, 345 PSI. Rabbit D.P. out of Derrick W/ 2.75" Drift. P/U 177K, SLK 73K.,Cont. RIH on elevators with 6 5/8" Liner on 5" D.P. from Derrick F/ 12,177' to 13,818' MD, Wash down F/ 13,818' to 13,942' MD. Stage pump up to 4.5 BPM, 700 PSI. Work down last stand W/ minimal SOW, start rotation at 6-8 RPM, TRQ 15K. Release TRQ and pull string into tension P/U 183K, SLK 36K. TOL @7,899' MD. Shoe at 13,492' MD.,CBU staging pumps up to 6.5 BPM, 1,000 PSI. Max Gas 482U.,PJSM W/ all parties for displacement. Displace 9.65 ppg Mud W/ 9.7 PPG Brine. Pump 40 bbl Hi Vis Sweep, chase with 380 bbis 9.7 ppg Brine at 6 BPM, 1,050 PSI. Sweep back 80 bbls late. Pump 3 as 40 bbl SAPP Pills at 5 BPM, 920 PSI. Dumped Chem train 248 bbis. Good 9.7 ppg in and out.,Monitor well for 10 Min, static. Drop 1.25" Ball down 5" D.P. Pump Ball down to WIV at 3 BPM, 287 PSI, slow to 1 BPM Ball seated at bbis away.,Pump 1.25" Ball down to WIV at 3.5 BPM, 340 PSI for 145 bbis. Slow pumps to 1.5 BPM, 84 PSI, Ball seated at 162 bbls away. Pressure up to 2,900 PSI for Pusher tool, increase Press to 3,400 PSI for 5 Min. Slack off F/ 165 K to 80K ensure Packer set. Pressure up to 4,400 PSI to release HRD running tool. Bleed down Press. All charted and witnessed by Baker and CO Rep.,Hauled 575 bbis Fluid to MP G&I total = 11,473 bbis Hauled 130 bbis H2O from L -Pad Lake total = 12,890 bbis Lost 69 bbis to formation total fluid lost = 1030 bbis 1/27/2019 P/U to release F/ Packer, broke over at 156K. PJSM for testing. Test SLZXP Packer to 1,700 PSI for 10 Min on chart witnessed by Co Rep onsite. R/D test Equip.,Break Circ. at 5 bpm, 510 PSI. Circ. Surf to Surf to displace inner annulus to 9.7 ppg Brine. Monitor well for 10 Min, static.,PJSM. POOH 5" D.P. and 3.5" racking back 5" D.P. in Derrick F/ 13,864'to 12,160' MD. P/U 153K.,PJSM Cont. POOH 5" D.P. racking back in Derrick F/ 12,160'to 5,974' MD. P/U 74K. Calc Disp. 50 bbis, actual 47 bbis. Lost 3 bbls. Static loss about 1 bph.,PJSM for UD Tubing. R/U Weatherford Power Tongs. POOH UD Liner running tool. P/U Safety Joint and break down Triple Connect, TIW and X/O. POOH LID 3.5" Tubing 5,974' to 4,713' MD. P/U 65K.,PJSM for POOH racking back in Derrick. Decision was made to rack back 3.5" Tubing due to BOPE test. POOH rack back 3.5" Tubing F/ 4,713' to surface. UD Slick Stinger.,PJSM Drain Stack, pull Wear Bushing. M/U Test Equip. Set test plug. Fill Stack and Choke Manifold W/ H2O and purge air. Test BOPE W/ 3.5" & 5" test joint. Test Press. 500 PSI low and 3,000 PSI high.,Tested Annular, Choke valves 1-15, 2 718!'X 5 1/2" Variable Upper and Lower Pipe Rams, TIW, Dart, Kill and Choke HCR, manual HCR and Choke, Super and Manual Choke, Blind Rams. Upper and lower IBOP.,Perform Kearney draw down, initial starting Press. Manifold 1,400 PSI, Accumulater 1,500 PSI, Annular 1,425 PSI, after function Manifold 1,550 PSI, 2,900 PSI, Annular 1,425 PSI. 200 PSI increase in 26 Sec, full charge 104 Sec. 6 bottles Nitrogen average 2,383 PSI. Witnessed waived by AOGCC Rep Guy Cook.,Hauled 1,860 bbls Fluid to MP G&I total = 13,333 bbis Hauled 260 bbis H2O from L -Pad Lake total = 13,150 bbis Lost 88 bbls to formation total fluid lost = 1118 bbis 1128/2019 RID ROPE test Equip. LID 3.5" test joint. Pull test plug and set Wear Bushing. RILDS.,Sewice rig, grease Crown, Top Drive, Blocks and Swivel Packing.,PJSM for RIH W/ 3.5" Tubing. RIH 3.5" Tubing from Derrick W/ Weatherford M/U Mule and RIH to 4,681' MD. P/U 62K, SLK 50K.,PJSM for POOH. POOH laying down 3.5" Tubing W/ Weatherford F/ 4,681' MD to surface. Calculated hole fill 13.8 bbls, actaul 29.1 bbls. Lost 15.5 bbls. Static loss rate 2 bph.,PJSM for RID Weatherford. RID Weatherford 3.5" handling Equip. R/U 5" D.P. handling Equip. Prep Rig floor for RIH. Static loss rate 2.8 bph.,PJSM P/U WU 3.5" Stinger and 8.375" No-Go. RIH from Derrick 5" D.P. to 7,895' MD. Calc. Disp. 53.2 bills, actual 50.4 bills. Lost 2.8 bbls. P/U 154K, SLK 92K.,RIH F/ 7,895' observed no drag in liner top. Tag TOL W/ No-Go at 7,895.50' MD verify tag W/ 5K down. Rack back one stand.,Wash out Liner top at 8 bpm, 325 PSI. POOH pumping from Mule Shoe at 7,919' to 7,856' MD, rack back one stand 5" D.P. Cont. CBU at 8 bpm, 300 PSI. Monitor. Dynamic loss rate 5 bph, lost 8 bbls.,PJSM for laying down D.P. POOH laying down 5" D.P. F/ 7,856'to 5,287' MD. P/U 125K, SLK 75K. Calc. Disp 17.3 bbls, actual 30 BBLS. Lost 12,6 bbis. Static loss rate 4 bph.,Hauled 57 bbls Fluid to MP G&I total = 13,390 bbis ylb�� /A•..� Hauled 0 bbis H2O from L-Pad Lake 13,150 bbis total = Total completion fluid lost 189 bbis Lost 101 bbis to formation total fluid lost = 1,438 bbis 1/29/2019 POOH laying down 5" drillpipe f/ 528T - 61'. RIH w/ 4 stands drillpipe from Derrick and finish pull out of hole laying the drillpipe down to pipe shed.,Pull wear bushing, LID pulling tool and clean rig floor., Drain stack, close blind rams, bleed down accumulator system and change out 2-7/8" X 5-1/2" VPR to 7-5/8" solid body rams., PJSM, WU test jt to test plug and set in wellhead. Test 7-5/8" Rams to 250psi Low / 3000psi High. Good Test. Rig down.,Pull lest plug, a little difficulty pulling the test plug as the rubber seals were hanging up in cavities of the multibowl, remove test plug and lay down test jt.,PJSM, Rig up Weatherford handling equipment - Tongs, slips & elevatom.,PJSM, P/U landing jt & hanger, perform dummy run t/ verify fit & RKB measurements.,Finish rigging up power tongs. Verify jt count in shed - 198 jts -. Hold PJSM with crew and third parties on running casing. Rig up and run torque turn, set at optimal tq for W521 of 10.1k ft/lbs.,PJSM with all parties involved, review plan for well control. P/U tie back seal assy, NOGO locator, XO and pup, WU to jt of 7 5/8" Wedge 521, 29.7# L-80 casing. Verify with Weatherford town supervisors that the torque curves obtained with first connections are acceptable prior to continuing in hole. Tq U10.1 k. P/U and run 7 5/8" tie back per tally t/ 2804'. Calculated displacement 29.68 bible, actual 11.9 bbis., Pumped 20bbl, 10ppg Brine dry job @ 2000' MD to stop flow out of pipe while RIH. Did not help, so adjust running speed to minimize fluid coming out of pipe.,Continue RIH with 7 5/8" Wedge 521, 29.79 L-80 w/ Tie Back assembly from 2804' to 6157'. P/U - 165K, S/O - 102K. Calculated displacement 55.1 bills, actual 23.1 bbls.,Hauled 57 bbls Fluid to MP G&I total = 13447 bbls Hauled 0 bbls H2O from L-Pad Lake total = 13150 bbis Total completion fluid lost 266 bbis Lost 77 bbis to formation total fluid o = 1515 bbls 1/3012019 Continue Run 7-518" 29.7# L-80 Wedge 521 tieback F/ 6 157'- T/ 7,857' MD. 190k up, 107k dn. 44 bbl loss for trip.,Tag up @ 40.T Qt #197) on depth TOL (7898' MD) w/ 10k dn. Observed 4k drag from seals. P/U Send re-tag with same parameters and results. POOH and replace jt #194 with jt # 197. Runback in with jts 195, 9.9' pup then jt #196. WU hanger assy w/ landing jt. RIH and landout on depth 1.55' off No Go (Seal assy mule shoe @ 7905.85' MD).,Reduce annular psi to 650 psi and close same. Psi up 300 on annulus and hold 5 min (good), bleed off. R/U to reverse circulate through side port entry sub back to mud manifold. Psi up to 300 on 7-5/8" x 9-5/8" annulus. Strip up 6.5' and observe psi drop when seals clear bore assy continue strip up a total of T-Reverse circulate 101 bbis corrosion inhibited 9.7 brine (4 bpm,260 psi), chase w/ 10 bbis 9.7 brine, FP w/ 50 bbis diesel (1.5 BPM, 310 psi), chase with 10 bbis 9.7 brine. 25 bbl loss during circulation. Strip down (70k do w/ bag closed) and landout on depth on hanger. 73k string wt on hanger. Bled back 1 bbl then went static. Open annular and RID circ equipment. RID WOT csg tools.,L/D landing jt. M/U packoff running tool and packoff. RIH and set packoff. RILDS. Test void 500/5000 w/ 5/15 min hold (good). SIMOPS - Load 2-7/8" tbg in shed. Stage spooling unit for ESP and power up.,R/U and test 7-5/8" x 9- 5/8" annulus. PIT 1000 psi w/ 30 min hold (test good). Chart and record same. 1 bbl pumped and 1 bbl bled back. Used test pump., Drain stack, shut blind rams and bleed accumulator pressure down. C/O UPR f1 75/8" to 2-718" X 5-1/2" variable rams. Re-energize accumulator pressure and open blind rams. SIMOPS - Start processing 2-718" completion string in pipe shed., Rig up and test upper and lower variable pipe rams at 250psi Low / 3000psi High & Annular preventer at 250psi Low / 2500psi High. Rig down test equipment.,Mobilize WOT tubing handling equipment to rig floor. Mobilize BOT ESP handling equipment to rig floor.,Rig up to run ESP completion. R/U WOT equip. Hang Sheave for ESP cable. Thread ESP cable and 2-3/8" capillary lines thru sheave to rig floor. Load ESP tools and equipment to rig floor. Static loss rate 3.2 bph.,P/U M/U 5.85" Centralizer, Zenith Sensor, XP250 Motor, Lower and Upp Tandem Seals, Dual Gas Separator, 2 ea 134 Flex 17.5 SXD Pumps, Discharge Head and 10'2-7/8" Pup as per Baker Centrilift Rep onsite. Attach MILE Pothead to Motor Assy and 3/8" SS CAP line. 3 Motor Clamps, 2 Seal Clamps and 8 Pump Clamps.,Hauled 0 bbls Fluid to MP G&I total = 13447 bbls Hauled 100 bbis H2O from L-Pad Lake total = 13250 bbis Total completion fluid lost 356 bbls Lost 90 bills to formation total fluid lost = 1605 bbls 1/31/2019 Continue RIH w/ 2-7/8", 6.5#, L-80 EUE 8rd ESP completion string as per detail F/ 99'- T/ 1814' MD. ESP continuity test @ 1130' MD (Test good). "XN" nipple installed between #41 & #42. Installed GLM w/ dummy valve between 943 & #44. S/O 44k.,Continue RIH w/ 2-7/8", 6.5#, L-80 EUE 8rd ESP completion string as per detail F/ 1814' - T/ 4860' MD. ESP continuity test @ 3090'& 4860' MD (Test good). SIO 49k. Hole taking 4-6 bph 9.7 brine while running pipe.,Continue RIH w/ 2-7/8", 6.59, L-80 EUE 8rd ESP completion string as per detail F/ 4860' - T/ 7696' MD. ESP continuity test @ 6636' & 7696' MD (Test good). Installed DPSOV GLM between jts #253 & #254. S/O 51k. Hole taking 34 bph 9.7 brine while running pipe.,Continue RIH w/ 2-7/8", 6.5#, L- 80 EUE 8rd ESP completion string as per detail F/ 7696- T/ 7728' MD. Rig up & pump to clear any debris, 10 bills pumped @ 1 BPM w/ 600psi. MU Tubing Hgr and landing joint. Centrilift splice ESP. Terminate control lines. Make test on cables. Test good. Drain stack. Land Hanger, RILDS, LID Landing Joint & install BPV.,Bottom of Centralizer @7758'. Pump set @ 7717'-7669'. Up Wt 80K w/Blocks, Dn Wt 52K w/Blocks. 256 its 2 7/8" 6.5# L-80 EUE tubing ran. 262 Canon Clamps used, 3 motor clamps, 2 Seal clamps, & 8 pump clamps., Rig down BOT & Weatherford equipment, remove sheave from Derrick, clean rig floor.,Hauled 57 bbis Fluid to MP G&I total = 13504 bbls Hauled 100 bbis H2O from L-Pad Lake total = 13350 bbls Total completion fluid lost 480 bbis Lost 124 bbls to formation total fluid lost = 1729 bbls 2/1/2019 Continue rig down BOT cantrilift equipment. Clean and clear rig floor. R/U 5" handling equipment and function test same (good). Make up Johnny whacker and flush stack. Vac out stack for N/D. Load shed w/ 260 Its 5" new drill pipe., N/D BOP stack. Bleed down and isolate koomey. Disconnect lines and cap same. Remove riser, choke and kill lines. Install surface flanges on choke and kill. Rack back BOP stack and secure same on stump.,Clean and install tbg adapter. Test hanger void 500/5000 psi w/ 5/15 min hold on each (test good). Witnessed by Shane Barber. Remove swab and production valve. Install 1502 tree cap. Pull BPV and install TWC. Swap to Gen power @ 17:OO,Bridle up and scope down Derrick. Take apart both mud pumps, start clean pits system. Continue processing 5" DP in shed.,PJSM. R/U LRS to Tree and test same to 300/5000 psi, Test Good. Pull TWC and install BPV. Line up LRS on IA, PT lines to 3000 psi and bullhead 95 bbis diesel down the 2 7/8" X 7 5/8" Annulus at 2 BPM. ICP - 450 PSI. FCP - 810 PSI. Swap over to top of Master Valve and PT lines to 3000 PSI. Bullhead 15 bbis down 2-7/8" tubing at 1 BPM. ICP - 1300 PSI, FCP - 1775 PSI. Shut in Pres - 150 PSI. Rig down LRS,Pressure wash tree and cellar box. Prep for rig move, lift stompers, chip ice and snow around stompers, raise out riggers, get all stairs ready for lifting up, finish clean all pits, blow down water, freeze protect test pump, start taking off drag chain paddles, start disconnecting mez interconnect. Rig released 00:00.,Hauled 157 bbis Fluid to MP G&I total = 13661 bbis Hauled 0 bbis H2O from L-Pad Lake total = 13350 bbis Total completion fluid lost 480 bible Lost 0 bbls to formation total fluid lost = 1729 bbls Hilcorp Milne Point M Pt E Pad MPU E-37 500292361600 Alaska, LLC Sperry Drilling Definitive Survey Report 28 January, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-37 Project: Milne Point TVD Reference: MPE-37 Actual RKB @ 48.48usft Site: M Pt E Pad MD Reference: MPE-37 Actual RKB @ 48,48usft Well: MPU E-37 North Reference: True Wellbore: MPU E-37 Survey Calculation Method: Minimum Curvature Design: MPU E-37 Database: NORTH US + CANADA rroject Milne Point, ACT, MILNE POINT Asp System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Asp Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-37 Well Position +N/ -S +E/ -W Position Uncertainty Wellbore MPU E-37 Magnetics Model Name 0.00 usft Northing: 6,016,180.37 usfl 0.00 usft Easting: 569,388.31 usfl 0.00 usft Wellhead Elevation: 0.00 usfl Sample Date Declination (I BGG M2018 11/20/2018 16.97 Design MPU E-37 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +NIS (usft) (usft) 26.78 0.00 Latitude: 70° 27' 16.412 N Longitude: 149° 26'1,542 W Ground Level: 21.70 usft Dip Angie Field Strength (°) (nT) 80.98 57,447.94327777 Tie On Depth: 10,854.21 +EI -W Direction (usft) (°) 0.00 295.95 Survey Program Date 1/23/2019 From To (usft) (usft) Survey (Wellbore) Toot Name Description Survey Date 102.00 226.00 MPU E-37PB1 Surface Gyro (MPU E-37 2_Gym-NS-GC_Drill cell: H029Ga: North seeking single shot in drill colla 12/26/2018 291.29 8,026.96 MPU E-37PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/04/2019 8,077.74 10,854.21 MPU E-37PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/21/2019 10,900.00 13,875.59 MPU E-37 MWD+IFR2+MS+sag (3) (MP 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/21/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (1 (°) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 26.78 0.00 0.00 26.78 -21.70 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 UNDEFINED 102.00 0.44 107.29 102.00 53.52 -0.09 0.28 6,016,180.29 569,388.59 0.58 -0.29 2_Gyro-NS-GC_Dnll collar (I 164.00 0.57 94.32 164.00 115.52 -0.18 0.81 6,016,180.20 569,389.12 0.28 -0.81 2_Gym-NS-GC_Dnll collar (I 226.00 1.32 61.32 225.99 177.51 0.14 1.74 6,016,180.53 569,390.05 1.45 -1.51 2 -Gyro -NS -GC Drill collar(1 291.29 2.94 55.75 291.23 242.75 1.44 3.79 6,016,181.85 569,392.08 2.50 -2.78 2_MWD+IFR2+MS+Sag(2) 344.49 4.62 52.75 344.31 295.83 3.51 6.62 6,016,183.94 569,394.90 3.18 -4.42 2_MWD+IFR2+M8+Sag (2) 414.11 6.13 53.52 413.63 365.15 7.42 11.84 6,016,187.89 569,400.08 2.17 -7.40 2_MWD+IFR2+MS+Sag (2) 475.39 7.18 52.81 474.49 426.01 11.68 17.52 6,016,192.21 569,405.72 1.72 -10.65 2_MWD+IFR2+MS+Sag (2) 536.24 7.42 39.49 534.85 486.37 17.01 23.05 6,016,197.59 569,411.20 2.80 -13.29 2_MWD+IFR2+MS+Sag (2) 598.13 9.18 37.72 596.09 547.61 24.00 28.62 6,016,204.63 569,416.70 2.87 -15.23 2_MWD+IFR2+MS+Sag(2) 660.12 11.00 32.98 657.12 608.64 32.87 34.86 6,016,213.56 569,422.86 3.22 -16.96 2_MWD+IFR2+MS+Sag (2) 1282019 3:46.*14PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 Design: MPU E-37 Survey MD Inc Azi TVD TVDSS +NIS (usft) (°) (') (usft) (usft) (usft) 723.27 12.87 25.01 718.91 670.43 44.30 787.48 14.73 23.44 781.26 732.78 58.27 850.31 18.40 20.96 841.48 793.00 74.86 913.41 21.30 19.96 900.82 852.34 94.94 976.29 24.04 20.61 958.84 910.36 117.67 1,040.17 27.78 19.37 1,016.29 967.81 143.90 1,102.82 31.67 21.15 1,070.68 1,022.20 173.02 1,165.23 34.00 22.60 1,123.12 1,074.64 204.42 1,229.79 37.12 23.47 1,175.63 1,127.15 238.96 1,292.99 39.08 22.05 1,225.37 1,176.89 274.92 1,355.96 42.90 20.89 1,272.89 1,224.41 313.36 1,418.37 46.96 20.27 1,317.06 1,268.58 354.61 1,481.31 48.50 19.03 1,359.40 1,310.92 398.48 1,544.97 50.25 19.08 1,400.85 1,352.37 444.14 1,607.55 53.42 16.92 1,439.51 1,391.03 490.93 1,671.29 53.86 16.59 1,477.30 1,428.82 540.08 1,734.43 54.44 17.91 1,514.28 1,465.80 588.96 1,798.20 53.87 17.67 1,551.63 1,503.15 638.18 1,860.95 52.85 18.74 1,589.07 1,540.59 686.01 1,924.20 52.96 17.09 1,627.22 1,578.74 734.01 1,986.92 54.74 16.40 1,664.22 1,615.74 782.50 2,050.09 54.41 16.83 1,700.84 1,652.36 831.83 2,112.95 53.64 17.46 1,737.76 1,689.28 880.44 2,176.48 52.65 16.74 1,775.87 1,727.39 929.03 2,239.49 52.71 16.25 1,814.07 1,765.59 977.07 2,302.87 53.78 16.73 1,852.00 1,803.52 1,025.76 2,365.54 55.35 17.25 1,888.33 1,839.85 1,074.59 2,428.80 53.28 17.42 1,925.23 1,876.75 1,123.64 2,491.56 53.96 17.06 1,962.45 1,913.97 1,171.90 2,554.78 55.21 17.54 1,999.09 1,950.61 1,221.09 2,618.04 57.32 16.42 2,034.22 1,985.74 1,271.40 2,681.08 57.02 17.46 2,068.40 2,019.92 1,322.07 2,744.14 57.40 16.51 2,102.55 2,054.07 1,372.77 2,807.54 57.57 17.04 2,136.63 2,088.15 1,423.96 2,870.96 57.58 16.74 2,170.63 2,122.15 1,475.18 2,933.53 56.37 16.99 2,204.73 2,156.25 1,525.38 2,996.91 55.03 17.58 2,240.45 2,191.97 1,575.38 3,059.92 55.35 18.25 2,276.42 2,227.94 1,624.60 3,123.53 53.33 18.06 2,313.50 2,265.02 1,673.71 3,186.22 55.32 16.99 2,350.06 2,301.58 1,722.27 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA 17262019 3.,46:14PM Page 3 COMPASS 5000.15 Build 91 Map Map vertical +El -W Northing Easting DLS Section (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 41.11 6,016,225.05 569,429.01 3.94 -17.58 2_MWD+IFR2+MS+Sag (2) 47.39 6,016,239.07 569,435.15 2.95 -17.11 2_MWD+IFR2+MS+Sag (2) 54.11 6,016,255.73 569,441.72 5.95 -15.90 2_MWD+IFR2+MS+Sag (2) 61.59 6,016,275.87 569,449.01 4.63 -13.83 2_MWD+IFR2+MS+Sag(2) 70.00 6,016,298.67 569,457.20 4.38 -11.45 2_MWD+IFR2+MS+Sag (2) 79.52 6,016,324.99 569,466.48 5.92 -8.53 2_MWD+IFR2+MS+Sag(2) 90.30 6,016,354.21 569,476.99 6.37 -5.48 2_MWD+IFR2+MS+Sag(2) 102.92 6,016,385.72 569,489.31 3.94 -3.09 2_MWD+IFR2+MS+Sag(2) 117.62 6,016,420.39 569,503.69 4.90 -1.19 2_MWD+IFR2+MS+Sag(2) 132.69 6,016,456.49 569,518.42 3.40 0.99 2_MWD+IFR2+MS+Sag(2) 147.79 6,016,495.06 569,533.16 6.19 4.23 2_MWD+IFR2+MS+Sag(2) 163.27 6,016,536.46 569,548.26 6.54 8.36 2_MWD+IFR2+MS+Sag (2) 178.93 6,016,580.46 569,563.50 2.85 13.48 2_MWD+IFR2+MS+Sag (2) 194.70 6,016,626.27 569,578.85 2.75 19.28 2_MWD+IFR2+MS+Sag(2) 209.89 6,016,673.19 569,593.59 5.75 26.10 2_MWD+IFR2+108+8ag(2) 224.68 6,016,722.47 569,607.93 0.81 34.30 2_MWD+IFR2+MS+Sag (2) 239.86 6,016,771.48 569,622.65 1.93 42.04 2_MWD+IFR2+MS+Sag(2) 255.65 6,016,820.84 569,637.99 0.94 49.38 2_MWD+IFR2+MS+Sag(2) 271.38 6,016,868.81 569,653.26 2.12 56.17 2_MWD+IFR2+MS+Sag (2) 286.90 6,016,916.95 569,668.33 2.09 63.22 2_MWD+IFR2+MS+Sag(2) 301.49 6,016,965.57 569,682.47 2.97 71.32 2_MWD+IFR2+MS+Sag(2) 316.20 6,017,015.03 569,696.72 0.76 79.67 2_MWD+IFR2+MS+Sag(2) 331.20 6,017,063.77 569,711.26 1.47 87.46 2_MWD+IFR2+MS+Sag (2) 346.15 6,017,112.49 569,725.76 1.80 95.28 2_MWD+IFR2+MS+Sag (2) 360.38 6,017,160.66 569,739.54 0.63 103.51 2_MWD+IFR2+MS+Sag (2) 374.79 6,017,209.48 569,753.50 1.79 111.86 2_MWD+IFR2+MS+Sag (2) 389.71 6,017,258.44 569,767.96 2.59 119.81 2_MWD+IFR2+MS+Sag (2) 405.02 6,017,307.63 569,782.81 3.28 127.51 2_MWD+IFR2+MS+Sag(2) 419.99 6,017,356.02 569,797.33 1.18 135.16 2_MWD+IFR2+MS+Sag(2) 435.32 6,017,405.34 569,812.20 2.07 142.90 2_MWD+IFR2+MS+Sag (2) 450.67 6,017,455.79 569,827.08 3.65 151.11 2_MWD+IFR2+MS+Sag(2) 466.11 6,017,506.60 569,842.04 1.47 159.41 2_MWD+IFR2+MS+Sag (2) 481.59 6,017,557.44 569,857.05 1.40 167.67 2_MWD+IFR2+MS+Sag (2) 497.02 6,017,608.76 569,872.00 0.75 176.19 2_MWD+IFR2+MS+Sag (2) 512.57 6,017,660.12 569,887.08 0.40 184.62 2_MWD+IFR2+MS+Sag(2) 527.79 6,017,710.46 569,901.83 1.96 192.91 2_MWD+IFR2+MS+Sag(2) 543.35 6,017,760.59 569,916.91 2.25 200.80 2_MWD+IFR2+MS+Sag(2) 559.26 6,017,809.96 569,932.37 1.01 208.03 2_MWD+IFR2+MS+Sag(2) 575.37 6,017,859.21 569,948.01 3.18 215.04 2_MWD+IFR2+MS+Sag(2) 590.69 6,017,907.90 569,962.88 3.46 222.50 2_MWD+IFR2+MS+Sag(2) 17262019 3.,46:14PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-37 Project: Milne Point TVD Reference: MPE-37 Actual RKB @ 48.48usft Site: M Pt E Pad MD Reference: MPE-37 Actual RKB @ 48.48usft Well: MPU E-37 North Reference: True Wellbore: MPU E-37 Survey Calculation Method: Minimum Curvature Design: MPU E-37 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azl ND TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,249.34 55.10 17.98 2,386.07 2,337.59 1,771.71 606.27 6,017,957.48 569,978.00 1.33 230.14 2_MWD+IFR2+MS+Sag (2) 3,312.23 54.85 18.60 2,422.17 2,373.69 1,820.61 622.43 6,018,006.52 569,993.70 0.90 237.00 2_MWD+IFR2+MS+Sag (2) 3,375.86 54.07 19.25 2,459.15 2,410.67 1,869.59 639.22 6,018,055.65 570,010.03 1.48 243.33 2_MWD+IFR2+MS+Sag (2) 3,438.93 53.69 19.02 2,496.33 2,447.85 1,917.72 655.92 6,018,103.93 570,026.28 0.67 249.38 2_MWD+IFR2+MS+Sag (2) 3,501.95 54.75 18.89 2,533.18 2,484.70 1,966.07 672.53 6,018,152.43 570,042.44 1.69 255.61 2_MWD+IFR2+MS+Sag(2) 3,565.04 54.31 19.13 2,569.79 2,521.31 2,014.65 689.26 6,018,201.16 570,058.72 0.76 261.81 2_MWD+IFR2+MS+Sag(2) 3,628.07 53.52 19.61 2,606.91 2,558.43 2,062.70 706.16 6,018,249.37 570,075.16 1.40 267.65 2_MWD+IFR2+MS+Sag (2) 3,691.60 54.07 18.91 2,644.44 2,595.96 2,111.10 723.06 6,018,297.91 570,091.62 1.24 273.63 2_MWD+IFR2+MS+Sag (2) 3,754.95 54.63 18.31 2,681.36 2,632.88 2,159.88 739.49 6,018,346.84 570,107.59 1.17 280.20 2_MWD+IFR2+MS+Sag(2) 3,816.93 54.23 18.34 2,717.41 2,668.93 2,207.74 755.34 6,018,394.84 570,122.99 0.65 286.89 2_MWD+IFR2+MS+Sag(2) 3,880.77 53.41 19.30 2,755.10 2,706.62 2,256.52 771.96 6,018,443.76 570,139.15 1.77 293.29 2_MWD+IFR2+MS+Sag(2) 3,943.81 54.51 17.74 2,792.19 2,743.71 2,304.85 788.15 6,018,492.24 570,154.89 2.65 299.89 2_MWD+IFR2+MS+Sag (2) 4,007.20 54.87 18.96 2,828.83 2,780.35 2,353.95 804.43 6,018,541.48 570,170.71 1.67 306.73 2_MWD+IFR2+MS+Sag (2) 4,070.63 53.87 19.50 2,865.78 2,817.30 2,402.62 821.41 6,018,590.31 570,187.24 1.72 312.76 2_MWD+IFR2+MS+Sag (2) 4,134.00 53.49 20.17 2,903.32 2,854.84 2,450.65 838.74 6,018,638.50 570,204.11 1.04 318.20 2_MWD+IFR2+MS+Sag(2)M 4,196.70 54.73 17.41 2,940.08 2,891.60 2,498.74 855.09 6,018,686.72 570,220.01 4.08 324.54 2_WD+IFR2+MS+Sag(2) 4,260.27 54.33 18.10 2,976.96 2,928.48 2,548.04 870.87 6,018,736.17 570,235.33 1.09 331.92 2_MWD+IFR2+MS+Sag (2) 4,323.29 55.21 17.96 3,013.32 2,964.84 2,596.99 886.81 6,018,785.26 570,250.81 1.41 339.01 2_MWD+IFR2+MS+Sag (2) 4,386.10 55.40 16.37 3,049.07 3,000.59 2,646.33 902.04 6,018,834.74 570,265.59 2.10 346.90 2_MWD+IFR2+MS+Sag (2) 4,449.61 55.38 16.67 3,085.14 3,036.66 2,696.44 916.91 6,018,884.98 570,279.98 0.39 355.47 2_MWD+IFR2+MS+Sag(2) 4,513.04 55.53 17.39 3,121.11 3,072.63 2,746.40 932.21 6,018,935.07 570,294.82 0.96 363.57 2_MWD+IFR2+MS+Sag(2) 4,574.49 56.15 16.99 3,155.62 3,107.14 2,794.98 947.24 6,018,983.78 570,309.39 1.14 371.31 2_MWD+IFR2+MS+Sag(2) 4,638.85 54.88 17.58 3,192.06 3,143.58 2,845.63 963.00 6,019,034.57 570,324.67 2.11 379.31 2_MWD+IFR2+MS+Sag (2) 4,701.16 54.36 16.80 3,228.13 3,179.65 2,894.16 978.01 6,019,083.24 570,339.24 1.32 387.04 2_MWD+IFR2+MS+Sag (2) 4,764.80 54.91 15.00 3,264.97 3,216.49 2,944.07 992.23 6,019,133.27 570,352.98 2.46 396.10 2_MWD+IFR2+MS+Sag (2) 4,828.05 54.33 14.12 3,301.59 3,253.11 2,993.98 1,005.19 6,019,183.30 570,365.48 1.46 406.28 2_MWD+IFR2+MS+Sag(2) 4,891.28 53.54 15.78 3,338.82 3,290.34 3,043.36 1,018.37 6,019,232.80 570,378.20 2.46 416.04 2_MWD+IFR2+MS+Sag(2) 4,954.31 53.56 13.14 3,376.27 3,327.79 3,092.45 1,031.03 6,019,281.99 570,390.40 3.37 426.14 2_MWD+IFR2+MS+Sag (2) 5,017.05 53.48 13.17 3,413.57 3,365.09 3,141.57 1,042.51 6,019,331.22 570,401.42 0.13 437.31 2_MWD+IFR2+MS+Sag (2) 5,080.16 54.32 11.04 3,450.76 3,402.28 3,191.43 1,053.20 6,019,381.16 570,411.64 3.03 449.51 2_MWD+IFR2+MS+Sag (2)M 5,143.46 54.43 9.97 3,487.63 3,439.15 3,242.02 1,062.58 6,019,431.83 570,420.55 1.38 463.22 2_WD+IFR2+MS+Sag(2) 5,206.14 55.02 7.08 3,523.83 3,475.35 3,292.61 1,070.16 6,019,482.49 570,427.66 3.88 478.54 2_MWD+IFR2+MS+Sag(2) 5,268.70 55.39 4.04 3,559.54 3,511.06 3,343.74 1,075.13 6,019,533.66 570,432.16 4.03 496.44 2_MWD+IFR2+MS+Sag (2) 5,331.36 56.95 1.00 3,594.43 3,545.95 3,395.73 1,077.41 6,019,585.66 570,433.95 4.74 517.14 2 MWD+IFR2+MS+Sag (2) 5,395.51 56.47 358.81 3,629.64 3,581.16 3,449.34 1,077.32 6,019,639.27 570,433.36 2.95 540.68 2_MWD+IFR2+MS+Sag(2) 5,458.85 56.78 356.43 3,664.49 3,616.01 3,502.19 1,075.12 6,019,692.09 570,430.67 3.18 565.78 2_MWD+IFR2+MS+Sag (2) 5,522.35 55.56 354.78 3,699.84 3,651.36 3,554.78 1,071.09 6,019,744.63 570,426.15 2.89 592.43 2_MWD+IFR2+MS+Sag(2) 5,584.95 55.17 352.05 3,735.42 3,686.94 3,605.94 1,065.18 6,019,795.73 570,419.77 3.64 620.12 2_MWD+IFR2+MS+Sag (2) 5,647.87 54.56 348.85 3,771.64 3,723.16 3,656.67 1,056.65 6,019,846.37 570,410.77 4.27 649.99 2_MWD+IFR2+MS+Sag (2) 5,711.06 55.70 345.19 3,807.77 3,759.29 3,707.17 1,045.00 6,019,896.76 570,398.65 5.08 682.57 2_MWD+IFR2+MS+Sag(2) 1282019 3:46:14PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-37 Project: Milne Point TVD Reference: MPE-37 Actual RKB @ 48.48usft Site: M Pt E Pad MD Reference: MPE-37 Actual RKB @ 48.48usft Well: MPU E-37 North Reference: True Wellborn: MPU E-37 Survey Calculation Method: Minimum Curvature Design: MPU E-37 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (') (") (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 5,774.27 56.11 340.93 3,843.22 3,794.74 3,757.22 1,029.75 6,019,946.66 570,382.93 5.62 718.18 2_MWD+IFR2+MS+Sag(2) 5,837.44 58.07 338.80 3,877.54 3,829.06 3,807.00 1,011.49 6,019,996.27 570,364.21 4.20 756.39 2_MWD+IFR2+MS+Sag (2) 5,900.60 58.98 335.96 3,910.52 3,862.04 3,856.72 990.77 6,020,045.78 570,343.03 4.10 796.77 2_MWD+IFR2+MS+Sag (2) 5,964.03 61.18 333.60 3,942.16 3,893.68 3,906.44 967.33 6,020,095.28 570,319.13 4.74 839.60 2_MWD+IFR2+MS+Sag (2) 6,026.91 62.93 332.81 3,971.63 3,923.15 3,956.02 942.29 6,020,144.62 570,293.63 3.00 883.81 2_MWD+IFR2+MS+Sag (2) 6,090.21 63.45 330.18 4,000.18 3,951.70 4,005.66 915.33 6,020,194.00 570,266.21 3.80 929.78 2_MWD+IFR2+MS+Sag (2) 6,153.40 64.93 325.62 4,027.71 3,979.23 4,053.82 885.10 6,020,241.87 570,235.54 6.91 978.04 2_MWD+IFR2+MS+Sag(2) 6,216.65 65.42 322.39 4,054.27 4,005.79 4,100.26 851.37 6,020,287.99 570,201.38 4.70 1,028.69 2_MWD+IFR2+MS+Sag(2) 6,279.47 66.23 318.94 4,080.00 4,031.52 4,144.57 815.04 6,020,331.96 570,164.65 5.17 1,080.74 2_MWD+IFR2+MS+Sag (2) 6,342.65 66.29 315.72 4,105.44 4,056.96 4,187.09 775.85 6,020,374.10 570,125.06 4.67 1,134.58 2_MWD+IFR2+MS+Sag (2) 6,406.62 66.72 311.58 4,130.95 4,082.47 4,227.57 733.41 6,020,414.18 570,082.25 5.97 1,190.46 2_MWD+IFR2+MS+Sag (2) 6,468.98 68.79 306.58 4,154.57 4,106.09 4,263.92 688.62 6,020,450.12 570,037.12 8.13 1,246.65 2_MWD+IFR2+MS+Sag (2) 6,532.62 69.34 304.03 4,177.32 4,128.84 4,298.27 640.11 6,020,484.01 569,988.31 3.84 1,305.29 2_MWD+IFR2+MS+Sag (2) 6,595.37 70.09 305.18 4,199.07 4,150.59 4,331.69 591.67 6,020,516.98 569,939.56 2.09 1,363.48 2_MWD+IFR2+MS+Sag(2) 6,658.93 71.72 302.43 4,219.87 4,171.39 4,365.10 541.77 6,020,549.91 569,889.35 4.83 1,422.97 2_MWD+IFR2+MS+Sag(2) 6,721.91 73.08 301.61 4,238.91 4,190.43 4,396.93 490.87 6,020,581.26 569,838.16 2.49 1,482.66 2_MWD+IFR2+MS+Sag (2) 6,784.68 75.64 297.77 4,255.84 4,207.36 4,426.85 438.37 6,020,610.69 569,785.39 7.16 1,542.96 2_MWD+IFR2+MS+Sag (2) 6,847.70 76.61 297.17 4,270.95 4,222.47 4,455.07 384.08 6,020,638.40 569,730.85 1.80 1,604.12 2_MWD+IFR2+MS+Sag (2) 6,910.90 78.43 295.21 4,284.61 4,236.13 4,482.30 328.72 6,020,665.11 569,675.24 4.18 1,665.82 2_MWD+IFR2+MS+Sag (2) 6,974.53 79.24 295.19 4,296.93 4,248.45 4,508.87 272.23 6,020,691.16 569,618.52 1.27 1,728.24 2_MWD+IFR2+MS+Sag(2) 7,036.92 80.76 293.13 4,307.76 4,259.28 4,534.02 216.18 6,020,715.78 569,562.23 4.06 1,789.65 2_MWD+IFR2+MS+Sag(2) 7,100.37 82.38 291.43 4,317.06 4,268.58 4,557.81 158.10 6,020,739.02 569,503.94 3.68 1,852.28 2_MWD+IFR2+MS+Sag(2) 7,163.62 84.49 287.65 4,324.30 4,275.82 4,578.82 98.90 6,020,759.48 569,444.55 6.81 1,914.70 2_MWD+IFR2+MS+Sag(2) 7,226.84 84.74 285.77 4,330.23 4,281.75 4,596.91 38.62 6,020,777.01 569,384.11 2.99 1,976.83 2_MWD+IFR2+MS+Sag (2) 7,289.83 83.05 287.13 4,336.93 4,288.45 4,614.65 -21.45 6,020,794.18 569,323.89 3.44 2,038.59 2_MWD+IFR2+MS+Sag (2) 7,353.26 82.25 287.70 4,345.05 4,296.57 4,633.48 -81.47 6,020,812.45 569,263.70 1.54 2,100.81 2_MWD+IFR2+MS+Sag(2) 7,415.97 84.12 286.18 4,352.49 4,304.01 4,651.62 -141.04 6,020,830.03 569,203.98 3.83 2,162.30 2_MWD+IFR2+MS+Sag(2) 7,479.01 84.61 285.24 4,358.68 4,310.20 4,668.60 -201.43 6,020,846.45 569,143.44 1.68 2,224.04 2_MWD+IFR2+MS+Sag(2) 7,542.07 84.18 285.15 4,364.84 4,316.36 4,685.05 -261.99 6,020,862.33 569,082.73 0.70 2,285.69 2_MWD+IFR2+MS+Sag(2) 7,605.20 85.11 283.92 4,370.73 4,322.25 4,700.82 -322.83 6,020,877.54 569,021.75 2.44 2,347.30 2_MWD+IFR2+MS+Sag (2) 7,668.50 84.73 284.28 4,376.33 4,327.85 4,716.18 -383.98 6,020,892.33 568,960.46 0.83 2,409.01 2_MWD+IFR2+MS+Sag (2) 7,731.89 84.18 284.82 4,382.46 4,333.98 4,732.03 -445.05 6,020,907.61 568,899.25 1.21 2,470.86 2_MWD+IFR2+MS+Sag (2) 7,794.76 83.99 284.58 4,388.94 4,340.46 4,747.90 -505.54 6,020,922.91 568,838.62 0.49 2,532.19 2_MWD+IFR2+MS+Sag(2) 7,858.33 83.37 285.01 4,395.93 4,347.45 4,764.04 -566.63 6,020,938.47 568,777.39 1.18 2,594.18 2_MWD+IFR2+MS+Sag(2) 7,921.51 86.54 285.03 4,401.49 4,353.01 4,780.35 -627.41 6,020,954.21 568,716.47 5.02 2,655.96 2_MWD+IFR2+MS+Sag(2) 7,984.76 90.31 285.52 4,403.23 4,354.75 4,797.00 -688.39 6,020,970.30 568,655.35 6.01 2,718.09 2_MWD+IFR2+MS+Sag (2) 8,026.96 90.24 286.06 4,403.03 4,354.55 4,808.48 -728.99 6,020,981.40 568,614.64 1.29 2,759.62 2_MWD+IFR2+MS+Sag (2) 8,077.74 90.02 289.23 4,402.91 4,354.43 4,823.87 -777.38 6,020,996.34 568,566.12 6.26 2,809.86 2_MWD+IFR2+MS+Sag (3) 8,141.19 89.33 291.61 4,403.27 4,354.79 4,846.01 -836.84 6,021,017.92 568,506.46 3.91 2,873.01 2_MWD+IFR2+MS+Sag (3) 8,203.98 89.95 291.78 4,403.66 4,355.18 4,869.22 -895.18 6,021,040.58 568,447.91 1.02 2,935.63 2_MWD+IFR2+MS+Sag (3) 1/28/1019 3:46:14PM Page 5 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 Design: MPU E-37 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) (olloo') (ft) Survey Tool Name 8,267.21 90.07 291.02 4,403.65 4,355.17 4,892.29 -954.05 6,021,063.10 568,388.83 1.22 2,998.66 2_MWD+IFR2+MS+Sag (3) 8,330.41 90. 44 288.68 4,403.37 4,354.89 4,913.75 -1,013.49 6,021,084.00 568,329.20 3.75 3,061.50 2_MWD+IFR2+MS+Sag(3) 8,393.72 89.82 285.54 4,403.23 4,354.75 4,932.37 -1,073.99 6,021,102.06 568,268.54 5.06 3,124.04 2_MWD+IFR2+MS+Sag(3) 8,456.51 90.69 283.16 4,402.95 4,354.47 4,947.93 -1,134.81 6,021,117.05 568,207.58 4.04 3,185.55 2_MWD+IFR2+MS+Sag(3) 8,519.96 89.45 281.31 4,402.87 4,354.39 4,961.38 -1,196.82 6,021,129.92 568,145.45 3.51 3,247.18 2_MWD+IFR2+MS+Sag(3) 8,583.09 89.82 281.07 4,403.27 4,354.79 4,973.63 -1,258.75 6,021,141.59 568,083.42 0.70 3,308.23 2_MWD+IFR2+MS+Sag(3) 8,646.27 89.08 280.66 4,403.88 4,355.40 4,985.54 -1,320.79 6,021,152.92 568,021.27 1.34 3,369.23 2_MWD+IFR2+MS+Sag (3) 8,709.04 89.70 280.51 4,404.55 4,356.07 4,997.07 -1,382.49 6,021,163.88 567,959.48 1.02 3,429.75 2_MWD+IFR2+MS+Sag (3) 8,772.08 89.33 281.30 4,405.08 4,356.60 5,008.99 -1,444.39 6,021,175.22 567,897.48 1.38 3,490.63 2_MWD+IFR2+MS+Sag(3) 8,835.21 89.33 281.78 4,405.82 4,357.34 5,021.62 -1,506.24 6,021,187.27 567,835.52 0.76 3,551.77 2_MWD+IFR2+MS+Sag(3) 8,898.96 88.34 283.66 4,407.12 4,358.64 5,035.66 -1,568.41 6,021,200.73 567,773.23 3.33 3,613.81 2_MWD+IFR2+MS+Sag(3) 8,961.84 87.85 284.84 4,409.21 4,360.73 5,051.12 -1,629.32 6,021,215.63 567,712.18 2.03 3,675.35 2_MWD+IFR2+MS+Sag (3) 9,025.59 88.03 287.01 4,411.50 4,363.02 5,068.60 -1,690.58 6,021,232.53 567,650.77 3.41 3,738.08 2_MWD+IFR2+MS+Sag (3) 9,087.06 87.72 289.15 4,413.78 4,365.30 5,087.67 -1,748.97 6,021,251.05 567,592.21 3.52 3,798.92 2_MWD+IFR2+MS+Sag(3) 9,151.07 88.34 290.66 4,415.98 4,367.50 5,109.45 -1,809.12 6,021,272.26 567,531.86 2.55 3,862.54 2_MWD+IFR2+MS+Sag (3) 9,213.66 89.77 290.63 4,417.01 4,368.53 5,131.51 -1,867.68 6,021,293.78 567,473.10 2.29 3,924.85 2_MWD+IFR2+MS+Sag(3) 9,277.66 90.32 290.50 4,416.96 4,368.48 5,153.99 -1,927.60 6,021,315.70 567,412.98 0.88 3,988.57 2_MWD+IFR2+MS+Sag (3) 9,340.65 89.70 290.40 4,416.95 4,368.47 5,176.00 -1,986.62 6,021,337.16 567,353.76 1.00 4,051.27 2_MWD+IFR2+MS+Sag (3) 9,403.60 89.33 290.31 4,417.48 4,369.00 5,197.89 -2,045.63 6,021,358.50 567,294.55 0.60 4,113.92 2_MWD+IFR2+MS+Sag(3) 9,466.00 88.46 290.11 4,418.69 4,370.21 5,219.45 -2,104.18 6,021,379.50 567,235.81 1.43 4,175.99 2_MWD+IFR2+MS+Sag(3) 9,529.94 88.65 289.99 4,420.30 4,371.82 5,241.36 -2,164.23 6,021,400.85 567,175.57 0.35 4,239.57 2_MWD+IFR2+MS+Sag(3) 9,593.42 89.70 290.09 4,421.21 4,372.73 5,263.11 -2,223.86 6,021,422.05 567,115.75 1.66 4,302.71 2_MWD+IFR2+MS+Sag (3) 9,655.60 90.38 290.73 4,421.17 4,372.69 5,284.80 -2,282.13 6,021,443.19 567,057.28 1.50 4,364.60 2_MWD+IFR2+MS+Sag(3) 9,719.31 89.45 290.54 4,421.26 4,372.78 5,307.25 -2,341.75 6,021,465.08 566,997.46 1.49 4,428.03 2_MWD+IFR2+MS+Sag (3) 9,782.81 89.64 290.31 4,421.77 4,373.29 5,329.41 -2,401.26 6,021,486.68 566,937.75 0.47 4,491.23 2_MWD+IFR2+MS+Sag(3) 9,845.64 90.88 290.95 4,421.48 4,373.00 5,351.54 -2,460.06 6,021,508.27 566,878.75 2.22 4,553.79 2_MWD+1FR2+M8+Sag(3) 9,908.38 91.62 290.81 4,420.11 4,371.63 5,373.90 -2,518.66 6,021,530.07 566,819.95 1.20 4,616.27 2_MWD+IFR2+MS+Sag (3) 9,971.89 93.79 291.43 4,417.12 4,368.64 5,396.76 -2,577.84 6,021,552.38 566,760.57 3.55 4,679.48 2_MWD+IFR2+MS+Sag (3) 10,034.97 94.34 292.75 4,412.65 4,364.17 5,420.42 -2,636.14 6,021,575.49 566,702.06 2.26 4,742.26 2_MWD+IFR2+MS+Sag (3) 10,098.37 92.41 293.04 4,408.91 4,360.43 5,445.04 -2,694.44 6,021,599.57 566,643.53 3.08 4,805.45 2_MWD+IFR2+MS+Sag(3) 10,161.06 91.86 293.37 4,406.58 4,358.10 5,469.72 -2,752.02 6,021,623.71 566,585.73 1.02 4,868.03 2_MWD+IFR2+MS+Sag(3) 10,224.47 92.42 295.22 4,404.21 4,355.73 5,495.79 -2,809.77 6,021,649.24 566,527.75 3.05 4,931.36 2_MWD+IFR2+MS+Sag(3) 10,287.64 92.17 296.99 4,401.68 4,353.20 5,523.57 -2,866.45 6,021,676.48 566,470.82 2.83 4,994.48 2_MWD+IFR2+MS+Sag (3) 10,350.66 91.80 298.55 4,399.50 4,351.02 5,552.91 -2,922.18 6,021,705.30 566,414.83 2.54 5,057.43 2_MWD+IFR2+MS+Sag (3) 10,413.76 91.99 299.68 4,397.41 4,348.93 5,583.59 -2,977.27 6,021,735.47 566,359.45 1.81 5,120.40 2_MWD+IFR2+MS+Sag(3) 10,476.93 92.54 301.94 4,394.91 4,346.43 5,615.92 -3,031.48 6,021,767.29 566,304.95 3.68 5,183.29 2 MWD+IFR2+MS+Sag(3) 10,539.80 93.60 304.30 4,391.55 4,343.07 5,650.22 -3,084.06 6,021,801.09 566,252.06 4.11 5,245.57 2_MWD+IFR2+MS+Sag(3) 10,603.22 94.33 306.83 4,387.16 4,338.68 5,687.02 -3,135.52 6,021,837.40 566,200.27 4.14 5,307.94 2_MWD+IFR2+MS+Sag(3) 10,664.42 95.03 309.12 4,382.17 4,333.69 5,724.54 -3,183.60 6,021,874.48 566,151.84 3.90 5,367.60 2_MWD+IFR2+MS+Sag (3) 10,728.47 95.70 311.19 4,376.18 4,327.70 5,765.66 -3,232.33 6,021,915.14 566,102.73 3.38 5,429.41 2_MWD+IFR2+MS+Sag (3) 12812019 3.46:14PM Page 6 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-37 MPU E-37 MPU E-37 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1 (') (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 10,791.00 94.52 311.31 4,370.61 4,322.13 5,806.73 -3,279.16 6,021,955.76 566,055.53 1.90 5,489.49 2_MWD+IFR2+MS+Sag (3) 10,854.21 92.91 311.93 4,366.51 4,318.03 5,848.62 -3,326.31 6,021,997.21 566,007.99 2.73 5,550.22 2_MWD+IFR2+MS+Sag(3) 10,900.00 93.93 312.23 4,363.78 4,315.30 5,879.25 -3,360.23 5,022,027.52 565,973.79 2.32 5,594.13 2_MWD+IFR2+MS+Sag(4) 10,980.77 91.98 311.23 4,359.62 4,311.14 5,932.94 -3,420.43 6,022,080.64 565,913.10 2.71 5,671.74 2_MWD+IFR2+MS+Sag(4) 11,044.27 92.73 311.02 4,357.01 4,308.53 5,974.67 -3,468.22 6,022,121.92 565,864.93 1.23 5,732.98 2_MWD+IFR2+MS+Sag(4) 11,107.33 91.49 310.12 4,354.69 4,306.21 6,015.65 -3,516.09 6,022,162.45 565,816.69 2.43 5,793.95 2_MWD+IFR2+MS+Sag (4) 11,170.25 91.74 308.88 4,352.91 4,304.43 6,055.66 -3,564.62 6,022,202.00 565,767.79 2.01 5,855.10 2_MWD+IFR2+MS+Sag (4) 11,233.48 91.98 306.98 4,350.86 4,302.38 6,094.50 -3,614.46 6,022,240.37 565,717.59 3.03 5,916.91 2_MWD+IFR2+MS+Sag (4) 11,296.77 91.55 305.04 4,348.91 4,300.43 6,131.69 -3,665.63 6,022,277.08 565,666.08 3.14 5,979.20 2 MWD+IFR2+MS+Sag(4) 11,359.99 90.25 303.71 4,347.92 4,299.44 6,167.38 -3,717.80 6,022,312.28 565,613.59 2.94 6,041.72 2_MWD+IFR2+MS+Sag (4) 11,423.12 90.19 301.10 4,347.67 4,299.19 6,201.21 -3,771.10 6,022,345.61 565,559.98 4.14 6,104.45 2_MWD+IFR2+MS+Sag (4) 11,486.63 89.45 299.42 4,347.87 4,299.39 6,233.21 -3,825.95 6,022,377.09 565,504.84 2.89 6,167.78 2_MWD+IFR2+MS+Sag (4) 11,549.08 90.20 298.95 4,348.06 4,299.58 6,263.66 -3,880.47 6,022,407.03 565,450.04 1.42 6,230.13 2_MWD+IFR2+MS+Sag (4) 11,612.52 91.06 298.94 4,347.37 4,298.89 6,294.37 -3,935.98 6,022,437.21 565,394.25 1.36 6,293.47 2_MWD+IFR2+MS+Sag (4) 11,676.11 90.63 298.78 4,346.43 4,297.95 6,325.06 -3,991.67 6,022,467.38 565,338.29 0.72 6,356.98 2_MWD+IFR2+MS+Sag (4) 11,739.09 89.08 298.36 4,346.59 4,298.11 6,355.17 -4,046.98 6,022,496.98 565,282.71 2.55 6,419.89 2_MWD+IFR2+MS+Sag (4) 11,802.75 89.58 297.95 4,347.33 4,298.85 6,385.21 -4,103.10 6,022,526.49 565,226.31 1.02 6,483.50 2_MWD+IFR2+MS+Sag (4) 11,866.01 89.58 296.34 4,347.80 4,299.32 6,414.07 -4,159.39 6,022,554.82 565,169.76 2.54 6,546.74 2_MWD+IFR2+MS+Sag (4)M 11,928.71 87.66 294.89 4,349.31 4,300.83 6,441.17 -4,215.91 6,022,581.39 565,113.00 3.84 6,609.41 2_WD+IFR2+MS+Sag (4) 11,991.74 88.16 295.38 4,351.61 4,303.13 6,467.92 -4,272.93 6,022,607.61 565,055.73 1.11 6,672.40 2_MWD+IFR2+MS+Sag (4) 12,052.28 87.23 295.41 4,354.04 4,305.56 6,493.86 4,327.58 6,022,633.04 565,000.86 1.54 6,732.88 2_MWD+IFR2+MS+Sag(4) 12,117.73 87.85 295.44 4,356.85 4,308.37 6,521.94 4,386.63 6,022,660.56 564,941.55 0.95 6,798.27 2_MWD+IFR2+MS+Sag (4) 12,181.41 87.79 295.51 4,359.27 4,310.79 6,549.31 4,444.08 6,022,687.39 564,883.85 0.14 6,861.90 2_MWD+IFR2+MS+Sag (4) 12,244.61 88.22 295.66 4,361.47 4,312.99 6,576.58 -4,501.05 6,022,714.13 564,826.64 0.72 6,925.06 2_MWD+IFR2+MS+Sag (4) 12,307.18 87.85 295.40 4,363.62 4,315.14 6,603.53 -4,557.48 6,022,740.55 564,769.97 0.72 6,987.59 2 MWD+IFR2+MS+Sag(4) 12,370.55 88.09 295.69 4,365.86 4,317.38 6,630.84 -4,614.62 6,022,767.32 564,712.58 0.59 7,050.92 2_MWD+IFR2+MS+Sag(4) 12,432.85 88.47 295.86 4,367.73 4,319.25 6,657.92 4,670.69 6,022,793.88 564,656.26 0.67 7,113.19 2_MWD+IFR2+MS+Sag(4) 12,497.00 88.65 295.43 4,369.34 4,320.86 6,685.68 4,728.50 6,022,821.09 564,598.20 0.73 7,177.32 2_MWD+IFR2+MS+Sag (4) 12,559.99 87.66 294.46 4,371.37 4,322.89 6,712.23 4,785.59 6,022,847.11 564,540.88 2.20 7,240.27 2_MWD+IFR2+MS+Sag (4) 12,622.18 87.97 294.03 4,373.74 4,325.26 6,737.75 4,842.25 6,022,872.09 564,483.98 0.85 7,302.38 2 MWD+IFR2+MS+Sag (4)M 12,686.85 89.39 294.21 4,375.23 4,326.75 6,764.17 -4,901.26 6,022,897.96 564,424.74 2.21 7,367.00 2_WD+IFR2+MS+Sag(4) 12,746.86 91.19 294.94 4,374.93 4,326.45 6,789.12 -4,955.83 6,022,922.40 564,369.94 3.24 7,426.99 2_MWD+IFR2+MS+Sag(4) 12,808.23 90.87 295.05 4,373.83 4,325.35 6,815.05 -5,011.44 6,022,947.81 564,314.09 0.55 7,488.34 2_MWD+IFR2+MS+Sag(4) 12,875.26 90.94 294.98 4,372.77 4,324.29 6,843.39 -5,072.18 6,022,975.68 564,253.10 0.15 7,555.36 2_MWD+IFR2+MS+Sag(4) 12,938.07 90.81 294.66 4,371.81 4,323.33 6,869.75 -5,129.18 6,023,001.41 564,195.87 0.55 7,618.15 2_MWD+IFR2+MS+Sag(4) 13,001.55 91.80 295.34 4,370.36 4,321.88 6,896.57 -5,186.69 6,023,027.69 564,138.11 1.89 7,681.60 2_MWD+IFR2+MS+Sag (4) 13,064.29 92.36 295.34 4,368.09 4,319.61 6,923.41 -5,243.36 6,023,053.99 564,081.20 0.89 7,744.29 2_MWD+IFR2+MS+Sag(4) 13,126.15 92.11 295.58 4,365.67 4,317.19 6,949.98 -5,299.17 6,023,080.04 564,025.15 0.56 7,806.11 2_MWD+IFR2+MS+Sag (4) 13,188.59 90.93 295.58 4,364.02 4,315.54 6,976.93 -5,355.47 6,023,106.46 563,968.61 1.89 7,868.52 2_MWD+IFR2+MS+Sag(4) 13,251.92 91.12 295.99 4,362.88 4,314.40 7,004.47 -5,412.48 6,023,133.47 563,911.34 0.71 7,931.84 2_MWD+IFR2+MS+Sag (4) 1282019 3:46:14PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-37 MPU E-37 MPU E-37 Local Co-ordinate Reference: Well MPU E-37 TVD Reference: MPE-37 Actual RKB @ 48.48usft MD Reference: MPE-37 Actual RKB @ 48.48usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +FJ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001) (ft) Survey Tool Name 13,309.15 91.62 295.86 4,361.52 4,313.04 7,029.49 -5,463.94 6,023,158.00 563,859.66 0.90 7,989.05 2_MWD+IFR2+MS+Sag (4) 13,380.37 89.63 296.20 4,360.74 4,312.26 7,060.74 -5,527.93 6,023,188.65 563,795.39 2.83 8,060.27 2_MWD+IFR2+MS+Sag (4) 13,444.16 90.26 296.23 4,360.80 4,312.32 7,088.91 -5,585.16 6,023,216.30 563,737.91 0.99 8,124.05 2_MWD+IFR2+MS+Sag (4) 13,507.04 89.33 296.45 4,361.03 4,312.55 7,116.81 -5,641.51 6,023,243.67 563,681.31 1.52 8,186.93 2_MWD+IFR2+MS+Sag (4) 13,570.46 88.77 296.44 4,362.08 4,313.60 7,145.05 -5,698.28 6,023,271.37 563,624.27 0.88 8,250.34 2 MWD+IFR2+MS+Sag(4) 13,633.22 88.84 296.74 4,363.39 4,314.91 7,173.14 -5,754.39 6,023,298.93 563,567.91 0.49 8,313.08 2_MWD+IFR2+MS+Sa9 (4) 13,696.43 89.76 296.66 4,364.16 4,315.68 7,201.54 5,810.86 6,023,326.80 563,511.19 1.46 8,376.28 2_MWD+IFR2+MS+Sag(4) 13,758.49 90.20 297.29 4,364.18 4,315.70 7,229.69 -5,866.17 6,023,354.43 563,455.63 1.24 8,438.33 2_MWD+IFR2+MS+Sag(4) 13,822.93 90.13 297.33 4,363.99 4,315.51 7,259.25 -5,923.42 6,023,383.46 563,398.10 0.13 8,502.75 2_MWD+IFR2+MS+Sag(4) 13,875.59 89.76 297.63 4,364.04 4,315.56 7,283.55 -5,970.14 6,023,407.32 563,351.16 0.90 8,555.39 2_MWD+IFR2+MS+Sag (4) 13,944.00 89.76 297.63 4,364.33 4,315.85 7,315.28 -6,030.75 6,023,438.48 563,290.27 0.00 8,623.77 PROJECTED to TO "'"°'°=:' Mitch Laird Checked By: Chelsea Wri ht"�`.m , y g Approved By: Date: 1-28-2019 1/282019 3:46:14PM Page 8 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-37 PB1 500292361670 Sperry Drilling Definitive Survey Report 28 January, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcerp Alaska, LLC Local Coordinate Reference: Well MPU E-37 Project: Milne Point TVD Reference: MPE-37 Actual IRKS @ 48.48usft Site: M Pt E Pad MD Reference: MPE-37 Actual RKB @ 48.48usft Well: MPU E-37 North Reference: True Wellbore: MPU E-37 PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-37 P61 Database: NORTH US+CANADA 3roject 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 E-37 Well Position +N/ -S +E/ -W Position Uncertainty Wellbore MPU E-37 PB1 Magnetics Model Name 0.00 usft Northing: 6,016,180.37 usfl 0.00 usft Easting: 569,388.31 usfl 0.00 usft Wellhead Elevation: 0.00 usfl Sample Date Declination (') BGGM2018 1/21/2019 16.88 Design MPU E-37 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S Inc (usft) (usft) TVDSS 26.78 0.00 Latitude: 70° 27' 16.412 N Longitude: 149° 26' 1.542 W Ground Level: 21.70usft Dip Angle Field Strength (`) (nT) 80.97 57,441.56516503 Tie On Depth: 26.78 +EI -W Direction (usft) (I 0.00 295.95 Survey Program Date 1/23/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 102.00 226.00 MPU E-37PB1 Surface Gyro (MPU E-37 2_Gyro-NS-GC_Drill colli H029Ga; North seeking single shot in drill colla 12/26/2018 291.29 8,026.96 MPU E-37PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/04/2019 8,077.74 10,982.04 MPU E -37P81 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 01/21/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/1001) (ft) Survey Tool Name 26.78 0.00 GM 26.78 -21.70 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 UNDEFINED 102.00 0.44 107.29 102.00 53.52 -0.09 0.28 6,016,180.29 569,388.59 0.58 -0.29 2_Gym-NS-GG_DMI collar (1 164.00 0.57 94.32 164.00 115.52 -0.18 0.81 6,016,180.20 569,389.12 0.28 -0.81 2_Gym.NS-GC_Drill collar (1 226.00 1.32 61.32 225.99 177.51 0.14 1.74 6,016,180.53 569,390.05 1.45 -1.51 2_Gym-NS-GC_Dnll collar (1 291.29 2.94 55.75 291.23 242.75 1.44 3.79 6,016,ldl.85 569,392.08 2.50 -2.78 2_MWD+IFR2+MS+Sag(2) 344.49 4.62 52.75 344.31 295.83 3.51 6.62 6,016,183.94 569,394.90 3.18 4.42 2_MWD+IFR2+MS+Sag (2)M 414.11 6.13 53.52 413.63 365.15 7.42 11.84 6,016,187.89 569,400.08 2.17 -7.40 2_WD+IFR2+MS+Sag (2) 475.39 7.18 52.81 474.49 426.01 11.68 17.52 6,016,192.21 569,405.72 1.72 -10.65 2_MWD+IFR2+MS+Sag(2) 536.24 7.42 39.49 534.85 486.37 17.01 23.05 6,016,197.59 569,411.20 2.80 -13.29 2 MWD+IFR2+MS+Sag(2) 598.13 9.18 37.72 596.09 547.61 24.00 28.62 6,016,204.63 569,416.70 2.87 -15.23 2_MWD+IFR2+MS+Sag (2) 660.12 11.00 32.98 657.12 608.64 32.87 34.86 6,016,213.56 569,422.86 3.22 -16.96 2_MWD+IFR2+MS+Sag (2) 723.27 12.87 25.01 718.91 670.43 44.30 41.11 6,016,225.05 569,429.01 3.94 -17.58 2_MWD+IFR2+MS+Sag(2) 1/282019 3.45:03PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 P81 Design: MPU E-37 PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 787.48 14.73 23.44 781.26 732.78 58.27 47.39 6,016,239.07 569,435.15 2.95 -17.11 2_MWD+IFR2+MS+Sag (2) 850.31 18.40 20.96 841.48 793.00 74.86 54.11 6,016,255.73 569,441.72 5.95 -15.90 2_MWD+IFR2+MS+Sag (2) 913.41 21.30 19.96 900.82 852.34 94.94 61.59 6,016,275.87 569,449.01 4.63 -13.83 2_MWD+IFR2+MS+Sag (2) 976.29 24.04 20.61 958.84 910.36 117.67 70.00 6,016,298.67 569,457.20 4.38 -11.45 2_MWD+IFR2+MS+Sag (2) 1,040.17 27.78 19.37 1,016.29 967.81 143.90 79.52 6,016,324.99 569,466.48 5.92 -8.53 2_MWD+IFR2+MS+Sag(2) 1,102.82 31.67 21.15 1,070.68 1,022.20 173.02 90.30 6,016,354.21 569,476.99 6.37 -5.48 2_MWD+IFR2+MS+Sag(2) 1,165.23 34.00 22.60 1,123.12 1,074.64 204.42 102.92 6,016,385.72 569,489.31 3.94 -3.09 2_MWD+IFR2+MS+Sag (2) 1,229.79 37.12 23.47 1,175.63 1,127.15 238.96 117.62 6,016,420.39 569,503.69 4.90 -1.19 2_MWD+IFR2+MS+Sag (2) 1,292.99 39.08 22.05 1,225.37 1,176.89 274.92 132.69 6,016,456.49 569,518.42 3.40 0.99 2_MWD+IFR2+MS+Sag (2) 1,355.96 42.90 20.89 1,272.89 1,224.41 313.36 147.79 6,016,495.06 569,533.16 6.19 4.23 2_MWD+IFR2+MS+Sag(2) 1,418.37 46.96 20.27 1,317.06 1,268.58 354.61 163.27 6,016,536.46 569,548.26 6.54 8.36 2_MWD+IFR2+MS+Sag(2) 1,481.31 48.50 19.03 1,359.40 1,310.92 398.48 178.93 6,016,580.46 569,563.50 2.85 13.48 2_MWD+IFR2+MS+Sag (2) 1,544.97 50.25 19.08 1,400.85 1,352.37 444.14 194.70 6,016,626.27 569,578.85 2.75 19.28 2_MWD+IFR2+MS+Sag (2) 1,607.55 53.42 16.92 1,439.51 1,391.03 490.93 209.89 6,016,673.19 569,593.59 5.75 26.10 2_MWD+IFR2+MS+Sag(2) 1,671.29 53.86 16.59 1,477.30 1,428.82 540.08 224.68 6,016,722.47 569,607.93 0.81 34.30 2_MWD+IFR2+MS+Sag(2) 1,734.43 54.44 17.91 1,514.28 1,465.80 588.96 239.86 6,016,771.48 569,622.65 1.93 42.04 2_MWD+IFR2+MS+Sag(2) 1,798.20 53.87 17.67 1,551.63 1,503.15 638.18 255.65 6,016,820.84 569,637.99 0.94 49.38 2_MWD+IFR2+MS+Sag (2) 1,860.95 52.85 18.74 1,589.07 1,540.59 686.01 271.38 6,016,868.81 569,653.26 2.12 56.17 2_MWD+IFR2+MS+Sag (2) 1,924.20 52.96 17.09 1,627.22 1,578.74 734.01 286.90 6,016,916.95 569,668.33 2.09 63.22 2_MWD+IFR2+MS+Sag(2) 1,986.92 54.74 16.40 1,664.22 1,615.74 782.50 301.49 6,016,965.57 569,682.47 2.97 71.32 2_MWD+IFR2+MS+Sag(2) 2,050.09 54.41 16.83 1,700.84 1,652.36 831.83 316.20 6,017,015.03 569,696.72 0.76 79.67 2_MWD+IFR2+MS+Sag(2) 2,112.95 53.64 17.46 1,737.76 1,689.28 880.44 331.20 6,017,063.77 569,711.26 1.47 87.46 2_MWD+IFR2+MS+Sag (2) 2,176.48 52.65 16.74 1,775.87 1,727.39 929.03 346.15 6,017,112.49 569,725.76 1.80 95.28 2_MWD+IFR2+MS+Sag (2) 2,239.49 52.71 16.25 1,814.07 1,765.59 977.07 360.38 6,017,160.66 569,739.54 0.63 103.51 2_MWD+IFR2+MS+Sag(2) 2,302.87 53.78 16.73 1,852.00 1,803.52 1,025.76 374.79 6,017,209.48 569,753.50 1.79 111.86 2_MWD+IFR2+MS+Sag(2) 2,365.54 55.35 17.25 1,888.33 1,839.85 1,074.59 389.71 6,017,258.44 569,767.96 2.59 119.81 2_MWD+IFR2+MS+Sag(2) 2,428.80 53.28 17.42 1,925.23 1,876.75 1,123.64 405.02 6,017,307.63 569,782.81 3.28 127.51 2_MWD+IFR2+MS+Sag (2) 2,491.56 53.96 17.06 1,962.45 1,913.97 1,171.90 419.99 6,017,356.02 569,797.33 1.18 135.16 2 MWD+IFR2+MS+Sag (2) 2,554.78 55.21 17.54 1,999.09 1,950.61 1,221.09 435.32 6,017,405.34 569,812.20 2.07 142.90 2_MWD+IFR2+MS+Sag (2) 2,618.04 57.32 16.42 2,034.22 1,985.74 1,271.40 450.67 6,017,455.79 569,827.08 3.65 151.11 2_MWD+IFR2+MS+Sag(2) 2,681.08 57.02 17.46 2,068.40 2,019.92 1,322.07 466.11 6,017,506.60 569,842.04 1.47 159.41 2_MWD+IFR2+MS+Sag (2) 2,744.14 57.40 16.51 2,102.55 2,054.07 1,372.77 481.59 6,017,557.44 569,857.05 1.40 167.67 2_MWD+IFR2+MS+Sag (2) 2,807.54 57.57 17.04 2,136.63 2,088.15 1,423.96 497.02 6,017,608.76 569,872.00 0.75 176.19 2_MWD+IFR2+MS+Sag (2) 2,870.96 57.58 16.74 2,170.63 2,122.15 1,475.18 512.57 6,017,660.12 569,887.08 0.40 184.62 2_MWD+IFR2+MS+Sag(2) 2,933.53 56.37 16.99 2,204.73 2,156.25 1,525.38 527.79 6,017,710.46 569,901.83 1.96 192.91 2_MWD+IFR2+MS+Sag(2) 2,996.91 55.03 17.58 2,240.45 2,191.97 1,575.38 543.35 6,017,760.59 569,916.91 2.25 200.80 2_MWD+IFR2+MS+Sag(2) 3,059.92 55.35 18.25 2,276.42 2,227.94 1,624.60 559.26 6,017,809.96 569,932.37 1.01 208.03 2_MWD+IFR2+MS+Sag(2) 3,123.53 53.33 18.06 2,313.50 2,265.02 1,673.71 575.37 6,017,859.21 569,948.01 3.18 215.04 2_MWD+IFR2+MS+Sag (2) 3,186.22 55.32 16.99 2,350.06 2,301.58 1,722.27 590.69 6,017,907.90 569,962.88 3.46 222.50 2_MWD+IFR2+MS+Sag(2) 3,249.34 55.10 17.98 2,386.07 2,337.59 1,771.71 606.27 6 569,978.00 1.33 M017,957.48 230.14 2_WD+IFR2+MS+Sag(2) 1/2&2019 3.45:03PM Page 3 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 PB1 Design: MPU E-37 P131 Survey MD Inc (usft) (°) 3,312.23 54.85 3,375.86 54.07 3,438.93 53.69 3,501.95 54.75 3,565.04 54.31 3,628.07 53.52 3,691.60 54.07 3,754.95 54.63 3,816.93 54.23 3,880.77 53.41 3,943.81 54.51 4,007.20 54.87 4,070.63 53.87 4,134.00 53.49 4,196.70 54.73 4,260.27 54.33 4,323.29 55.21 4,386.10 55.40 4,449.61 55.38 4,513.04 55.53 4,574.49 56.15 4,638.85 54.88 4,701.16 54.36 4,764.80 54.91 4,828.05 54.33 4,891.28 53.54 4,954.31 53.56 5,017.05 53.48 5,080.16 54.32 5,143.46 54.43 5,206.14 55.02 5,268.70 55.39 5,331.36 56.95 5,395.51 56.47 5,458.85 56.78 5,522.35 55.56 5,584.95 55.17 5,647.87 54.56 5,711.06 55.70 5,774.27 56.11 Halliburton Definitive Survey Report Azt TVD TVDSS +NI -S V) (usft) (usft) (usft) 18.60 2,422.17 2,373.69 1,820.61 19.25 2,459.15 2,410.67 1,869.59 19.02 2,496.33 2,447.85 1,917.72 18.89 2,533.18 2,484.70 1,966.07 19.13 2,569.79 2,521.31 2,014.65 19.61 2,606.91 2,558.43 2,062.70 18.91 2,644.44 2,595.96 2,111.10 18.31 2,681.36 2,632.88 2,159.88 18.34 2,717.41 2,668.93 2,207.74 19.30 2,755.10 2,706.62 2,256.52 17.74 2,792.19 2,743.71 2,304.85 18.96 2,828.83 2,780.35 2,353.95 19.50 2,865.78 2,817.30 2,402.62 20.17 2,903.32 2,854.84 2,450.65 17.41 2,940.08 2,891.60 2,498.74 18.10 2,976.96 2,928.48 2,548.04 17.96 3,013.32 2,964.84 2,596.99 16.37 3,049.07 3,000.59 2,646.33 16.67 17.39 16.99 17.58 16.80 15.00 14.12 15.78 13.14 13.17 11.04 9.97 7.08 4.04 1.00 358.81 356.43 354.78 352.05 348.85 345.19 340.93 3,085.14 3,036.66 2,696.44 3,121.11 3,072.63 2,746.40 3,155.62 3,107.14 2,794.98 3,192.06 3,143.58 2,845.63 3,228.13 3,179.65 2,894.16 3,264.97 3,301.59 3,338.82 3,376.27 3,413.57 3,450.76 3,487.63 3,523.83 3,559.54 3,594.43 3,629.64 3,664.49 3,699.84 3,735.42 3,771.64 3,807.77 3,843.22 3,216.49 2,944.07 3,253.11 2,993.98 3,290.34 3,043.36 3,327.79 3,092.45 3,365.09 3,141.57 3,402.28 3,439.15 3,475.35 3,511.06 3,545.95 3,581.16 3,616.01 3,651.36 3,686.94 3,723.16 3,759.29 3,794.74 3,191.43 3,242.02 3,292.61 3,343.74 3,395.73 3,449.34 3,502.19 3,554.78 3,605.94 3,656.67 3,707.17 3,757.22 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +EI -W Northing (usft) (ft) 622.43 6,018,006.52 639.22 6,018,055.65 655.92 6,018,103.93 672.53 6,018,152.43 689.26 6,018,201.16 706.16 6,02,249.37 723.06 6,018,297.91 739.49 6,018,346.84 755.34 6,018,394.84 771.96 6,018,443.76 788.15 6,018,492.24 804.43 6,018,541.48 821.41 6,018,590.31 838.74 6,018,638.50 855.09 6,018,686.72 870.87 6,018,736.17 886.81 6,018,785.26 902.04 6,018,634.74 916.91 6,018,884.98 932.21 6,018,935.07 947.24 6,018,983.78 963.00 6,019,034.57 978.01 6,019,083.24 992.23 6,019,133.27 1,005.19 6,019,183.30 1,018.37 6,019,232.80 1,031.03 6,019,281.99 1,042.51 6,019,331.22 1,053.20 6,019,381.16 1,062.58 6,019,431.83 1,070.16 6,019,482.49 1,075.13 6,019,533.66 1,077.41 6,019,585.66 1,077.32 6,019,639.27 1,075.12 6,019,692.09 1,071.09 6,019,744.63 1,065.18 6,019,795.73 1,056.65 6,019,846.37 1,045.00 6,019,896.76 1,029.75 6,019,946.66 Well MPU E37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (°1100') 569,993.70 0.90 570,010.03 1.48 570,026.28 0.67 570,042.44 1.69 570,058.72 0.76 570,075.16 1.40 570,091.62 1.24 570,107.59 1.17 570,122.99 0.65 570,139.15 1.77 570,154.89 2.65 570,170.71 1.67 570,187.24 1.72 570,204.11 1.04 570,220.01 4.08 570,235.33 1.09 570,250.81 1.41 570,265.59 2.10 570,279.98 0.39 570,294.82 0.96 570,309.39 1.14 570,324.67 2.11 570,339.24 1.32 570,352.98 2.46 570,365.48 1.46 570,378.20 2.46 570,390.40 3.37 570,401.42 0.13 570,411.64 3.03 570,420.55 1.38 570,427.66 3.88 570,432.16 4.03 570,433.95 4.74 570,433.36 2.95 570,430.67 3.18 570,426.15 2.89 570,419.77 3.64 570,410.77 4.27 570,398.65 5.08 570,382.93 5.62 Vertical Section (ft) Survey Tool Name 237.00 2_MWD+IFR2+MS+Sag (2) 243.33 2_MWD+IFR2+MS+Sag (2) 249.38 2_MWD+IFR2+MS+Sag(2) 255.61 2_MWD+IFR2+MS+Sag (2) 261.81 2_MWD+IFR2+MS+Sag (2) 267.65 2_MWD+IFR2+MS+Sag(2) 273.63 2_MWD+IFR2+MS+Sag (2) 280.20 2_MWD+IFR2+MS+Sag (2) 286.89 2_MWD+IFR2+MS+Sag(2) 293.29 2_MWD+IFR2+MS+Sag (2) 299.89 2_MWD+IFR2+MS+Sag (2) 306.73 2_MWD+IFR2+MS+Sa9 (2) 312.76 2_MWD+IFR2+MS+Sag(2) 318.20 2_MWD+IFR2+MS+Sag(2) 324.54 2_MWD+IFR2+MS+Sag(2) 331.92 2_MWD+IFR2+MS+Sag (2) 339.01 2_MWD+IFR2+MS+Sag (2) 346.90 2_MWD+IFR2+MS+Sag(2) 355.47 2_MWD+IFR2+MS+Sag(2) 363.57 2_MWD+IFR2+MS+Sag (2) 371.31 2_MWD+IFR2+MS+Sag (2) 379.31 2_MWD+IFR2+MS+Sag (2) 387.04 2_MWD+IFR2+MS+Sag(2) 396.10 2_MWD+IFR2+MS+Sag(2) 406.28 2_MWD+IFR2+MS+Sag (2) 416.04 2_MWD+IFR2+MS+Sag (2)M 426.14 2_WD+IFR2+MS+Sag (2) 437.31 2_MWD+IFR2+MS+Sag (2) 449.51 2_MWD+IFR2+MS+Sag (2) 463.22 2_MWD+IFR2+MS+Sag (2) 478.54 2_MWD+IFR2+MS+Sag (2) 496.44 2_MWD+IFR2+MS+Sag(2) 517.14 2_MWD+IFR2+MS+Sag(2) 540.68 2_MWD+IFR2+MS+Sag(2) 565.78 2_MWD+IFR2+MS+Sag (2) 592.43 2_MWD+IFR2+MS+Sag(2) 620.12 2_MWD+IFR2+MS+Sag(2) _ 649.99 2MWD+IFR2+MS+Sag(2) 682.57 2_MWD+IFR2+MS+Sag (2) 718.18 2_MWD+IFR2+MS+Sag (2) 12&2019 3:45.'03PM Page 4 COMPASS 5000.15 Build 91 Company: Hiloorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 PBI Design: MPU E-37 PB1 Survey Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-37 MPE-37 Actual RKB @ 48.48usft MPE-37 Actual RKB @ 48.48usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,837.44 58.07 338.80 3,877.54 3,829.06 3,807.00 1,011.49 6,019,996.27 570,364.21 4.20 756.39 2_MWD+IFR2+MS+Sag (2) 5,900.60 58.98 335.96 3,910.52 3,862.04 3,856.72 990.77 6,020,045.78 570,343.03 4.10 796.77 2_MWD+IFR2+MS+Sag (2) 5,964.03 61.18 333.60 3,942.16 3,893.68 3,906.44 967.33 6,020,095.28 570,319.13 4.74 839.60 2_MWD+IFR2+MS+Sag(2) 6,026.91 62.93 332.81 3,971.63 3,923.15 3,956.02 942.29 6,020,144.62 570,293.63 3.00 883.81 2_MWD+IFR2+MS+Sag(2) 6,090.21 63.45 330.18 4,000.18 3,951.70 4,005.66 915.33 6,020,194.00 570,266.21 3.80 929.78 2_MWD+IFR2+MS+Sag(2) 6,153.40 64.93 325.62 4,027.71 3,979.23 4,053.82 885.10 6,020,241.87 570,235.54 6.91 978.04 2_MWD+IFR2+MS+Sag (2) 6,216.65 65.42 322.39 4,054.27 4,005.79 4,100.26 851.37 6,020,287.99 570,201.38 4.70 1,028.69 2_MWD+IFR2+MS+Sag(2) 6,279.47 66.23 318.94 4,080.00 4,031.52 4,144.57 815.04 6,020,331.96 570,164.65 5.17 1,080.74 2_MWD+IFR2+MS+Sag(2) 6,342.65 66.29 315.72 4,105.44 4,056.96 4,187.09 775.85 6,020,374.10 570,125.06 4.67 1,134.58 2_MWD+IFR2+MS+Sag(2) 6,406.62 66.72 311.58 4,130.95 4,082.47 4,227.57 733.41 6,020,414.18 570,082.25 5.97 1,190.46 2_MWD+IFR2+MS+Sag(2) 6,468.98 68.79 306.58 4,154.57 4,106.09 4,263.92 688.62 6,020,450.12 570,037.12 8.13 1,246.65 2_MWD+IFR2+MS+Sag (2) 6,532.62 69.34 304.03 4,177.32 4,128.84 4,298.27 640.11 6,020,484.01 569,988.31 3.84 1,305.29 2_MWD+IFR2+MS+Sag (2) 6,595.37 70.09 305.18 4,199.07 4,150.59 4,331.69 591.67 6,020,516.98 569,939.56 2.09 1,363.48 2_MWD+IFR2+MS+Sag(2) 6,658.93 71.72 302.43 4,219.87 4,171.39 4,365.10 541.77 6,020,549.91 569,889.35 4.83 1,422.97 2_MWD+IFR2+MS+Sag (2) 6,721.91 73.08 301.61 4,238.91 4,190.43 4,396.93 490.87 6,020,581.26 569,838.16 2.49 1,482.66 2_MWD+IFR2+MS+Sag(2) 6,784.68 75.64 297.77 4,255.84 4,207.36 4,426.85 438.37 6,020,610.69 569,785.39 7.16 1,542.96 2_MWD+IFR2+MS+Sag(2) 6,847.70 76.61 297.17 4,270.95 4,222.47 4,455.07 384.08 6,020,638.40 569,730.85 1.80 1,604.12 2_MWD+IFR2+MS+Sag(2) 6,910.90 78.43 295.21 4,284.61 4,236.13 4,482.30 328.72 6,020,665.11 569,675.24 4.18 1,665.82 2_MWD+IFR2+MS+Sag(2) 6,974.53 79.24 295.19 4,296.93 4,248.45 4,508.87 272.23 6,020,691.16 569,618.52 1.27 1,728.24 2_MWD+IFR2+MS+Sag (2) 7,036.92 80.76 293.13 4,307.76 4,259.28 4,534.02 216.18 6,020,715.78 569,562.23 4.06 1,789.65 2_MWD+IFR2+MS+Sag(2) 7,100.37 82.38 291.43 4,317.06 4,268.58 4,557.81 158.10 6,020,739.02 569,503.94 3.68 1,852.28 2_MWD+IFR2+MS+Sag(2) 7,163.62 84.49 287.65 4,324.30 4,275.82 4,578.82 98.90 6,020,759.48 569,444.55 6.81 1,914.70 2_MWD+IFR2+MS+Sag(2) 7,226.84 84.74 285.77 4,330.23 4,281.75 4,596.91 38.62 6,020,777.01 569,384.11 2.99 1,976.83 2_MWD+IFR2+MS+Sag(2) 7,289.83 83.05 287.13 4,336.93 4,288.45 4,614.65 -21.45 6,020,794.18 569,323.89 3.44 2,038.59 2_MWD+IFR2+MS+Sag (2) 7,353.26 82.25 287.70 4,345.05 4,296.57 4,633.48 -81.47 6,020,812.45 569,263.70 1.54 2,100.81 2_MWD+IFR2+MS+Sag (2) 7,415.97 84.12 286.18 4,352.49 4,304.01 4,651.62 -141.04 6,020,830.03 569,203.98 3.83 2,162.30 2_MWD+IFR2+MS+Sag(2) 7,479.01 84.61 285.24 4,358.68 4,310.20 4,668.60 -201.43 6,020,846.45 569,143.44 1.68 2,224.04 2_MWD+IFR2+MS+Sag(2) 7,542.07 84.18 285.15 4,364.84 4,316.36 4,685.05 -261.99 6,020,862.33 569,082.73 0.70 2,285.69 2_MWD+IFR2+MS+Sag(2) 7,605.20 85.11 283.92 4,370.73 4,322.25 4,700.82 -322.63 6,020,877.54 569,021.75 2.44 2,347.30 2_MWD+IFR2+MS+Sag (2) 7,668.50 84.73 284.28 4,376.33 4,327.85 4,716.18 -383.98 6,020,892.33 568,960.46 0.83 2,409.01 2_MWD+IFR2+MS+Sag(2) 7,731.89 84.18 284.82 4,382.46 4,333.98 4,732.03 .445.05 6,020,907.61 568,899.25 1.21 2,470.86 2_MWD+IFR2+MS+Sag(2) 7,794.76 83.99 284.58 4,388.94 4,340.46 4,747.90 -505.54 6,020,922.91 568,838.62 0.49 2,532.19 2_MWD+IFR2+MS+Sag (2) 7,858.33 83.37 285.01 4,395.93 4,347.45 4,764.04 -566.63 6,020,938.47 568,777.39 1.18 2,594.18 2_MWD+IFR2+MS+Sag (2) 7,921.51 86.54 285.03 4,401.49 4,353.01 4,780.35 -627.41 6,020,954.21 568,716.47 5.02 2,655.96 2_MWD+IFR2+MS+Sag (2) 7,984.76 90.31 285.52 4,403.23 4,354.75 4,797.00 -688.39 6,020,970.30 568,655.35 6.01 2,718.09 2_MWD+IFR2+MS+Sag(2) 8,026.96 90.24 286.06 4,403.03 4,354.55 4,808.48 -728.99 6,020,981.40 568,614.64 1.29 2,759.62 2_MWD+IFR2+MS+Sag (2) 8,077.74 90.02 289.23 4,402.91 4,354.43 4,823.87 -777.38 6,020,996.34 568,566.12 6.26 2,809.86 2_MWD+IFR2+MS+Sag (3) 8,141.19 89.33 291.61 4,403.27 4,354.79 4,846.01 -836.84 6,021,017.92 568,506.46 3.91 2,873.01 2_MWD+IFR2+MS+Sag (3) 8,203.98 89.95 291.78 4,403.66 4,355.18 4,869.22 -895.18 6,021,040.58 568,447.91 1.02 2,935.63 2_MWD+IFR2+MS+Sag(3) 8,267.21 90.07 291.02 4,403.65 4,355.17 4,892.29 -954.05 6,021,063.10 568,388.83 1.22 2,998.66 2_MWD+IFR2+MS+Sag(3) 1282019 3:45:03PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-37 MPU E-37 Pet MPU E-37 Pet Local Coordinate Reference: Well MPU E-37 TVD Reference: MPE-37 Actual RKB @ 48.48usft MD Reference: MPE-37 Actual RKB @ 48.48usft 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 8,330.41 90.44 288.68 4,403.37 4,354.89 4,913.75 -1,013.49 6,021,084.00 568,329.20 3.75 3,061.50 2_MWD+IFR2+MS+Sag(3) 8,393.72 89.82 285.54 4,403.23 4,354.75 4,932.37 -1,073.99 6,021,102.06 568,268.54 5.06 3,124.04 2_MWD+IFR2+MS+Sag(3) 8,456.51 90.69 283.16 4,402.95 4,354.47 4,947.93 -1,134.81 6,021,117.05 568,207.58 4.04 3,185.55 2_MWD+IFR2+MS+Sag(3) 8,519.96 89.45 281.31 4,402.87 4,354.39 4,961.38 -1,196.82 6,021,129.92 568,145.45 3.51 3,247.18 2_MWD+IFR2+MS+Sag(3) 8,583.09 89.82 281.07 4,403.27 4,354.79 4,973.63 -1,258.75 6,021,141.59 568,083.42 0.70 3,308.23 2_MWD+IFR2+MS+Sag (3) 8,646.27 89.08 280.66 4,403.88 4,355.40 4,985.54 -1,320.79 6,021,152.92 568,021.27 1.34 3,369.23 2_MWD+IFR2+MS+Sag (3) 8,709.04 89.70 280.51 4,404.55 4,356.07 4,997.07 -1,382.49 6,021,163.88 567,959.48 1.02 3,429.75 2_MWD+IFR2+MS+Sag (3) 8,772.08 89.33 281.30 4,405.08 4,356.60 5,008.99 -1,444.39 6,021,175.22 567,897.48 1.38 3,490.63 2_MWD+IFR2+MS+Sag(3) 8,835.21 89.33 281.78 4,405.82 4,357.34 5,021.62 -1,506.24 6,021,187.27 567,835.52 0.76 3,551.77 2 MWD+IFR2+MS+Sag(3) 8,898.96 88.34 283.66 4,407.12 4,358.64 5,035.66 -1,568.41 6,021,200.73 567,773.23 3.33 3,613.81 2_MWD+IFR2+MS+Sag(3) 8,961.84 87.85 284.84 4,409.21 4,360.73 5,051.12 -1,629.32 6,021,215.63 567,712.18 2.03 3,675.35 2_MWD+IFR2+MS+Sag (3) 9,025.59 88.03 287.01 4,411.50 4,363.02 5,068.60 -1,690.58 6,021,232.53 567,650.77 3.41 3,738.08 2_MWD+IFR2+MS+Sag(3) 9,087.06 87.72 289.15 4,413.78 4,365.30 5,087.67 -1,748.97 6,021,251.05 567,592.21 3.52 3,798.92 2_MWD+IFR2+MS+Sag(3) 9,151.07 88.34 290.66 4,415.98 4,367.50 5,109.45 -1,809.12 6,021,272.26 567,531.86 2.55 3,862.54 2 MWD+IFR2+MS+Sag(3) 9,213.66 89.77 290.63 4,417.01 4,368.53 5,131.51 -1,867.68 6,021,293.78 567,473.10 2.29 3,924.85 2_MWD+IFR2+MS+Sag (3) 9,277.66 90.32 290.50 4,416.96 4,368.48 5,153.99 -1,927.60 6,021,315.70 567,412.98 0.88 M 3,988.57 2_WD+1FR2+MS+Sag (3) 9,340.65 89.70 290.40 4,416.95 4,368.47 5,176.00 -1,986.62 6,021,337.16 567,353.76 1.00 4,051.27 2_MWD+IFR2+MS+Sag (3) 9,403.60 89.33 290.31 4,417.48 4,359.00 5,197.89 -2,045.63 6,021,358.50 567,294.55 0.60 4,113.92 2_MWD+IFR2+MS+Sag(3) 9,466.00 88.46 290.11 4,418.69 4,370.21 5,219.45 -2,104.18 6,021,379.50 567,235.81 1.43 4,175.99 2_MWD+IFR2+MS+Sag (3) 9,529.94 88.65 289.99 4,420.30 4,371.82 5,241.36 -2,164.23 6,021,400.85 567,175.57 0.35 4,239.57 2_MWD+IFR2+MS+Sag(3) 9,593.42 89.70 290.09 4,421.21 4,372.73 5,263.11 -2,223.86 6,021,422.05 567,115.75 1.66 4,302.71 2_MWD+IFR2+MS+Sag (3) 9,655.60 90.38 290.73 4,421.17 4,372.69 5,284.80 -2,282.13 6,021,443.19 567,057.28 1.50 4,364.60 2_MWD+IFR2+MS+Sag(3) 9,719.31 89.45 290.54 4,421.26 4,372.78 5,307.25 -2,341.75 6,021,465.08 566,997.46 1.49 4,428.03 2_MWD+IFR2+MS+Sag(3) 9,782.81 89.64 290.31 4,421.77 4,373.29 5,329.41 -2,401.26 6,021,486.68 566,937.75 0.47 4,491.23 2_MWD+IFR2+MS+Sag (3) 9,845.64 90.88 290.95 4,421.48 4,373.00 5,351.54 -2,460.06 6,021,508.27 566,878.75 2.22 4,553.79 2_MWD+IFR2+MS+Sag (3) 9,908.38 91.62 290.81 4,420.11 4,371.63 5,373.90 -2,518.66 6,021,530.07 566,819.95 1.20 4,616.27 2_MWD+IFR2+MS+Sag (3) 9,971.89 93.79 291.43 4,417.12 4,368.64 5,396.76 -2,577.84 6,021,552.38 566,760.57 3.55 4,679.48 2_MWD+IFR2+MS+Sag(3) 10,034.97 94.34 292.75 4,412.65 4,364.17 5,420.42 -2,636.14 6,021,575.49 566,702.06 2.26 4,742.26 2_MWD+IFR2+MS+Sag(3) 10,098.37 92.41 293.04 4,408.91 4,360.43 5,445.04 -2,694.44 6,021,599.57 566,643.53 3.08 4,805.45 2_MWD+IFR2+MS+Sag (3) 10,161.06 91.86 293.37 4,406.58 4,358.10 5,469.72 -2,752.02 6,021,623.71 566,585.73 1.02 4,868.03 2_MWD+IFR2+MS+Sag (3) 10,224.47 92.42 295.22 4,404.21 4,355.73 5,495.79 -2,809.77 6,021,649.24 566,527.75 3.05 4,931.36 2_MWD+IFR2+MS+Sag (3) 10,287.64 92.17 296.99 4,401.68 4,353.20 5,523.57 -2,866.45 6,021,676.48 566,470.82 2.83 4,994.48 2_MWD+IFR2+MS+Sag(3) 10,350.66 91.80 298.55 4,399.50 4,351.02 5,552.91 -2,922.18 6,021,705.30 566,414.83 2.54 5,057.43 2_MWD+IFR2+MS+Sag(3) 10,413.76 91.99 299.68 4,397.41 4,348.93 5,583.59 -2,977.27 6,021,735.47 566,359.45 1.81 5,120.40 2_MWD+IFR2+MS+Sag (3) 10,476.93 92.54 301.94 4,394.91 4,346.43 5,615.92 -3,031.48 6,021,767.29 566,304.95 3.68 5,183.29 2_MWD+IFR2+MS+Sag (3) 10,539.80 93.60 304.30 4,391.55 4,343.07 5,650.22 -3,084.06 6,021,801.09 566,252.06 4.11 5,245.57 2_MWD+IFR2+MS+Sag (3) 10,603.22 94.33 306.83 4,387.16 4,338.68 5,687.02 -3,135.52 6,021,837.40 566,200.27 4.14 5,307.94 2_MWD+IFR2+MS+Sag(3) 10,664.42 95.03 309.12 4,382.17 4,333.69 5,724.54 -3,183.60 6,021,874.48 566,151.84 3.90 5,367.60 2_MWD+IFR2+MS+Sag(3) 10,728.47 95.70 311.19 4,376.18 4,327.70 5,765.66 -3,232.33 6,021,915.14 566,102.73 3.38 5,429.41 2_MWD+IFR2+MS+Sag (3) 10,791.00 94.52 311.31 4,370.61 4,322.13 5,806.73 -3,279.16 6,021,955.76 566,055.53 1.90 5,489.49 2_MWD+IFR2+MS+Sag(3) 1/2872019 3:45:03PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-37 Wellbore: MPU E-37 PB1 Design: MPU E-37 PB1 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (1) V) (usft) (usft) (usft) 10,854.21 92.91 311.93 4,366.51 4,318.03 5,848.62 10,918.69 94.34 312.35 4,362.43 4,313.95 5,891.80 10,982.04 95.45 313.10 4,357.03 4,308.55 5,934.62 11,051.00 95.45 313.10 4,350.48 4,302.00 5,981.53 Local Co-ordinate Reference: Well MPU E-37 TVD Reference: MPE-37 Actual RKB @ 48.48usft MD Reference: MPE-37 Actual RKB @ 48.48usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA -3,470.52 6,022,128.75 565,862.57 0.00 5,738.04 PROJECTEDto TD Checked By: Chelsea Wright <d—_MApproved By: Mitch Laird Date: 1-28-2019 1/282019 3..45:03PM Page 7 COMPASS 5000.15 Build 91 Map Map vertical +El -W Northing Easting DLS Section (usft) (ft) (ft) (°1100') (ft) Survey Tool Name -3,326.31 6,021,997.21 566,007.99 2.73 5,550.22 2_MWD+IFR2+MS+Sag(3) -3,374.03 6,022,039.93 565,959.88 2.31 5,612.01 2_MWD+IFR2+MS+Sag (3) -3,420.39 6,022,082.32 565,913.12 2.11 5,672.45 2_MWD+IFR2+MS+Sag(3) -3,470.52 6,022,128.75 565,862.57 0.00 5,738.04 PROJECTEDto TD Checked By: Chelsea Wright <d—_MApproved By: Mitch Laird Date: 1-28-2019 1/282019 3..45:03PM Page 7 COMPASS 5000.15 Build 91 Lease & Well No. County Hi/corp Energy Company CASING & CEMENTING REPORT MP E-37 Date Run 10Jan-19 State Alaska Sup;. S Barber/ C Montague CASING RECORD sum . 13 TO 8,066.00 Shoe Depth: 8,056.00 PBTD: 7,934.34 No. Jts. Delivered 2051 No .Its. Run 90S Nn .Its RMu-n! 4 Csg Wt. On Hook: 330 Type Float Collar. Conventional No. Hrs to Run: Casing (Or Liner) Detail Csg Wt, On Slips: 60,000 Type of Shoe: BWlnose Setting Capons its. Component Size Wt. Grade THD Make Length Bottom Top Liner top Packer: Shoe 103/4 40.0 L-80 TXP DHP 1.60 8,056.00 8,054.40 2 Casing 95/8 40.0 L-80 TXP 60 Mixing/ Pumping Rate (bpm): 78.33 8,054A0 7,976.07 Float Collar 103/4 40.0 L-80 TXP DHP 1.29 7,976.07 7,974.78 1 Casing 95/8 40.0 L-80 TXP asing Rotated? _Yes 38.98 7,974.78 7,935.80 sment returns to surface? X Baffie Ada ter 103/4 240 smart In Place At 2010 TXP Halliburton 1.46 7,935.80 7,934.34 140 Casing 95/8 40.0 L-80 TXP 5,475.81 7,934.34 2,458.53 Pup Joint -Casing 95/8 40.0 L-80 TXP 14.04 2,458.53 2,444.49 ES Cementer 113/4 TXP Halliburton 11.84 2,444.49 2,432.65 Pup Joint -Casin 95/8 40.0 L-80 TXP 13.65 2,432.65 2,419.00 61 Casin 95/8 40.0 L-80 TXP 2,385.19 2,419.00 33.81 Cut Joint 95/8 40.0 L-80 TXP 6.99 1 33.81 26.82 Csg Wt. On Hook: 330 Type Float Collar. Conventional No. Hrs to Run: 29 Csg Wt, On Slips: 60,000 Type of Shoe: BWlnose Casing Crew: WeaheTrd Rotate Csg Yes X No Recip Csg X Yes No a0 Ft. Min. 9.5 PPG Fluid Description: Spud Mud In Place At: 911 Date: 1111f2019 Liner hanger Info(MakeNodel): Liner top Packer: No Liner hanger test pressure: Floats Held _Yes X Yes No Centralizer Placement: 2 -10' from collars an joint 1 1 - mid tube on joints 2, 3 Sacks: 289 Yield 1.17 1 each on joints 4 -25 Volume pumped (BBLs) 60 Mixing/ Pumping Rate (bpm): 2.4 1 every other joint from pint 25 -43 1 every joint 5 pints (139-143) before stage collar and 10 joints (144-153) after stage collar Rate (bpm): Volume: 1 every other joint on joint 155 -195 CEMENTING REPORT Shoe Q 8056 FC @ 7,974.78 Top of Liner .. Clean Spacer Density(ppg) 10 Volume pumped (BBLs) d Slurry s: Type Illi Sacks: 763 Yield: sity(ppg) 12 Volume pumped (BBLs) 32V Miring/ Pumping Rate (bpm): Slurry .. Premium Class G Sacks: 398 Yield: sity (ppg) 15.8 Volume pumped (BBLs) 82 Maung / Pumping Rate (bpm): t Flush (Spacer) Rate (bpm): Volume: Drilling Fluid Density(ppg) 9.5 Rate(bpm): 3 Volume (actual /calculated): 61 :i): 850 Pump used for disp: Rig Bump Plug? X Yes -No Bump press Rotated? Yes X No Reciprocated? X Yes No % Returns during job i( returns to surface? _Yes X No SpacormWms?_Yes X No Vol to Sud 8 In Place At: 911 Date: 1111f2019 Estimated TOC 2,432 Used To Determine TOC: Returns after beeline areas .[no Volume pumped (BBLs) 308 Mixing / Pumping Rate (bpm): Stage Collar @ 2432.56 Type ES Cementer Closure OK Yes re0ush(Spacer) me: Clean Spacer Density Ping) I Volume pumped (BBLs) 53 sad Slurry /pe: PemlaFrostL Sacks: 400 Yield: 4.33 ensity (ppg) 11.1 Volume pumped (BBLs) 308 Mixing / Pumping Rate (bpm): 6.5 III slurry rpe: Premium Class Sacks: 289 Yield 1.17 ansity(ppg) 15.8 Volume pumped (BBLs) 60 Mixing/ Pumping Rate (bpm): 2.4 sat Flush (Spacer) rpe: Density(ppg) Rate (bpm): Volume: Isplacement: rpe: Drilling Fluid Density (ppg) 9.5 Rate (bpm): 4.5 Volume (actual / calculated): 185/185 :P (psi): 570 Pump used for disp: Rig Bump Plug? X Yes -No Bump press 2( asing Rotated? _Yes X No Reciprocated? Yes X No % Returns during job 100 sment returns to surface? X Yes _No $pacerretums? X Yes No Vol to Surf: 240 smart In Place At 2010 Date: 1/1112019 Estimated TOC' 27 amen Used To Determine TOC: Returns Calculated Cmt Vol @ 0% excess: 482.2 Total Volume cmt Pumped: Chit returned fo surface: 240 Calculated cement left in wellbore: 530 OH volume Calculated 482 OH volume actual: 530 Actual % Washout: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Pool, MPU E-37 Hilcorp Alaska, LLC Permit to Drill Number: 218-158 Alaska Oil and Gas Conservation Commission Surface Location: 3641' FSL, 1757' FEL, SEC. 25, T13N, R10E, UM, AK Bottomhole Location: 400' FSL, 2526' FEL, SEC. 14, T13N, R10E, UM, AK Dear Mr. Myers: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wvvw.a ogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. 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 Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: • Gamma ray and resistivity logs required from base of conductor to TD. 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, Hollis S. French {� Chair DATED this ( day of December, 2018. IFIECEI ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV Z 7 2018 PERMIT TO DRILL 20 AAC 25.005 A 0-% � 1 a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas LJ Service - WAG Ll Service - Disp ❑ 1c. SpecilMi or: Drill ❑� - Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑� • Service - Winj ❑ Single Zone ❑v Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q. Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244. MPU E-37 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 13,943' TVD: 4,333' Milne Point Field Schrader Bluff Oil Pool . 4a. Location of Well (Governmental Section): 7. Property Designation: _ Surface: 3641' FSL, 1757' FEL, Sec 25, T13N, R10E, UM, AK ADL02551 i / ADL047437 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2202' FNL, 2181' FEL, Sec 24, TI 3N, R1 OE, UM, AK LONS 94-017 12/13/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 400' FSL, 2526' FEL, Sec 14, TI 3N, R10E, UM, AK 5120 7714' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.2 15. Distance to Nearest Well Open Surface: x-569388 y- 6016180 • Zone -4 GL / BF Elevation above MSL (ft): 21.7 to Same Pool: MPC -411_21850' 16. Deviated wells: Kickoff depth: 280 feet • 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.1 degrees Downhole: 1925 Surface: 1488 1 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" - X-52 Weld 107' Surface Surface 107' 107' ±270 ft3 Sig 1 L - 1691 ft3 / T - 458 0 12-1/4" 9-5/8" 40# L-80 TXP 7,653' Surface Surface 7,653' ' 4,375' Sig 2 L- 1937 ft3 / T - 314 ft3 Tieback 7-5/8" 29.7# L-80 Hyd 521 7,503' Surface Surface 7,503' 4,362' Tieback Assy 8-1/2" 6-5/8" 20# L-80 Hyd 563 6,440' 7,503' 4,362' 13,943' 4,333' PreDrilled 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 ❑4 20. Attachments: Property Plat Q BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch B Seabed Report B Drilling Fluid Program e 20 AAC 25.050 requirements e 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email:en el hilcor .Com Authorized Title: mm erS hilcor .com Contact Phone: 777-8395 Authorized Signature Date: (1, 2 7 -ZD � p Commission Use Only Permit to Drill .� (a _ API Number: / ��_Q- Permit Approval See cover letter for other Number. L 50 -OZ - Z�> Date: requirements. Conditions of approval : If box is checke , well may not be used to explore for, test, or produce coalbed methane, as hydrates, /56) or gas contained in shales: Other: y 3000 ,p S. to�S {- T Samples req'd: Yes ❑ No [2 Mud log req'd: Yes E] No / n h t •-�E / wCR•✓ I Y % HzS measures: Yes rz] No ❑ Directional svy req'd: Yes v❑�No ❑ Z.Si> 0 PS ` l7 Spacing exception req'd: Yes ❑ No E?( Inclination -only svy req'd: Yes ❑ No [Y� Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY /l (. I n Approved by: C I SIO R THE COMMISSION Date: I Z 1 TQC T/%- / Z- -1, _ 1y U {.f W4 NA� Submit Form and Form 10-401 Revised 5120170 This permit Is valid fo t t e royal per 20/AA C 25.005(8) Anacn is in oupliwt Hilcorp Alaska, LLC Milne Point Unit (MPU) E-37 Drilling Program Version 1 11/27/2018 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 10.0 N/U 13-5/8" 5M Diverter Configuration.....................................................................................11 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 14.0 BOP NIU and Test.........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 6-5/8" Production Pre -Drilled Liner...................................................................................31 17.0 Run 7-5/8" Tieback.......................................................................................................................36 18.0 Run ESP Assembly........................................................................................................................39 19.0 RDMO............................................................................................................................................40 20.0 Innovation Rig Diverter Schematic.............................................................................................41 21.0 Innovation Rig BOP Schematic....................................................................................................42 22.0 Wellhead Schematic......................................................................................................................43 23.0 Days Vs Depth................................................................................................................................44 24.0 Formation Tops & Information...................................................................................................45 25.0 Anticipated Drilling Hazards.......................................................................................................47 26.0 Innovation Rig Layout..................................................................................................................49 27.0 FIT Procedure................................................................................................................................50 28.0 Innovation Rig Choke Manifold Schematic................................................................................51 29.0 Casing Design.................................................................................................................................52 30.0 8-1/2" Hole Section MASP............................................................................................................53 31.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................54 32.0 Surface Plat (As Built) (NAD 27).................................................................................................55 33.0 Schrader Bluff OA Sand Offset MW vs TVD Chart ..................................................................56 34.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50...............................................................57 1.0 Well Summary Milne Point Unit E-37 SB Producer Drilling Procedure Well MPU E-37 Pad Milne Point "E" Pad Planned Completion Type ESP on 2-7/8" Production Tubing Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD / TVD 13,943' MD / 4,333' TVD PBTD, MD / TVD 13,933' MD / 4,333' TVD Surface Location (Governmental) 3641' FSL, 1757' FEL, Sec 25, T13N, R10E, UM, AK Surface Location (NAD 27) X= 569,388.31, Y= 6,016,180.37 Top of Productive Horizon (Governmental) 2202' FNL, 2181' FEL, Sec 24, T13N, R10E, UM, AK TPH Location (NAD 27) X= 568,919.89 Y= 6,020,892.36 BHL (Governmental) 400' FSL, 2526' FEL, Sec 14, T13N, R10E, UM, AK BHL (NAD 27) X= 563,269.99, Y=6,023,444.00 AFE Number 1813044 AFE Drilling Das 18 days AFE Completion Das 9 days AFE Drilling Amount $4,572,411 AFE Completion Amount $2,435,633 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1488 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1925 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 21.7 ft = 48.2 If GL Elevation above MSL: 21.7 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Milne Point Unit E-37 SB Producer Drilling Procedure Management of Change Information 11 Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: 11/2712018 1 Subject: Changes to Approved Permit to Drill for MPU E-37 File #: MPU E-37 Drilling and Completion Program Any modifications to MPU E-37 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the AOGCC. Approval: Drilling Manager Prepared: Drilling Engineer Page 3 H Hilcorp E. W �vdr 3.0 Tubular Program: Milne Point Unit E-37 SB Producer Drilling Procedure 4.0 Drill Pipe Information: OD in in Max Surface& 5" 4.276" 3.25" 6.625" 19.5 5-135 GPDS50 36,100 43,100 560klb Production 5" 4.276" 1 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wel1Ez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcoip.com, mmyers e hilcQM, jeneel(2hilcorp.com and cdingernhilcoip.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 mmyers e hilcorp,com ieneelnhilcorp.com and cdinizer@hilcgM.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcorp.com hilcorp.com ieneel@hilcorp.com and cdingerna hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Milne Point unit Monty Myers 907.777.8431 907.538.1168 E-37 SB Producer 1 Drilling Engineer Hilco Em Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wel1Ez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcoip.com, mmyers e hilcQM, jeneel(2hilcorp.com and cdingernhilcoip.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 mmyers e hilcorp,com ieneelnhilcorp.com and cdinizer@hilcgM.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcorp.com hilcorp.com ieneel@hilcorp.com and cdingerna 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 ieneel@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.907.9533 twellman@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcoro.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcoro.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleminR@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones�hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger�hilcoro.com Page 5 ff Hilcorp U-2 6.0 Planned Wellbore Schematic Proposed SCHEMATIC Ong KB Ep✓.: 265'Qmovldvp Page 6 TREE & WELLHEAD CEMENT DETAIL Milne Point Unit E-37 SB Producer Drilling Procedure ;Jilne Point Unit Well: MPU E-37 Last Completed: PTD: xxx-xxx 20" -270 R3 5.5 a dumped down hacksW. WV Grade/ Conn 51g -458 1, L-1 h3, T ft3 I Top I Stg2-193]R3,T-314169R3 20" Condutt r -/x-52 Welded I N/A CASING DETAIL Size Type WV Grade/ Conn I ID I Top I Btm 20" Condutt r -/x-52 Welded I N/A I Surface 1 ±107' 938" I Surface 40/L41 MP 1 8.835 Surfau I ±7,653' 7-58" 1 Tieback 1 29.71 L43)ltbA521. 1 6.875 5urfax 1 ±7503' 65/8' 1 EMQ0(?&Uner I 20/1,-80/ 563 1 6.049 1 ±7,503' 1 ±13,943' TUBING DETAIL 2-78" Tubing 6.5/L430 WEBrd I 2"J. Surtax ±7,300' 3/8^ I Dual 53BFVIJx I BS I N/A ISprface ±±7,300 WELL INCLINATION DETAIL KOPp21W Olde Role Mel.. 91.1 deg. �7,806' JEWELRY DETAIL No Depth Item 1 ±331' 5M M2: GLM- 1' Bide Pocket KBMM w/Orifi. 2 ±7 o0Cr §3g *Ir GL W P W/ Dummy 3 ±7200' 2-7/8" M.Np (2.205 No ID) 4 ±7,2 Dischar Head: FPDIS 5 ±7,234 Upper Tandem Pump: 62 SRS RL 175 6 ±7240' Loner Tandem P..p: 134 STG FLEK 17.5 7±7,250' Gas Separator Glia FER N AR 8 ±7260' UPW Tandem Seal: G583DBUT SB/SB PF SA 9 ±7,270' Lower Tandem Seal: GS83081.rr 58/58 PFSA 10 ±7,2W Motor CLS XP- 200hp / M35V / 34A 11 ±7,290' Se. , Zenith S/S T812629 12 17,300 Centralizer: 13 ±7,503' BOT SL PUner Top FV w/8D Slips, 7"x95/8" 14 ±] 530 Crpstover Sub, T 4563 x 6.625" V,,a 563 15 ±13 Ori' Crossover Sub 6.625" tW563. 4.5- 16 1 XW 41 Drilla We Sub 17 ±13,940' W Valve with J' Rall on Seat 18 13,943' Round N.e Flort Bh.: GENERAL WELL INFO AFI: SO -029-..,-00-00 Odlled Cased and Co.~ b, Innovation - 6-5/8" Predrilletl Liner Debil 6S: 3' Pzedrilled Liner '• 8 hdes'fmt 3:8" Inl lx 6 [ 7.7 -" free caul' 7.0 Drilling / Completion Summary MPU E-37 is a grassroots ESP producer planned to be drilled in the Schrader Bluff OA sand. E-37 is part of an eight well program targeting the Schrader Bluff sand on E -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" pre -drilled liner will be run in the open hole section and the well produced with an ESP assembly. The Inn 11 be used to drill and complete the wellbore. Drilling operations are expected to commence approximately Dec 13, 2018, pending rig schedule. Surface casing will be run to 7,653' MD / 4,327' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. NX & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. N/D diverter, NX & test 13-5/8" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner. 6. Run 7-5/8" tieback. 7. Run production tubing. 8. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Point unit E-37 SB Producer Hilco Drilling Procedure 7.0 Drilling / Completion Summary MPU E-37 is a grassroots ESP producer planned to be drilled in the Schrader Bluff OA sand. E-37 is part of an eight well program targeting the Schrader Bluff sand on E -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" pre -drilled liner will be run in the open hole section and the well produced with an ESP assembly. The Inn 11 be used to drill and complete the wellbore. Drilling operations are expected to commence approximately Dec 13, 2018, pending rig schedule. Surface casing will be run to 7,653' MD / 4,327' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. NX & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. N/D diverter, NX & test 13-5/8" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner. 6. Run 7-5/8" tieback. 7. Run production tubing. 8. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 H Hilcorp E• C= Milne Point Unit E-37 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 E-37. Ensure to provide AOGCC 24 his 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 fluidflow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: Hilcorp Alaska LLC does not request any variances at this time. Page 8 H Hilcorp M= Summary of BOP Equipment and Test Requirements Milne Point Unit E-37 SB Producer Drilling Procedure Hole Section Equipment Test Pressure(psi) 12 1/4" • 13-5/8" 5M CTI Annular BOP w/ 16" diverter line Function Test Only • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" 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. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-xxx-xxxx / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorsna alaska.gov Test/Inspection notification standardization format: htW://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 9 H Hilcorp ��r 9.0 R/U and Preparatory Work Milne Point Unit E-37 SB Producer Drilling Procedure 9.1 E-37 will utilize a newly set 20" conductor on E Pad Expansion. Ensure to review attached surface plat and make sure rig is over appropriate con uc or. 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 RAJ. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation Rig. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<80°F). 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 10 H Hilcorp ��-2 10.0 N/U 0-5/8" 5M Diverter Configuration Milne Point Unit E-37 SB Producer Drilling Procedure 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • N/U 20" x 13-5/8" DSA • N/U 13 5/8", 5M diverter "T". • NU Knife gate & 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. • Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking A prohibition on ignition sources or running equipment A prohibition on staged equipment or materials Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 Milne Point unit E-37 SB Producer HUCO Drilling Procedure e�c®� 10.5 Rig & Diverter Orientation: I 13 ■ ■ 5 26 ■ ■ 30 9 ■ ■ 6 25 ■ 0 2 11 ■ ■ 7 18 ■ ■ 16 20 ■ ■ 23 tf I 24 ■ ■ 19 ( + IJ 14 ■ 12 E -37E 1 II{ 1 15 ■ 17 E-35', ! E-38 E-37 �. __.•' E-39 E-36 E-41 E-35 7S' Radius Clear of Ignition Sources — Diverter line MPU E Pad Expansion 'Drawing Not To scale Page 12 H Hilcorp M� 11.0 Drill 12-1/4" Hole Section Milne Point Unit E-37 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# 5-135. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4" hole section to section TD, in the 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. ESP equipment can be damaged if run through high dog legs. 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 to leave a "Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. Target location of ESP pump tangent is 1000' MD and 200' TVD above target reservoir. • 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). Page 13 Milne Point Unit E-37 SB Producer Drilling Procedure Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Gas hydrates have been encountered on E -Pad, typically around 2100-2400' TVD (lust 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 • Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin & .5% lube. After drilling through hydrate sands, MW was cut back to normal • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. 11.5 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interyal MW g) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.8 For Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • 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 14 n Hilcorp Eo C®p�uy Milne Point Unit E-37 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 — 9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH I Tem Surface 8.8-9.8 75-175 20-40 25-45 <10 8.5-9.0 570F System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 — 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.2 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.7 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 —10 ft / minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.8 TOOH and LD BHA 11.9 No open hole logging program planned. Page 15 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. Milne Point Unit E-37 SB Producer Drilling Procedure 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 PIU shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consisting of: 9-5/8" Float Shoe 1 joint — 9-5/8" DWC, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" DWC, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' 1 joint — 9-5/8" DWC, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle LIN • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 16 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pins Dpening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter (d used) ID Depth or Shut-off Baffle to— Depth D_Depth Float Collar Depth _ Float Shoe Depth — Hole TD _ "Reference Casing Sales Manual S.,=n 5 Page 17 "A Hkwp 1511 gunning Order Part No. Overall Length B Shut Otr mug M.. ID After Drliloue C OD Max. TWI OD D Opening Plug op rev Seat ID E OD Clasing Seat 10 Plug Set Hkwp 1511 gunning Order Part No. ESll Cementer SO No. Shut Otr mug Closing Plug OD By-0ass pug LL1j Opening Plug By pass Batik OD OD Shut-off Plug OD Bypass Plug (d used) OD Milne Point Unit E-37 SB Producer Drilling Procedure Z Hkwp 1511 gunning Order ESll Cementer Shut Otr mug Batik Adapter By-0ass pug LL1j By pass Batik Fred WW Heat Shoe Z 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 10 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/81140# L-80 TXP Make Up Torques: Casing OD Minimum Milne Point unit Maximum 9-5/8" 18,860 ft -lbs E-37 SB Producer 23,060 ft -lbs Hilcorp MCa 2 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 10 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/81140# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 TXPO BTC outside Diameter 9.62511. Wall Thickness 0.395 n. Grade LBO Type V Min. wall 87.516 Thickness Connection 00 Option REGULAR Connection OD REGULAR Option 1st Band. Red DnR FPI standard Type Casing Milne Point Unit E-37 SB Producer Drilling Procedure ...,. 11108,2018 I'I Grade LBO som Type 1 Connection 00 Option REGULAR COUPLING PIPE BODY Eody Red 1st Band. Red 1st sand: Braun 2nd Ban: 2nd Band: - Brown art Band, - 3rd Sand: - 916.000x1000 41n Bantl: - GEOMETRY Thratuds per it 5 Connection 00 Option REGULAR Nornmai OD Nominal ID 9.6n in. 8.935 in, rs minal might wa9Thickness 40 lost 0.395 n. Ddtt Plain End Might 8.679 m. 38.97 Post OD Tbiars oe API PERFORMANCE Body Yield Seergth 916 x1000 Bs ImemNyeld 5750 psi sms 90000 psi eabpse 3090:si GEOMETRY Connector. 00 10.825 in. co4im9 Le.1yh 10825 is Connection ID 8823 in Matte -up Loss 4891 in Thratuds per it 5 Connection 00 Option REGULAR PERFORMANCE Tension EAnienoy 100.0% :int Yisdsrsog:h 916.000x1000 Internal Pressure Capacity in 5750,000 psi lbs Compression EOrciency 100% Campn ian SMWh 916.000x1000 1.1ax. Almwable bending 382000t lbs Ettemal Pressure Capacity 3090.000 psi MAKE-UPTORQUES IS,omvm 188608-Pos Oponnum 20989 h-Ibs um 23968 h-IBs OPERATION LIMIT TORQUES Operating Torque 356008 -Bs Yield T.M.e 43400 B -@s This connection is fully interchangeable with TXn BTC - 9-625 in. - 36 / 43.5 t 47 / 53.5158.4 Ibsilt [7] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 50 / ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenants technical sales representative. Page 19 n Hilcorp E=W company Milne Point Unit E-37 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 20 n Hilcorp �r 13.0 Cement 9-5/8" Surface Casing Milne Point Unit E-37 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 1" stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1s' Stage Total Cement Volume: Page 21 3t3 sx 33 `t 12-1/4" OH x 9-5/8" � (6,653'- 2500') x .0558 bpf x 1.3 = 301.25 1691.4 Casing Total Lead 176.5 1691.4 12-1/4" OH x 9-5/8" (7,653'- 6,653') x .0558 bpf x 1.3 = 72.5 407 — Casing ~ 9-5/8" Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 3t3 sx 33 `t Milne Point Unit E-37 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: %/�tL 7,533' x .0758 bpf = 571 bbls 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Lead Slurry Tail Slurry System ExtendaCEM 'm System SwiftCEM Im System Density 11.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: %/�tL 7,533' x .0758 bpf = 571 bbls 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 n HilcoT- rp �� Milne Point Unit E-37 SB Producer Drilling Procedure 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 330si to open circulating ports in stage collar. Slightly higher pressure may be necessary if'1'O07M-s 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. S • If ESIPC is ran, Increase pressure to 2090 psi to shift ESIPC sleeve and to begin inflating the packer. Inflate packer as per HEC rep. Reference ESIPC procedure. • Once ESIPC packer is inflated, increase pressure to 3000 psi to open rupture disc / circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 23 H Hilcorp E -W Camgvy Second Stage Surface Cement Job: Milne Point Unit E-37 SB Producer Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. (If ESIPC is used and packer element inflated, CBU x1 minimum before pumping second stage). Hold pre -job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2"d 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 2"d Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) 20" Conductor 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 a J 12-1/4" CH x 9-5 8" Casing (2000'- 110') x .0558 bpf 3 - 316.4 1776.3 Total Lead 345 1937 12-1/4" CIH x 9-5 8" Casi n (2500'- 2000') x .0558 bpf 2 - 55.8 314 ~ Total Tail 55.8 314 Cement Slurry Design (2nd stage cement job): Page 24 y 90 `* Lead Slurry Tail Slurry System Permafrost L SwiftCEM TM System (Hal Cem) Density 10.7 lb/gal 15.8 lb/gal Yield 4.3279 ft3/sk 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk Page 24 y 90 `* H Hilcarp W Milne Point Unit E-37 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 = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 —1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns duringjob, 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 successor problems during the cement job Send final "As -Run" casin tally & casing and cement report to jeW'e1@hilcorp.com and cdin er ,hilcoT.com This will be included with the EOW documentation that goes to the AOGCC. Page 25 H Hilc F'X22 Milne Point Unit E-37 SB Producer Drilling Procedure 14.0 BOP N/U and Test 14.1 N/D the diverter T, 16" knife gate, 16" diverter line & N/U 11" x 13-5/8" 5M casing spool. 14.2 N/U 13-5/8" x 5M CTI BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5.5" VBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 5.5" VBRs or 5" Solid Body Rams • N/U bell nipple, install flowline. i Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5" BOP test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Confirm test pressures with PTD • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.4 R/D BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set wearbushing in wellhead. 14.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.9 Ensure 5" liners in mud pumps. Page 26 15.0 Drill 8-1/2" Hole Section 15.1 MM 8.5" Cleanout BHA (Milltooth Bit & 1.22° PDM) Milne Point Unit E-37 SB Producer Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC taggo on morning report. �L yo */�t) .tX 15.4 R/U and test casing to 2500 psi / 30 min. Ensure to record vo ume / pressure and plot on FIT CL's` graph. AOGCC reg is 50% of burst = / 2 = — Tsi, but max test pressure on the well is 2,500 psi as per AOGCC. Document it?cremental s ine pumped (and subsequent pressure) and At volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH & LD Cleanout BHA 15.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 15.10 8-1/2" hole section mud program summary: Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Page 27 v H Hilcorp M Milne Point Unit E-37 SB Producer Drilling Procedure • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9-9.5 ppg Baradrill-N drilling fluid Properties: Section Denslt I Plastic Viscosity Yield Point I Total Solids I MBT I HPHT Productio 8.9-9. 15-25 1 20-25 1 <10% 1 <7 1 <11.0 System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-C1DE 207 0.015 ppb Page 28 H Hilcorp 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Milne Point Unit E-37 SB Producer Drilling Procedure 15.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OAl & 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% 15.15 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 29 H H lc -1 Milne Point Unit E-37 SB Producer Drilling Procedure 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Once well has TD'd the production lateral, swap to the completion AFE • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe 15.18 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.19 Monitor well for flow. Increase mud weight if necessary Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 15.20 POOH and LD BHA. Rabbit DP on TOIL ensure rabbit diameter is sufficient for future ball drops. 15.21 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 30 16.0 Run 6-5/8" Production Pre -Drilled Liner 16.1. 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: • PIU & 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 position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. • Proceed with well kill operations. 16.2. Well control preparedness: In the event of an influx of formation fluids while running the 3- 1/2" inner string inside the 6-5/8" pre drilled liner: • P/U & M/U the 5" safety joint (with 6-5/8" x 3-1/2" triple connect crossover installed on bottom, TIW valve in open position on top, 3-1/2" handling joint above TIW). M/U 3-1/2" and then 6-5/8" to triple connect. • This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.3. R/U 6-5/8" pre -drilled 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. 16.4. Run 6-5/8" pre -drilled 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 packoff and float shoe on bottom. • 6-5/8" pre -drilled 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 # Hydril 563 Torque OD Minimum Optimum Maximum Yield Tor ue 6-5/8 Milne Point unit 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs E-37 SB Producer Hilco Drilling Procedure 16.0 Run 6-5/8" Production Pre -Drilled Liner 16.1. 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: • PIU & 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 position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. • Proceed with well kill operations. 16.2. Well control preparedness: In the event of an influx of formation fluids while running the 3- 1/2" inner string inside the 6-5/8" pre drilled liner: • P/U & M/U the 5" safety joint (with 6-5/8" x 3-1/2" triple connect crossover installed on bottom, TIW valve in open position on top, 3-1/2" handling joint above TIW). M/U 3-1/2" and then 6-5/8" to triple connect. • This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.3. R/U 6-5/8" pre -drilled 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. 16.4. Run 6-5/8" pre -drilled 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 packoff and float shoe on bottom. • 6-5/8" pre -drilled 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 # Hydril 563 Torque OD Minimum Optimum Maximum Yield Tor ue 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs Page 31 Wedge 56M Page 32 Outside D..M, 6625, wan Thidness OI86.n. Gmda LBO TypD t' GEOMETRY NOminal Go Nominal tl OD wlcrarx PERFORMANCE aWy YNd 51rcmIRi c UB . CONNECTION DATA GEOMETRY Min.N 11 Thipk..s co,n tiara OD Option Ddn Tyx yra11TN:Oness 450,1 cCc ID: Imamal r4a1e 3670— ST 5'% REGULAR AP1 Standard Casin® Milne Point Unit E-37 SB Producer Drilling Procedure I•) GnWe Leo Type 1 CCUFUNG Buy Red L -t BaM: Brpvm and Ba d:. 3rd Band . e......,111=2018 ow WEBOVY 1M Bac Red 2rn1 Bak: 13 p 3rd Band:. 41h Band.. 20A01C,d1 opo 5.95{:11. 0.29a,, Plain End M,11 19511Ls'a Connp.w w OKw REGULAR PERFORMANCE 6a90ra1=_LAYS T..,. Effi OM, 95_71. JNn1 Yx11 51Not 60000 CA Canneuv�C=i.39%. ;:unV<_2gm - 9.55 in. Gonwnkn to 5.999.11 Natr-up Lcss IA50.r T1111.o' n 3.19 Connp.w w OKw REGULAR PERFORMANCE T..,. Effi OM, 95_71. JNn1 Yx11 51Not 439363a10JJ NWm.Y PKssuIa CDD9[ry 6M -W P. MG Opmplesslan EB.cnry 10OA% 5rcr� /59-000,1000 ID: Ma. Arpwaca E.rd. 55.6'IIp00 E.W.i PmravlD Gaia:iry U1. AG0 P. ti0uplrq:ac¢Lpad 39606025 MAKE-UP TORQUES Mmmum 5900.^. -OK Opdmum 71W t,kv. N.uimum 10300 A 0, OPERATION LIMIT TORQUES Op0raleg Tmw- 310002-0, YWtl Tequp 36000410, BUCK -ON Mfimum 18W040s Mal:mum H390 p-Ivs Notes This connection is 4WIy interchangeable with_ Wedge 563£1- 6.525 in. - 2+4128132 IbsAl connections wilh DopelessS Technology are Bully compathle wth the same wnnection in its Standard version H Hilc ��22rp 6-5/8" Lower Completion Running Order Milne Point Unit E-37 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. RAJ false rotary and run 3-1/2" 9# Inner String • Ensure inner string is drifted for WIV closing ball OD 16.8. Before picking up Baker ZXP liner hanger/ packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/U Baker ZXP liner top packer to inner string and 6-5/8" liner. Fill liner tieback sleeve with "Xanplex", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.10. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/ liner on 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. 16.12. The inner string will prevent the DP from auto filling. Fill DP with mud every 5 stands, more frequently if SOW trend indicates. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, &20 rpm 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Rig up to pump down the work string with the rig pumps. Page 33 Milne Point Unit E-37 SB Producer Drilling Procedure NOTE: The wellbore will be swapped over to brine after the liner has reached TD to remove mud cake from the well bore. Mud cake will cause facility upsets. 16.18. Break circulation and circulate out the mud. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. Displace well to brine (-9.2 ppg KCl/NaCI). , over displace well by at least 100+ bbl. 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. 16.19. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers (if run). Do not exceed 1,600 psi while circulating as noted above. Note all losses. Confirm all pressures with Baker. 16.20. 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. 16.21. Displace 1.5 OH + Liner volume. 16.22. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.23. Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.24. Continue pressuring up to 2700 psi to set the ZXPN liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the Flexlock liner hanger to ensure the HRDE setting tool is in compression for release from the ZXPN liner hanger/packer. Continue pressuring up 4500 psi to activate the hydraulic pusher tool to set the ZXPN packer. This will also release the HRDE running tool. 16.25. 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, 16.26. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.27. 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. 16.28. P/U pulling 3-1/2" out of the pack off & displace out liner with two volumes at max rate. Note: Flexlock Liner Hanger & separate packer will be run, with a hydraulic running tool with exposed ports that may inhibit circulation through the toe of the 3-1/2". Page 34 ff Hilcorp Euv®Cmnyey Milne Point Unit E-37 SB Producer Drilling Procedure 16.29. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOIL L/D 3-1/2" inner string. Leave enough 5" DP racked back to trip back to 9- 5/8" shoe. 16.30. M/U 3.5" wash tool & RIH w/ remaining DP out of derrick to liner top. 16.31. Wash through liner top at max rate & circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.32. POOH & L/D remaining 5" HWDP. Page 35 17.0 Run 7-5/8" Tieback 17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 17.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7-5/8" (250/3000 psi) solid body casing rams. 17.2 RX 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 17.3 PIU tieback seal assembly and set in rotary table. Ensure 7-5/8" 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 7-5/8" annulus. 17.4 MX first joint of 7-5/8" to seal assy. 17.5 Run 7-5/8" 29.7# H521 tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 36 Milne Point Unit E-37 SB Producer HileDrilling Eveigy,,2ryT Procedure 17.0 Run 7-5/8" Tieback 17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 17.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7-5/8" (250/3000 psi) solid body casing rams. 17.2 RX 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 17.3 PIU tieback seal assembly and set in rotary table. Ensure 7-5/8" 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 7-5/8" annulus. 17.4 MX first joint of 7-5/8" to seal assy. 17.5 Run 7-5/8" 29.7# H521 tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 36 Wedge 5210 Milne Point unit E-37 SB Producer Hilco M.TP Drilling Procedure Wedge 5210 � rrt Da2ota Oalslde Dlammer 1.625. Min. IoWl f1.5`e Thickness I -i Grade Lep GNP Type 1 Wall Thickness p.575 T. Con:ncrtion OD REGULAR Option C"UNG MEscnY Gad' Red 111 cane Red Grade 1.60 Type 1' DnN AN SLlndanl 1v Dsd: I6rdwn 2M Band- 2nd Sand. • crown Tree Casing 3rd Lund. • Srd Gard:. SN Ford - FIDE 3CDY DATA Nominal cc 7.i25 m. NemhmPwai0hl 29-T6M0 Odll 6S5:n N...ID 6.675.n. 'hell TE28mzz 0.175m. finln End Via Win 2%Wt, 1, OGTemrarc6 API PERFORMANCE 1 sod, rwd sm"th 61381aalbc 1nMma YOld 6890 pal EL'Y=_ eaa06 us. fAraf'Gp a; 96 �1 CONNECTION DATA GEOMETRY Oannac0m W T.N7.n Gpn,.d", D saloon kla..-up Lcz 3.706.n Throa06pmin 3.26 Cannad.' MCeOcr. REGULAR PERFORMANCE Tnnzlon Eff.e,.y 712% Jain Ycld SV oh 986]96 .1o00 Y.mal Prrzura capa[f, 6696.000 ps les co.p.mEft*,," 673 597-s2Sa1000 Mae AN -w memdrq 363'ft0pn mi, exie..l R.. capvtty 4T90.s60 P. MAKE4IP TORQUES Melmum 6900`6, 0e0mum 101" td" 5tanmum. 147M b -las OPERATION LIMB TORQUES Opma4T Ta9up 35000t'll- KnW Tcryuc 53006:-mx Notes This connection is fay interchangeattie with Wedge 521 & - 7.625 in. - 264; 33.7134 RJs: t CGnraechms with Ltlpeles-0 Technology am fully compatible v.ith the same connection in its Standard version Page 37 Milne Point unit E-37 SB Producer Hilcorp Drilling Procedure Ennp'Ca T 17.6 M/U 7-5/8" to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 17.10 Continue lowering string and land out on no-go. Set down 5 — l Ok lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & remove unnecessary 7-5/8" joints. 17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 17.13 Ensure circulation is possible through 7-5/8" string. 17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7-5/8" annulus. 17.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7-5/8" x 9- 5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7-5/8", verify collapse pressure of 7-5/8" tie back. 17.16 Slack off and land hanger. 17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 17.19 R/D casing running tools. Test 7-5/8" x 9-5/8" production annulus to 1000 psi / 30 min. �� 17.20 17.3 Set test plug and change top rams from 7-5/8" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 38 18.0 Run ESP Assembly Milne Point Unit E-37 SB Producer Drilling Procedure 18.1 RU spooler with ESP power cable and heat trace. RU two 3/8" capillary string spoolers. The capillary strings should be filled with hydraulic fluid. 18.2 Verify the ESP components as per Centrilift. Verify that the length of the motor lead flat cable will place the splice between the discharge head and the 10' handling pup collar. A Centrilift rep shall be on the rig floor at all times during the running of the ESP. 18.3 Makeup new ESP assembly with new motor lead extension, seal section and motor. 18.4 Run the 2-7/8" ESP Completion as noted below. The completion includes two 3/8" capillary tube from surface to the centralizer on the motor. The capillary tube will be secured to the tubing with Cannon clamps. Function test the capillary tube every 2,000' by pumping —2 gallons of hydraulic oil through the check valves. Record the pressure at each testing point 18.5 M/U ESP assy and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. • Centrilift ESP Assembly with bottom of assembly @ predetermined depth • 10' 2-7/8" 6.5#, L-80 Pup Joint • 1 joint 2-7/8" 6.5#, L-80 EUE 8rd tubing • 2-7/8" "XN" nipple (2.313" packing bore / 2.205" No -Go ID) • 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing • 10' 2-7/8" 6.5#, L-80 Pup Joint • GLM 2-7/8" x 1" GLM w/ dummy installed • 10' 2-7/8" 6.5#, L-80 Pup Joint • 2-7/8" 6.54, L-80 EUE 8rd tubing • 10' 2-7/8" 6.5#, L-80 Pup Joint • GLM 2-7/8" x l" w/ SO @ —140' MD • 10' 2-7/8" 6.5#, L-80 Pup Joint • 3 joints 2-7/8" 6.5#, L-80 EUE 8rd tubing • Tubing Hanger o Check the conductivity of electric cable every 2,000' and every new splice while running in hole. o Function test the capillary tube every 2,000' when checking the conductivity of the electric cable. Page 39 H Hilcorp E, Cmnpmy Milne Point Unit E-37 SB Producer Drilling Procedure o Use Cannon clamps on every joint to secure the capillary tube. o The makeup torque values for 2-7/8" L-80 6.5# EUE 8rd tubing are: Minimum: 1,730 ft -lb, Optimum: 2,300 ft -lb, and maximum: 2,800 ft -lb. o The 2-7/8" L-80 6.5# EUE 8rd tubing performance properties are: Body Yield: 145,000#, Burst: 10,570 psi, Collapse: 11,160 psi. 18.6 Fill tubing while splicing cable, mid -cable splices and tubing hanger splices. After tubing is full, break circulation by pumping 10 bbls down the tubing to clear any debris. 18.7 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.8 MU tubing hanger and landing joint. Splice ESP power cable and terminate control lines. Test cable. Install a brass -shipping cap on the ESP penetrator. 18.9 Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. 18.10 RILDS and test hanger. LD landing joint. 18.11 Install BPV and N/D BOP. 18.12 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.13 Circulate diesel freeze protection down 2-7/8" x 7-5/8" annulus (Volume should equal capacity of tubing to 2500' + tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. Note — this may be done post -rig. 18.14 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 18.15 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.0 RDMO 19.1 RDMO Innovation Rig Page 40 H Hilcorp M ZT- 20.0 Innovation Rig Diverter Schematic 3.118' Kill 13.518 Technology 13 Page 41 Milne Point Unit E-37 SB Producer Drilling Procedure ontrol Technology 3-518' 5M Control edmology Double Ram •118' Choke Line _16' Divener Line ff HilcoN M� 21.0 Innovation Rig BOP Schematic Milne Point Unit E-37 SB Producer Drilling Procedure —13-5/8' 5M Control Technology Annular BOP ®-13-518" 5M Control o Technology Double Ram 3-1/8" Kill Line(�+'y�§i 11FF��CC��J��''➢➢!! y �� 3-118" Choke Line oc ® o0 O O 5M Control ®--13-5/8" Technology Single Ram 13-5/8" x 5M 11"x5M 9-518" DBL D Seal 2-1/16"x 5M Casing Hanger 13-518" x 5M S-22 13-518" NOM 9.5/8' BTC Btm x 2-1/16" x 5M 10.5" -4 SA Pin Top W/ Primary Seal 20" Casing 9-518" Casing Page 42 22.0 Wellhead Schematic A. "N Milne Point unit E-37 SB Producer F(FI wvemsssr.• Hite o M -21P Drilling Procedure 22.0 Wellhead Schematic l FK.Gft,a ae IcanG Ell, `[ z ISL om r ec eo m rrl +s vrz,190-[Ta IINfeL 9f(��n. ei:i. IN(N ML aon. _ IIGV I WL+ V - ] -4 •.�A- 41V =1o:ouree�. I� l ', LI? `�':.4i11{ NY'ifP, VdbF(. a. (Ll -ICC 1 f- IG.3eO &Cx,. 15u SF. iu.0 t5'N n n'V F coo sues A; nA vox 1 nr xf p N� 5 p[G 1 Nr1V M-p"M i(Al RaU '[[ FIEW' I]i69! — I AI(IIM1L RIN4 — 6 BIV RILo. fi O11 S('�I IS[� tOP. 1 iW iG &E2 eGNL 3 N0 "(tiG — - - 3: e'pC 1e1116 A. "N l FK.Gft,a ae IcanG Ell, `[ z ISL om r ec eo m rrl +s vrz,190-[Ta IINfeL 9f(��n. ei:i. IN(N ML aon. _ IIGV I WL+ V - ] -4 •.�A- 41V =1o:ouree�. I� l ', LI? `�':.4i11{ NY'ifP, VdbF(. a. (Ll -ICC 1 f- IG.3eO &Cx,. 15u SF. iu.0 t5'N n n'V F coo sues A; nA vox 1 nr xf p N� 5 p[G 1 Nr1V M-p"M i(Al RaU '[[ FIEW' I]i69! — I AI(IIM1L RIN4 — 6 BIV RILo. fi O11 S('�I IS[� tOP. 1 iW iG &E2 eGNL 3 N0 "(tiG — - - 3: e'pC 1e1116 F(FI wvemsssr.• ---GRIVA[E AND COf1FID_HTIA'- OESi R1v1111, IIA F:. ea=vew uaa.�n t -4 7.. WARQUE7 iO-lS-li io ir. iF w msu. waNx ra IdR klr .2.}11ryWYr0..N - J if Mc,4 LS ICI -25 -ii NA w+lv'�11. aW.a rr.I nn1: ur[a Ip p[mrW�at w._ n..i ey6frryprr4 VFFO.4. 'Jf.rr (u -iWyi. mrt+a a.,, a ION.oHm r«I»or.:; as1..rG w•r IG -2S- I i A uo enwcre 'Ta "°" '•'^ J.. C4F C 25 1 pA1:0-727001 Iri Page 43 23.0 Days Vs Depth -1000 1000 3000 1 5000 a v 0 � 3 N v 9000 11000 iX1�ZQU 15000 Page 44 MPU E-37 SB OA Producer Days vs Depth 0 5 10 15 20 25 30 Days Milne Point unit E-37 SB Producer Hilco =71 Drilling Procedure 23.0 Days Vs Depth -1000 1000 3000 1 5000 a v 0 � 3 N v 9000 11000 iX1�ZQU 15000 Page 44 MPU E-37 SB OA Producer Days vs Depth 0 5 10 15 20 25 30 Days 24.0 Formation Tops & Information MPU E-37 Formations (wp07) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (ppg) Milne Point Unit 2426 1867 1915 E-37 56 Producer 8.46 Hilco2 Ee uy Drilling Procedure 24.0 Formation Tops & Information MPU E-37 Formations (wp07) MD (ft) TVDss (ft) ND (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2426 1867 1915 842.6 8.46 SV1 3440 2456 2504 1101.76 8.46 LA3 5585 3700 3748 1649.12 8.46 Schrader Bluff NA 6695 4193 4241 1866.04 8.46 Schrader Bluff OA 7678 4329 1 4377 1925.88 8.46 Page 45 GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL Milne Point Unit FM LITH DESCRIPTION E-37 SB Producer Hilem En m �vtlr Drilling Procedure GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION NI Gaol. apis Gubl Unconsolidated coarse to medium sand and small gravel with «.tam. 600 minor siltstone. 1,000 Heavy gravel conglomerate to 1400'. Wood fragments - ; throughout permafrost zone. Abundant pyrite at 1500 ft. a Base -0100 RUNNING GRAVELS 1700' permafrost 2,000' Be prepared for HYDRATE gas cut HYDRATESI I C mud 2W0to 2500' as (E-7and E�1 Saga nUkrok L ' -11&-13„- (E.,4.-30, ♦, HYDRATES. .339.-1). E-3 33 a 21,. E32. GAS CUT MUD A predominantly clay to +f- 3000' with inlerbeds of sand, clays and slllslones with occasional shows of coal. Y 3,000 Continued uterbeds of sand, clays and siftslones with occasional shows of coal- Clay, Mitstone and sand Interbeds between 3000 and 6000'. Lgnile341)0350011. SVimervaismoreraHy("muddier")than C chose in the Prudhoe Bay area. sto• UGUK,S SWABBINGlSTICKY L`1- t A Ugnu: thick package -200 1r,300 ft in sometimes, mostly water4liled fl E-pstl• although g q somezones are lined wall hydrocsrbon. The Ugnu section (Interbedded OlMal sandstone, with A n and shite) represents the Initial progradation of the Ugnu deltaic system over the underlying CLAYIGUMBO: E -20a. -28. 0 3shallow Y maims Schrader Bluff section. fluvial nature can make ft difficult to determine top base individual Bodoni bounding the Ugnu is -32 & -12. D Y C4 C and of units. surface of entire package picked A at the regional unconfomily M70S (see the M -sands below). GAS CUT MUD E-24 AT 3996 g M•Sands: Fluvial. delfalc channel sandstones prograded overthe underlying shallow TVD; E-138 @ 3618 tire. 4,000 a marine sandstones of the Schrader Blue. The M-SerWs we subdivided into three TIG14TIPACKING OFF. E -25A-, -ra•.- lirthostravgraphre units fMa. Mb. Me tram top to bottom) that can be diHlcua to correlate due A • to then Iluvid-deluke nature. The M70S marks the lower most boundary. M -sand Intervals Surface casing seat ! n are typically coarsening upward packages of varying thicknesses. rargngfrom 50.80't1hick, - la Schrader BIuH 0 C s All zones we highly unconsolidated sandstones with porosities range In the 30.38% and completion. aYzO. reaching upwards of 2000-59md. Each sand interval sets as a pereabliama reamW M L ons hydraulically separate reservoir based on current understanding. TIGHPLEDGES (COAL) CM N•Sands: The N -sands are composed d slacked. marine,sbareface sandstones thin RUNNING SURFACE A •D coarsen upwards from thin, silly mudstones into thin, low net -gross very lira to medium- CASING. E-14. -33 & -25. C C grained sandstones- The NB, NC & 1,10 -sands are the best quality reservoir rock of dean. 0 Y m high neCgross fine to medium grained sandstone. "and porosity ranges from 12-36%and d Z e priny target. with penmeaNidlei, m range from 100-3000 d. The 11C & NO -sands we Nur C j E secondary targets In the NB -sand. The more unconsolidated sands (typlcaly the HE. NC & J m ND) tend to washout, and the Inner grained silly mudslones can cause slow ROP. Each N -sand acts as a tryeraulicaly isolated separate reservoir. 12Tm. asks i O•SantlS: The 0 -sands consist of stacked taxer mantic sands that A R thin bed to upwards from lily mutlalones (Intervening alleles) to thin betltled. very tinea to IUw grained t sandslones. These OA and OB sandstorws are 25.30'th ek. and the OA -sand is the primary B U td target Ior horizamal wells at E -pad. Olandri porosities range from 12-36%and pereebillbes U) In the 09 -sand reach upwards of 800 m0. whereas permeadlilies In the OMsand reach only 350 met. There are underlying OB sands (Ofitr-0Bf) that correlate over the region. y0 May cOntain light nodules and lenses that cause directional deflection (especially when horizontal) and slow ROP- Each 0 -sand Interval acts as a hydraulically Isolated reservoir. The numerous subseismic 530 d laults and the lateral discontmufty of the NB -sands make A 4600' 0 esaenilal for clear pick Idemdlcation down through the Ugnu and N-sarWs. as well as careful •7- 100' geosteenng in horizontal wefts. Page 46 25.0 Anticipated Drilling Hazards Milne Point Unit E-37 SB Producer Drilling Procedure 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have been seen on E Pad. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non - pressurized scale will reflect the actual mud cut weight. Add 1.0 —2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. Page 47 H Hilcorp Evag/ Compuy Milne Point Unit E-37 SB Producer Drilling Procedure 1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 112S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on this pad. Page 48 H Hileorp �W �'T 26.0 Innovation Rig Layout Milne Point Unit E-37 SB Producer Drilling Procedure / Page 49 n Hilcorp 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-37 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 50 28.0 Innovation Rig Choke Manifold Schematic Page 51 Milne Point unit E-37 SB Producer Hilco �P EM Drilling Procedure 28.0 Innovation Rig Choke Manifold Schematic Page 51 n Hilcorp E�C�, Milne Point Unit E-37 SB Producer Drilling Procedure 29.0 Casing Design Hoilw� Calculation & Casing Design Factors DATE: 11/27/2018 WELL: MPU E-37 DESIGN BY: Joe Engel Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode MASP: 1488 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1488 psi (see attached MASP determination & Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing e%acuated for the internal stress Page 52 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9518" 6-518" Top (MD) 0 7,653 Top (TVD) 0 4,375 Bottom (MD) 7,653 13,943 Bottom (TVD) 4,375 4,333 Length 7,653 6,290 Weight 40 20 Grade L-80 L-80 Connection TXP H563 Weight w/o Bouyancy Factor (lbs) 306,120' 125,800 Tension at Top of Section (Ibs) 306,120 125,800 Min strength Tension (1000 Its) 916 459 Worst Case Safety Factor (Tension) 2.99 3.65 Collapse Pressure at bottom (Psi) 2,161 2,141 Collapse Resistance w/o tension (Psi) 3,090 3,470 Worst Case Safety Factor (Collapse) 1.43 1.62 MASP (psi) 1,488 1,488 Minimum Yield (psi) 5,750 6,090 Worst case safety factor (Burst) 3.86 4.09 Page 52 n Hilcorp EnoHY CamPmY 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 11 11 8-1/2" Hole Section MPU E-37 Milne Point Unit MD TVD Planned Top: 7653 4375 Planned TD: 13943 4333 Milne Point Unit E-37 SB Producer Drilling Procedure Anticipated Formations and Pressures: Formation TVD TVDss EstPressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 1 4,375 1 4,375 1 1925 1 Oil I8.46 0.440 Offset Well Mud Densities Well MW range Too (TVDI Bottom (TVD) 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 35/8" shoe considering a full column of gas from shoe to surface: 4,375 (ft) x 0.78(psi/ft)= 3412.5 3413(psi)-[0.1(psi/ft)•4375(ft)]= 2976 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4375 (ft) x 0.44(psi/ft)= 1925 psi 1925(psi)-0.1(psi/ft)`4375(ft) 1488psi ✓ Summary: 1. MASP while drilling 8-1/2' production hole is govemed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 53 Oj 31.0 Spider Plot (NAD 27) (Governmental Sections) 1 MILNE POINT UNIT '00'.1§, ppap-" Milne Point Unit .. ---'^�'�, E-37 SB Producer Hilco2 Eve(® Cvmpny Drilling Procedure -37 BHL I _ ♦ 31.0 Spider Plot (NAD 27) (Governmental Sections) 1 MILNE POINT UNIT '00'.1§, ppap-" Sec 18 .. ---'^�'�, i630; ._. •Sec t. -37 BHL I _ ♦ - epz ` r. I/ 1 1 y / -------------- - BiJ[ r / / I _ _ L ___ _ _ ___ _ _ � p n .''' ��pOpOppppp'OppE 1 �- -~/ADL04743 niPF-'p .TPp `�' `U013N010E_ • E.I1 ppap-" I � p Szc. 24 - , I 1 i I 1 1 I/ 1 1 y / 19 \ • BiJ[ r / / I i \\ 1 t ,Sec. 19 t 1,633) ! I I r -- i U013N011E 1 r. --r•,cte��ua��I Ni t-±! SHL( ------------ ess`xx ceryl„_ Ilk Sec. 30 Sec. 2e Sec. 25 c .cvaS �•`�}='✓ ADL025518 1, ,� AD .028231 �az3rai A i \ I �Z HAM \ Legend Mgu S -s K-RECEI, - 1 • MPE-37_SHL Otrler Surface Holes(SHL) X MPE-37_iPH ' ONer Bolton Holes (BHL) a-z9=ei - / Sec 31 Page 54 Hilcorp m Cmnpuy 32.0 Surface Plat (As Built) (NAD 27) Milne Point Unit E-37 SB Producer Drilling Procedure Page 55 DR~c 24 ss ■3 I a* ■ 2 T 2r■ ;. N � to • � u I crAD p � 2n ■ m ■ 4 ■ 1 ` 4 tl' I 2c1 ■ ■ S THS PROJECT - 13 ■ 26 •b 9 ■ • 61 -N- 26■ •2t 1ACINITY MAP � I 1+ ■ 0 r I x_ts. 6 ■ ■ m MFUE-rAD m ■ ■ 2s 24 ■ A ■ 2 'A FEL •• • E-39 E 37 *' 9 3M . E-41 E-35 ' 2Dpthy .••al• 10200 NOTES', L M A STATE P E UXADMAIES ARE ZDAE 4. LEGEND MM27. + AS-R,ALT CDWWr0Q SURVEYOR'S CERTIFICATE 2. SARIS O LOCATION 6 MONMI, OP -D ARD E-1. I ISMOY fEATFY NAT 1 AM a EMSMC C Muc;DA PROPERLY WVSIEAED AND MDD = ]. RAS 3 aE IMNAMN -1 FaMT DANR MS_ Ta PRACTA;F VMD 9LR\EYNG IN 4 ®EDC'W"S ARE MlD27. NE STATE CIFALASKA AND NAT E PAD MEAAF scut FA" IS. a"0*4 GRAPHIC SCALE NM ASS L REPRES7IT5 A 9 RVEY C 9AYD DAT. MAY 31,2MR Y ALY 1, min . D m 200 bC MALE BY ME C6 JMER MY DIRECT 7. /J.FEREACE FFID SIXM: MA -02 PDS. 2a•22 S;:'PERN9aM AND NAT ALL le DA AR: x.ld-02 PCS 63-73 ( W FEET 1 COR`�EE TMASAOFF MAYOTW�31,, 2018 LOCATED 1MTMIN PROTRACTED SEC. 25, T. 13 N., R. IC E, GMIAT MERIDIAN, ALASKA WELL PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORD7NATE5 COORDINATES POSITION(OMS) POSITION(DAD) BOX ELEV. OFFSETS Y=6,016,133.24' N+1,829.99' 7D'2T75.9a5" 7D.4544292' 21 7• 3.594' FSL E-35 X+ 569,426.37' ' E= 1.450.02' 1a926'170.a38" 149.4334550' l,'520' FEL Y+6,016.156.74' N=1,864-72' 702715.178" 70.4544459' 21.7• 3,617 F5L E-36 %= 569 407.5 ' :1450.03' 149'26'00.964' 149.4338087• 1,738' FEL Y+6,016,180.37 N- 1,890.58' 7G'2T16-412" 7D.4545589' 21'7 3fi41'FSL E-37 X= 569. 88.31' E. 1,449,194' 14925'01.542" 149.43J7677. 1,757 FEL Y=5.016.081.06' N+1.890.22' 702715.446" ]D.45<29C6' 21,8' 3543'FSL E-38 X+ 569.265.12' Em 1.291.58' 149'26'05.189" t4Aa3<774T 1 881' FEL Y=8.016,057.25' N+1,859.75' 702 iS.210" 70.4542250' 21'7 ' 3.$1 9' PSL E-39 X- 569.284.13' E= 1 291.52' 14926'04.656" 749.4346211' 1.663' F.I. Y=6,076,034.09' N-9,829.93 70'27 14.981 70.4541614 3,496'FSL E-41 X- 569 302.9 ' = 1.291,66' 149'26'04-09 49 - A RilcorpANSIMILNE re I POINT, ALASKA�„A MP E -PAD, FELLS S5, 36. V. 38, 39 h 41 CONDUCTOR AS -BUILT t o a AEu3t2 ua m�o.rw.AVIMAIa M1me. not-: � � `A°' ' r . xac' Page 55 149.43446971,84i' FEL H Hilcorp 33.0 Milne Point Unit E-37 SB Producer Drilling Procedure Schrader Bluff OA Sand Offset MW vs TVD Chart Page 56 500 1000 1500 2000 4= 0 2500 3000 3500 4000 4500 Schrader Bluff OA Sand Offset MW vs ND mw, ppB 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.1 10.3 10.5 -MPU L-46 (2015) -MPU L-47 (2015) -MPU L-48 (2015) -MPU L-49 (2015) -MPU L-50 (2015) -MPU F-106 (2017) -MPU F-107 (2017) -MPU F-108 (2017) -MPU F-109 (2017) -MPU F-110 (2017) ff Hilcorp M f.®%^9 Milne Point Unit E-37 SB Producer Drilling Procedure 34.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD I*5.15W Pipe Body Wall Thickness mi 0.362 Pipe Body Grade S-135 Drill Pipe Length 2 Connection GPOS50 Tad Joint OD 6.625 Tod Joint ID in: 3256 Pin Tong 9 Box Tong 12 80 %Inspection Class Nominal Nominal Weight Designation 19.50 DO Pipe Approximate Length 1")131-5 SmoctilEdge Height (^) 31'32 Roused Tool Joint SMYS msi 120.000 Upset Type IEU Max Upset OD (DTE) ns� 5.125 Friction Factor 1.0 0M4 1,658.000 NM, TOM 5w:e may mclWe 11 Pdlp. Drill Pipe Performance Drag -Pipe Length Range2 100 100 Connection Performance Tension Nominal 2329 0.36 0.0065 0.72 ............. 0.0172 IT Ony 10 550.800 Drift Size n^� 3.125+ cmmrca-MMS,32.100 467.400 NM, pp VIM exml MuIm 42 US pvlen 5. ,a', N, pe a::emur.aluC. al MH eY. aM -, r am In robe o _', l a¢. MM -, pl nee.,. -e open rack, GPOS50 ( 6.625 M) OD X 3.250 (n) ID ) 120,000 �) mmee Ins.ii a S,IMa T..-.. Tool Jo int Dimensions Balanced OD M 6.435 paemea T. J.00W FPI 5.930 amm4m.mss an u TMTJ. p 5.93 ce�mmi. nn Ntta Tu m.S.mce �.^netluoxm^nv le^5.e5.rn rr4)•3r sca ;n4e5:.5nom5 pe ecgcd Nominal Tod Joint Torsional Strength Tool Joint Tensile Strenpm rnev mn 171.800 71 IOD 1250.000 Elevator Shoulder Information SmoothEdge Height 3+32 Raised m -MM 74.100 58,100 Box OD )Ink 6.812 Elevator Cavadly 0M4 1,658.000 1.24 80% Pipe Torsional Strength i Elevator OD 332 Raised 6.812(-) 'orn to Min TJ OD for API Premium Class Assumed Elevator Bore Diameter I^ 5219 Nme. .4u ee.amr oo bo..55e5 ele.ma 5a,axr. .pe .maae.wm - Pipe Body Slip Crushing Capacity Pipe Bady LonNurati n ( 5 )b) OD 0.362 rb) wall S-135) Nominal 80 %Inspection pass I API Premium Gass ,TV �I f9 Slip Crushing Capacitv b:) 498.300 396.500 396,5f)D i \VI IY/ Assumed Sli Le fh 15ap U.an^p sbo..erm r�pucn.aln an re:y�.r me5m m.r....+iroovz a.ln In116.5 Fill^TL alp M[SHAGd..Y9b Xe YbtVl�wi.aeeae bSpbnP L'Ne.�p.90 brt5emc atY �.pbNJ+eV SLeXTSTIm I.e 9b 0cpn sbmVbr,mtlltlnXalll[.m.l1YN�O1¢¢.V Transverse Load Factor (KI 142 urs eee peeoompwarx�n .>roenabm5 cae:ewu me sme�me¢mmsmam rnroor_ Pipe Body Performance Pipe Body CcM5gurston ( 5(-) OD 0.362 (b) Wall S-135) Page 57 Nae: NomlNl eu�J. vbiea m e3. re ee•n• a. me Nominal 80 % Inspection Class API Prerni m Class Pipe Tensile Strength 71 IOD 660,81]0 560,800 Pipe Torsional SU m -MM 74.100 58,100 58.100 TXRpeBody Torsional Ratio 0.97 124 1.24 80% Pipe Torsional Strength ?-n5) 59.300 46.500 46,500 Burst wi 17,105 15.638 15638 Collapse 15,672 10.029 10.029 Pipe OD Mi 5.000 4.855 4.855 Wall Thickness 0.362 0.290 0.290 Nominal Pipe ID as) 4276 142fb 14210 Cross Sectional Area at Pipe Body wzt 5275 4.154 4.154 Cross Sectional Area of OD (W2519.635 18.514 18.514 Sectional Area d ID (N-22 14.366 14.360 14.360 mCross SecSon Maduka rb"3 5.708 4876 14.476 PolarSection Modulus (.'3111.415 8.953 18.953 Nae: NomlNl eu�J. vbiea m e3. re ee•n• a. me 500204050016200 1W Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-518" OD x 3-1/4" ID Tool Joint DRILL PIPE SPECIFICATIONS Milne Point Unit S-135 Connection NC 50 E-37 SB Producer 5' XH & 4-12' IF Hitcorp UCL7 Drilling Procedure 500204050016200 1W Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-518" OD x 3-1/4" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5' XH & 4-12' IF Upset Type IEU Nominal Weight per Foot 19.50 lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6.5/8' Inside Diameter 3-1/4' API Drift 3-1/8' Rabbit OD, Suggested 3-1/16' Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26.800 ft -lbs Torsional Yield Strength_ 51,700 ft -lbs Tensile Strength 1.269.000 lbs TUBE DATA New Premium Outside Diameter 5.000' 4.855' Inside Diameter 4.276' 4.276' Wall Thickness 0.362' 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Loadfrensile Strength 712.000 lbs 560.800 lbs Slip rushing/ Slip Type (SDXL) 572.100 lbs 453.500 lbs Burst Pressure 17,100 psi 16.100 psi Collapse Pressure 15.700 psi 10.000 psi Torsional Yield Stren th 74.100 ft -lbs 58.100 ft -lbs Capacity W/ Tool Joint 0.726 US qaVft 0.726 US al/ft Dis lacement W/ Tool Joint 0.353 US gaVft 0.322 US oallft Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 58 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-37 M P E-37 Plan: MPE-37 wp07 Standard Proposal Report 09 November, 2018 HALLIBURTON Sperry Drilling Services F a m 0o z W,o 0 NCIH ry0� ONOmOF w>zn�z��mz� z`a �azm N�ioo<�n�m� @�nv�vo 2 2� Q-@ N p _ 000@ O NnN�Umi�d�m �OV�uI C] oo�omcMomo rcmom� 0 0 0 0 0 M O m O m 000"0000000 000000 3wwwwwwwww wmw mv'3 Q m m N m W m W m W m W 41 W N W F 2 U U U H r o r o 0 3 3 3 3 3 y v n m M M n w w w w w 0 Z �•oomP�mnPmMmNomMm�m � "oo v,MnooMPmPMmOmmnm U inoomm��mroi6 �i �d vi v: oimn � Nm w mmmNY]NfUmnnm m u00000mo@OmoP@omoMo �y00 OP `O CI�OIAOGOm�O�GPO r v000000000000000000 0000m0000000000000 p O O m P P P O O O@ O m m O m O m O OO O m M m r N m m O r P m N m m M r O N�-mV�<DmNNNNmmP"m WOO f1A fUPP�U1r Cr0�NlO mO NO mmmNNMOJm OHO ooroPnmoMm�mmnMrMnm,m ZOO`mO�@e'm NO1N@@@Or0 + @@@mmmmmmmr �OOOmNmmmOmNOmOP000 N o y pmj r M O m m 0 0 0@ m W m O m Nmm.f-�n°"r�'emin MPJ (N'1mm�CM'� @P@PP@P@@@@ N N N CO'IM N N 0o m�vNmmrnmrnmmmmmm �n0000mroom�omMPmmP . M mom'-rNOmmm'-�M vnnmoor�onio ei mnN(pa�f^%N@mmmmmm N r r i 0 zo U � Q ENmAK c, _ ' A a Ryba w` eS�Qc m w`m w`E � 3 t ftN,Zml Wm mw a ti mn �enm z�Nty<P o�RmR� �Ov �o a y Io moo porn zpP gl S O LL G LL m W c oh 009Z < n�L CLW MA n OOOZI� 4� a % f oMk-------------- /p O� Oh 4�S •r1,. 2. _ <' oh Qc m 4 ' a a 9 i 0 zo U � Q ENmAK c, _ ' A a Ryba w` eS�Qc m w`m w`E � 3 t ftN,Zml Wm mw a ti mn �enm z�Nty<P o�RmR� �Ov �o a y Io moo porn zpP gl S O LL G LL m SM3 00$EL wouI p a<p< n• oh 009Z < n�L , n OOOZI� 4� 4, SM3 00$EL wouI p a<p< n• oh" 009Z < O <pll� 90 �s n OOOZI� 4� % f oMk-------------- /p O� Oh 4�S •r1,. 2. _ <' oh ,fg< /O L. W 00501 p f' /p4� ggd a S 00004 OLY - �fd, p4G 0096 V2. g2�� 0006 - O �S �rS g9p0, pz� OA, 0056 - Ohl. /O O - ,0008. �g Y 00SLI Kg6`rf 6 _---------- 000[ p d. ph`A a 0% s a Ru F w n /O 4� Q 2 p m `D O �S O �g Y 6 � S o 0 0 0 0 o S S in o m n n w n a e (uyusn 000 1) 9)dad ImiUaA anLl M o a n N M 0 ■ i| , ,A=w _, , _ § ( f ( /\ \) / ®� \ \\\ \ 7 \ In In - — § r ) In ;{ , ! § $ \ IT IT 0 ■ i| , ,A=w _, , _ § ( f ( 0 ■ i| , ,A=w _, , HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-37 TVD Reference: MPE-37 wp03 @ 48.20usft MD Reference: MPE-37 wp03 @ 48.20usft North Reference: True I Survey Calculation Method: Minimum Curvature ' roject Milne Point, ACT, MILNE POINT ap System: US State Plane 1927 (Exact solution) • System Datum: Mean Sea Level co Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt E Pad, TR -13-10 Site Position: Northing: 6,013,798.68usfl Latitude: 70° 26'52.982 N From: Map Easting; 569,440.72usft Longitude: 149° 26'0.655 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.53 ' well Plan: MPU E-37 Well Position +NI -S 0.00 usft Northing: 6,016,180.37 usfl Latitude: 70° 27' 16.412 N +E/ -W 0.00 usft Easting: 569,388.31 usfl Longitude: 149° 26' 1.542 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: - 21.70usft Wellbore MPE-37 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2018 11/20/2018 16.97 80.98 57,447.94327777 Design MPE-37 wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction (usft) (usft) (usft) (I 26.50 0.00 0.00 320.43 11/92018 11:53.52AM Page 2 COMPASS 5000.15 Build 91 Plan Sections Halliburton H A L L I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-37 Company: Hilcorp Alaska, LLC TVD Reference: MPE-37 wp03@48.20usft Project: Milne Point MD Reference: MPE-37 wp03 @ 48.20usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-37 Survey Calculation Method: Minimum Curvature Wellbore: MPE-37 Design: MPE-37 wp07 Dogleg Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 26.50 0.00 0.00 26.50 -2170 0.00 0.00 0.00 0.00 0.00 0.00 280.00 0.00 0.00 280.00 23180 0.00 0.00 0.00 0.00 0.00 0.00 550.00 8.10 40.00 549.10 500.90 14.60 12.25 3.00 3.00 0.00 40.00 700.00 13.63 27.18 696.38 648.18 38.43 27.13 4.00 3.69 -8.54 -30.00 1,200.00 35.99 20.69 1,147.42 1.09922 230.76 106.98 4.50 4.47 -1.30 -10.00 1,665.59 54.51 17.88 1,473.78 1,425.58 541.90 214.47 4.00 3.98 -0.60 -7.19 4,984.67 54.51 17.88 3,400.49 3,352.29 3,114.00 1,044.12 0.00 0.00 0.00 0.00 7,203.10 85.00 285.86 4,335.98 4,287.78 4,581.30 51.66 4.00 1.37 -4.15 -95.24 7,653.10 85.00 285.86 4,375.20 4,327.00 4,703.81 -379.56 0.00 0.00 0.00 0.00 7,806.73 91.15 285.81 4,380.36 4,332.16 4,745.69 -527.20 4.00 4.00 -0.03 -0.45 9,290.21 91.15 285.81 4,350.72 4,302.52 5,149.82 -1,954.27 0.00 0.00 0.00 0.00 9,430.00 90.92 290.00 4,348.20 4,300.00 5,192.78 -2,087.24 3.00 -0.16 3.00 93.04 9,637.86 90.92 296.24 4,344.86 4,296.66 5,274.34 -2,278.28 3.00 0.00 3.00 89.94 10,611.63 90.92 296.24 4,329.20 4,281.00 5,704.77 -3,151.62 0.00 0.00 0.00 0.00 10,990.54 89.13 307.46 4,329.04 4,280.84 5,904.38 -3,472.95 3.00 -0.47 2.96 99.05 11,592.19 89.13 307.46 4,338.20 4,290.00 6,270.28 -3,950.46 0.00 0.00 0.00 0.00 11,990.18 90.21 295.57 4,340.50 4,292.30 6,477.95 -4,289.13 3.00 0.27 -2.99 -84.83 13,943.34 90.21 295.57 4,333.20 4,285.00 7,320.99 -6,050.97 0.00 0.00 0.00 0.00 11NQ018 11:53:52AM Page 3 COMPASS 5000.15 Build 91 Planned Survey Measured Halliburton H A LL I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-37 Company: Hilcorp Alaska, LLC TVD Reference: MPE-37 wp03 @ 48.20ul Project: Milne Point MD Reference: MPE-37 wp03 @ 48.20us0 Site: M Pt E Pad North Reference: True Well: Plan: MPU E-37 Survey Calculation Method: Minimum Curvature Wellbore: MPE-37 (1) (1) Design: MPE-37 wp07 usft (usft) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easing OLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) -21.70 26.50 0.00 0.00 26.50 -21.70 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 100.00 0.00 0.00 100.00 51.80 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 200.00 0.00 0.00 200.00 151.80 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 280.00 0.00 0.00 280.00 231.80 0.00 0.00 6,016,180.37 569,388.31 0.00 0.00 Start Dir 3°/100' : 280' MD, 280'TVD 300.00 0.60 40.00 300.00 251.80 0.08 0.07 6,016,180.45 569,388.38 3.00 0.02 400.00 3.60 40.00 399.92 351.72 2.89 2.42 6,016,183.28 569,390.71 3.00 0.68 500.00 6.60 40.00 499.51 451.31 9.70 8.14 6,016,190.14 569,396.35 3.00 2.29 550.00 8.10 40.00 549.10 500.90 14.60 12.25 6,016,195.08 569,400.42 3.00 3.45 Start Dir 4°/100' : 550' MD, 549.1'TVD 600.00 9.88 34.16 598.49 550.29 20.85 16.92 6,016,201.37 569,405.04 4.00 5.29 700.00 13.63 27.18 696.38 648.18 38.43 27.13 6,016,219.05 569,415.08 4.00 12.34 Start Dir 4.60/100': 700' MD, 696.38'TVD 800.00 18.08 24.67 792.55 744.35 63.02 38.99 6,016,243.75 569,426.71 4.50 23.74 900.00 22.54 23.12 886.31 838.11 94.77 53.00 6,016,275.62 569,440.42 4.50 39.28 1,000.00 27.02 22.07 977.08 928.88 133.47 69.07 6,016,314.47 569,456.13 4.50 58.88 1,100.00 31.51 21.29 1,064.29 1,016.09 178.90 87.10 6,016,360.05 569,473.73 4.50 82.40 1,200.00 35.99 20.69 1,147.42 1,099.22 230.76 106.98 6,016,412.09 569,493.13 4.50 109.71 Start Dir 4-/100': 1200' MD, 1147.427VD 1,300.00 39.97 19.91 1,226.22 1,178.02 288.47 128.31 6,016,469.99 569,513.92 4.00 140.60 1,400.00 43.94 19.25 1,300.58 1,252.38 351.45 150.70 6,016,533.17 569,535.72 4.00 174.88 1,500.00 47.92 18.68 1,370.12 1,321.92 419.39 174.04 6,016,601.32 569,558.42 4.00 212.38 1,600.00 51.90 18.18 1,434.50 1,386.30 491.95 198.21 6,016,674.10 569,581.91 4.00 252.92 1,665.59 54.51 17.88 1,473.78 1,425.58 541.90 214.47 6,016,724.19 569,597.70 4.00 281.06 End Dir : 1665.59' MD, 1473.78' TVD 1,700.00 54.51 17.88 1,493.75 1,445.55 568.56 223.07 6,016,750.93 569,606.05 0.00 296.14 1,800.00 54.51 17.88 1,551.80 1,503.60 646.06 248.06 6,016,828.65 569,630.32 0.00 339.94 1,900.00 54.51 17.88 1,609.85 1,561.65 723.55 273.06 6,016,906.37 569,654.59 0.00 383.75 2,000.00 54.51 17.88 1,667.90 1,619.70 801.05 298.06 6,016,984.08 569,678.87 0.00 427.56 2,100.00 54.51 17.88 1,725.95 1,677.75 878.54 323.05 6,017,061.80 569,703.14 0.00 471.37 2,200.00 54.51 17.88 1,784.00 1,735.80 956.04 348.05 6,017,139.52 569,727.41 0.00 515.17 2,300.00 54.51 17.88 1,842.05 1,793.85 1,033.53 373.05 6,017,217.23 569,751.68 0.00 558.98 2,400.00 54.51 17.88 1,900.10 1,851.90 1,111.03 398.04 6,017,294.95 569,775.95 0.00 602.79 2,426.01 54.51 17.88 1,915.20 1,867.00 1,131.18 404.54 6,017,315.17 569,782.26 0.00 614.18 BPRF 2,500.00 54.51 17.88 1,958.15 1,909.95 1,188.52 423.04 6,017,372.67 569,800.22 0.00 646.60 2,600.00 54.51 17.88 2,016.20 1,968.00 1,266.02 448.04 6,017,450.38 569,824.49 0.00 690.41 2,700.00 54.51 17.88 2,074.25 2,026.05 1,343.51 473.03 6,017,528.10 569,848.77 0.00 734.21 2,800.00 54.51 17.88 2,132.30 2,084.10 1,421.01 498.03 6,017,605.82 569,873.04 0.00 778.02 2,900.00 54.51 17.88 2,190.35 2,142.15 1,498.50 523.03 6,017,683.53 569,897.31 0.00 821.83 3,000.00 54.51 17.88 2,248.40 2,200.20 1,575.99 548.02 6,017,761.25 569,921.58 0.00 865.64 3,100.00 54.51 17.88 2,306.45 2,258.25 1,653.49 573.02 6,017,838.97 569,945.85 0.00 909.44 3,200.00 54.51 17.88 2,364.50 2,316.30 1,730.98 598.02 6,017,916.68 569,970.12 0.00 953.25 3,300.00 54.51 17.88 2,422.55 2,374.35 1,808.48 623.01 6,017,994.40 569,994.39 0.00 997.06 3,400.00 54.51 17.88 2,480.60 2,432.40 1,885.97 648.01 6,018,072.12 570,018.67 0.00 1,040.87 11797Y018 11:53:52AM Page 4 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Planned Survey Measured Map Vertical 6,020,564.30 Depth Inclination Azimuth Depth TVDss (usft) (') (1) (usft) usft 3,440.66 54.51 17.88 2,504.20 2,456.00 SV1 570,028.54 0.00 1,058.68 1,963.47 3,500.00 54.51 17.88 2,538.65 2,490.45 3,600.00 54.51 17.88 2,596.69 2,548.49 3,700.00 54.51 17.88 2,654.74 2,606.54 3,800.00 54.51 17.88 2,712.79 2,664.59 3,900.00 54.51 17.88 2,770.84 2,722.64 4,000.00 54.51 17.88 2,828.89 2,780.69 4,100.00 54.51 17.88 2,886.94 2,838.74 4,200.00 54.51 17.88 2,944.99 2,896.79 4,300.00 54.51 17.88 3,003.04 2,954.84 4,400.00 54.51 17.88 3,061.09 3,012.89 4,500.00 54.51 17.88 3,119.14 3,070.94 4,600.00 54.51 17.88 3,177.19 3,128.99 4,700.00 54.51 17.88 3,235.24 3,187.04 4,800.00 54.51 17.88 3,293.29 3,245.09 4,900.00 54.51 17.88 3,351.34 3,303.14 4,984.67 54.51 17.88 3,400.49 3,352.29 Start Dir 4°/100' : 4984.67' MD, 3400.49TVD 5,000.00 54.46 17.13 3,409.39 3,361.19 5,100.00 54.23 12.21 3,467.71 3,419.51 5,200.00 54.19 7.28 3,526.22 3,478.02 5,300.00 54.36 2.36 3,584.63 3,536.43 5,400.00 54.72 357.47 3,642.67 3,594.47 5,500.00 55.28 352.63 3,700.05 3,651.85 5,585.20 55.91 348.57 3,748.20 3,700.00 LA3 1,900.13 3,446.64 1,088.85 6,019,636.67 5,600.00 56.03 347.87 3,756.48 3,708.28 5,700.00 56.96 343.20 3,811.70 3,763.50 5,800.00 58.06 338.64 3,865.44 3,817.24 5,900.00 59.32 334.20 3,917.43 3,869.23 6,000.00 60.72 329.87 3,967.42 3,919.22 6,100.00 62.26 325.67 4,015.16 3,966.96 6,200.00 63.92 321.59 4,060.44 4,012.24 6,300.00 65.70 317.63 4,103.01 4,054.81 6,400.00 67.57 313.78 4,142.68 4,094.48 6,500.00 69.53 310.04 4,179.26 4,131.06 6,600.00 71.57 306.39 4,212.56 4,164.36 6,695.66 73.59 302.98 4,241.20 4,193.00 SB NA 4.00 2,689.91 4,205.27 722.10 6,700.00 73.68 302.83 4,242.42 4,194.22 6,800.00 75.85 299.34 4,268.70 4,220.50 6,900.00 78.07 295.92 4,291.27 4,243.07 7,000.00 80.32 292.56 4,310.02 4,261.82 7,100.00 82.61 289.24 4,324.86 4,276.66 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-37 MPE-37 wp03 @ 48.20usft MPE-37 wp03 @ 48.20usft True Minimum Curvature 4,379.87 Map Map 6,020,564.30 +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 2,456.00 569,764.59 1,917.48 658.17 6,018,103.72 570,028.54 0.00 1,058.68 1,963.47 673.01 6,018,149.83 570,042.94 0.00 1,084.67 2,040.96 698.00 6,018,227.55 570,067.21 0.00 1,128.48 2,118.46 723.00 6,018,305.27 570,091.48 0.00 1,172.29 2,195.95 748.00 6,018,382.98 570,115.75 0.00 1,216.10 2,273.45 772.99 6,018,460.70 570,140.02 0.00 1,259.91 2,350.94 797.99 6,018,538.42 570,164.30 0.00 1,303.71 2,428.44 822.98 6,018,616.13 570,188.57 0.00 1,347.52 2,505.93 847.98 6,018,693.85 570,212.84 0.00 1,391.33 2,583.42 872.98 6,018,771.57 570,237.11 0.00 1,435.14 2,660.92 897.97 6,018,849.28 570,261.38 0.00 1,478.94 2,738.41 922.97 6,018,927.00 570,285.65 0.00 1,522.75 2,815.91 947.97 6,019,004.72 570,309.92 0.00 1,566.56 2,893.40 972.96 6,019,082.44 570,334.20 0.00 1,610.37 2,970.90 997.96 6,019,160.15 570,358.47 0.00 1,654.18 3,048.39 1,022.96 6,019,237.87 570,382.74 0.00 1,697.98 3,114.01 1,044.12 6,019,303.67 570,403.29 0.00 1,735.08 3,125.91 1,047.87 6,019,315.61 570,406.93 4.00 1,741.86 3,204.47 1,068.45 6,019,394.35 570,426.77 4.00 1,789.31 3,284.37 1,082.17 6,019,474.37 570,439.75 4.00 1,842.15 3,365.23 1,088.98 6,019,555.27 570,445.80 4.00 1,900.13 3,446.64 1,088.85 6,019,636.67 570,444.91 4.00 1,962.97 3,528.21 1,081.77 6,019,718.16 570,437.08 4.00 2,030.35 3,597.54 1,070.28 6,019,787.38 570,424.95 4.00 2,091.11 3,609.54 1,067.78 6,019,799.36 570,422.33 4.00 2,101.96 3,690.24 1,046.95 6,019,879.85 570,400.75 4.00 2,177.44 3,769.92 1,019.38 6,019,959.26 570,372.44 4.00 2,256.41 3,848.18 985.20 6,020,037.19 570,337.53 4.00 2,338.51 3,924.64 944.57 6,020,113.27 570,296.21 4.00 2,423.33 3,998.94 897.71 6,020,187.12 570,248.66 4.00 2,510.45 4,070.71 844.83 6,020,258.38 570,195.12 4.00 2,599.46 4,139.59 786.20 6,020,326.71 570,135.85 4.00 2,689.91 4,205.27 722.10 6,020,391.78 570,071.15 4.00 2,781.37 4,267.40 652.83 6,020,453.26 570,001.31 4.00 2,873.39 4,325.70 578.75 6,020,510.86 569,926.70 4.00 2,965.52 4,377.62 503.70 6,020,562.07 569,851.17 4.00 3,053.35 4,379.87 500.21 6,020,564.30 569,847.66 4.00 3,057.32 4,429.66 417.59 6,020,613.31 569,764.59 4.00 3,148.33 4,474.83 331.29 6,020,657.66 569,677.88 4.00 3,238.12 4,515.14 241.74 6,020,697.14 569,587.97 4.00 3,326.25 4,550.41 149.37 6,020,731.54 569,495.28 4.00 3,412.28 i1FJ2018 11:53.52AM Page 5 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Planned Survey Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-37 TVD Reference: MPE-37 wp03 @ 48.20usft MD Reference: MPE-37 wp03 @ 48.20usft North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S (usft) (°) (°) (usft) usft (usft) 7,203.10 85.00 285.86 4,335.98 4,287.78 4,581.30 End Dir : 72133.1' MD, 4335.98' TVD - Start ESP Tangent 7,300.00 85.00 285.86 4,344.43 4,296.23 4,607.68 7,400.00 85.00 285.86 4,353.14 4,304.94 4,634.91 7,500.00 85.00 285.86 4,361.86 4,313.66 4,662.13 7,600.00 85.00 285.86 4,370.57 4,322.37 4,689.36 7,653.10 85.00 285.86 4,375.20 4,327.00 4,703.81 Start Dir 4-1100': 7653.1' MD, 4375.2'TVD - 9 518" x 12 114" 7,678.65 86.02 285.85 4,377.20 4,329.00 4,710.77 SB OA 7,700.00 86.88 285.85 4,378.52 4,330.32 4,716.59 7,806.73 91.15 285.81 4,380.36 4,332.16 4,745.69 End Dir : 7806.66' MD, 4380.37' TVD 7,900.00 91.15 285.81 4,378.50 4,330.30 4,771.10 8,000.00 91.15 285.81 4,376.50 4,328.30 4,798.34 8,100.00 91.15 285.81 4,374.50 4,326.30 4,825.58 8,200.00 91.15 285.81 4,372.51 4,324.31 4,852.83 8,300.00 91.15 285.81 4,370.51 4,322.31 4,880.07 8,400.00 91.15 285.81 4,368.51 4,320.31 4,907.31 8,500.00 91.15 285.81 4,366.51 4,318.31 4,934.55 8,600.00 91.15 285.81 4,364.51 4,316.31 4,961.79 8,700.00 91.15 285.81 4,362.51 4,314.31 4,989.04 8,800.00 91.15 285.81 4,360.52 4,312.32 5,016.28 8,900.00 91.15 285.81 4,358.52 4,310.32 5,043.52 9,000.00 91.15 285.81 4,356.52 4,308.32 5,070.76 9,100.00 91.15 285.81 4,354.52 4,306.32 5,098.00 9,200.00 91.15 285.81 4,352.52 4,304.32 5,125.25 9,290.21 91.15 285.81 4,350.72 4,302.52 5,149.82 Start Dir 4°/100' : 9326.27' MD, 4350.07'TVD 9,300.00 91.13 286.10 4,350.53 4,302.33 5,152.51 9,400.00 90.97 289.10 4,348.69 4,300.49 5,182.74 9,430.00 90.92 290.00 4,348.20 4,300.00 5,192.78 9,500.00 90.92 292.10 4,347.07 4,298.87 5,217.92 9,600.00 90.92 295.10 4,345.47 4,297.27 5,257.95 9,637.86 90.92 296.24 4,344.86 4,296.66 5,274.34 End Dir : 9637.86' MD, 4344.86' TVD 9,700.00 90.92 296.24 4,343.86 4,295.66 5,301.81 9,800.00 90.92 296.24 4,342.25 4,294.05 5,346.01 9,900.00 90.92 296.24 4,340.64 4,292.44 5,390.21 10,000.00 90.92 296.24 4,339.03 4,290.83 5,434.42 10,100.00 90.92 296.24 4,337.43 4,289.23 5,478.62 10,200.00 90.92 296.24 4,335.82 4,287.62 5,522.82 10,300.00 90.92 296.24 4,334.21 4,286.01 5,567.02 10,400.00 90.92 296.24 4,332.60 4,284.40 5,611.22 10,500.00 90.92 296.24 4,330.99 4,282.79 5,655.43 11/91Y2018 11:53:52AM Page 6 COMPASS 5000.15 Build 91 Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 4,287.78 51.66 6,020,761.52 569,397.30 4.00 3,498.34 -41.19 6,020,787.03 569,304.21 0.00 3,577.83 -137.02 6,020,813.36 569,208.15 0.00 3,659.86 -232.85 6,020,839.69 569,112.08 0.00 3,741.90 -328.68 6,020,866.02 569,016.01 0.00 3,823.93 -379.56 6,020,880.00 568,965.00 0.00 3,867.49 -404.06 6,020,886.73 568,940.43 4.00 3,888.47 -424.56 6,020,892.36 568,919.89 4.00 3,906.01 -527.20 6,020,920.50 568,816.98 4.00 3,993.84 -616.93 6,020,945.07 568,727.04 0.00 4,070.58 -713.12 6,020,971.41 568,630.60 0.00 4,152.86 -809.32 6,020,997.75 568,534.16 0.00 4,235.15 -905.52 6,021,024.09 568,437.72 0.00 4,317.43 -1,001.72 6,021,050.44 568,341.29 0.00 4,399.71 -1,097.91 6,021,076.78 568,244.85 0.00 4,482.00 -1,194.11 6,021,103.12 568,148.41 0.00 4,564.28 -1,290.31 6,021,129.46 568,051.97 0.00 4,646.56 -1,386.50 6,021,155.81 567,955.54 0.00 4,728.85 -1,482.70 6,021,182.15 567,859.10 0.00 4,811.13 -1,578.90 6,021,208.49 567,762.66 0.00 4,893.41 -1,675.10 6,021,234.83 567,666.22 0.00 4,975.70 -1,771.29 6,021,261.18 567,569.79 0.00 5,057.98 -1,867.49 6,021,287.52 567,473.35 0.00 5,140.26 -1,954.27 6,021,311.28 567,386.35 0.00 5,214.49 -1,963.68 6,021,313.88 567,376.92 3.00 5,222.56 -2,058.97 6,021,343.23 567,281.36 3.00 5,306.57 -2,087.24 6,021,353.00 567,253.00 3.00 5,332.32 -2,152.55 6,021,377.53 567,187.46 3.00 5,393.31 -2,244.17 6,021,416.69 567,095.49 3.00 5,482.52 -2,278.29 6,021,432.77 567,061.22 3.00 5,516.90 -2,334.02 6,021,459.71 567,005.24 0.00 5,573.58 -2,423.70 6,021,503.07 566,915.16 0.00 5,664.78 -2,513.39 6,021,546.44 566,825.07 0.00 5,755.99 -2,603.08 6,021,589.80 566,734.99 0.00 5,847.20 -2,692.76 6,021,633.16 566,644.90 0.00 5,938.41 -2,782.45 6,021,676.52 566,554.81 0.00 6,029.62 -2,872.13 6,021,719.88 566,464.73 0.00 6,120.82 -2,961.82 6,021,763.24 566,374.64 0.00 6,212.03 -3,051.51 6,021,806.60 566,284.56 0.00 6,303.24 11/91Y2018 11:53:52AM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US + CANADA Company: H ilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Measured Map Map Vertical Northing Easting DLS Depth (usft) Inclination (usft) Azimuth Depth TVDss +NIS (usft) 0.00 (1) -3,151.62 (") 566,184.00 (usft) usft -3,229.96 (usft) 10,600.00 3.00 90.92 -3,316.26 296.24 566,018.53 4,329.39 4,281.19 -3,399.83 5,699.63 10,611.63 3.00 90.92 -3,472.96 296.24 565,860.85 4,329.20 4,281.00 -3,480.47 5,704.77 Start Dir 3°1100' : 10611.63' MD, 4329.2'TVD -3,559.83 6,022,117.35 565,773.37 10,700.00 6,870.29 90.50 6,022,177.42 298.85 0.00 4,328.10 4,279.90 6,022,237.49 5,745.63 10,800.00 7,065.17 90.03 6,022,297.56 301.82 0.00 4,327.64 4,279.44 6,022,357.63 5,796.13 10,900.00 7,260.05 89.56 6,022,413.00 304.78 0.00 4,328.00 4,279.80 6,022,417.68 5,851.02 10,990.54 7,357.49 89.13 6,022,475.31 307.46 3.00 4,329.04 4,280.84 6,022,528.60 5,904.39 End Dir : 10990.54' 6,022,577.42 MD, 4329.04' TVD 7,643.02 -4,289.13 6,022,617.48 11,000.00 3.00 89.13 4,297.99 307.46 565,030.55 4,329.18 4,280.98 -4,388.19 5,910.14 11,100.00 0.00 89.13 4,478.40 307.46 564,849.36 4,330.71 4,282.51 -4,568.60 5,970.96 11,200.00 0.00 89.13 -4,658.81 307.46 564,668.17 4,332.23 4,284.03 -4,749.01 6,031.77 11,300.00 0.00 89.13 -4,839.22 307.46 564,486.98 4,333.75 4,285.55 -4,929.42 6,092.59 11,400.00 0.00 89.13 -5,019.63 307.46 564,305.80 4,335.27 4,287.07 -5,109.83 6,153.40 11,500.00 0.00 89.13 -5,200.03 307.46 564,124.61 4,336.80 4,288.60 -5,290.24 6,214.22 11,592.19 0.00 89.13 -5,380.44 307.46 563,943.42 4,338.20 4,290.00 -5,470.65 6,270.29 Start Dir 3"1100' : 11592.19' 8,914.20 MD, 4338.2 TVD 6,023,214.08 563,762.23 0.00 11,600.00 -5,651.06 89.15 563,671.64 307.23 9,095.68 4,338.32 4,290.12 563,581.05 6,275.02 11,700.00 -5,831.46 89.42 563,490.45 304.24 9,277.15 4,339.57 4,291.37 563,399.86 6,333.41 11,800.00 -6,011.87 89.69 563,309.26 301.25 9,458.63 4,340.34 4,292.14 563,270.00 6,387.50 11,900.00 89.97 298.27 4,340.64 4,292.44 6,437.13 11,990.18 90.21 295.57 4,340.50 4,292.30 6,477.95 End Dir : 11990.18' MD, 4340.5' TVD 12,000.00 90.21 295.57 4,340.46 4,292.26 6,482.19 12,100.00 90.21 295.57 4,340.09 4,291.89 6,525.35 12,200.00 90.21 295.57 4,339.71 4,291.51 6,568.51 12,300.00 90.21 295.57 4,339.34 4,291.14 6,611.68 12,400.00 90.21 295.57 4,338.96 4,290.76 6,654.84 12,500.00 90.21 295.57 4,338.59 4,290.39 6,698.00 12,600.00 90.21 295.57 4,338.22 4,290.02 6,741.17 12,700.00 90.21 295.57 4,337.84 4,289.64 6,784.33 12,800.00 90.21 295.57 4,337.47 4,289.27 6,827.49 12,900.00 90.21 295.57 4,337.10 4,288.90 6,870.65 13,000.00 90.21 295.57 4,336.72 4,288.52 6,913.82 13,100.00 90.21 295.57 4,336.35 4,288.15 6,956.98 13,200.00 90.21 295.57 4,335.98 4,287.78 7,000.14 13,300.00 90.21 295.57 4,335.60 4,287.40 7,043.31 13,400.00 90.21 295.57 4,335.23 4,287.03 7,086.47 13,500.00 90.21 295.57 4,334.86 4,286.66 7,129.63 13,600.00 90.21 295.57 4,334.48 4,286.28 7,172.79 13,700.00 90.21 295.57 4,334.11 4,285.91 7,215.96 13,800.00 90.21 295.57 4,333.74 4,285.54 7,259.12 13,900.00 90.21 295.57 4,333.36 4,285.16 7,302.28 13,943.34 90.21 295.57 4,333.20 4,285.00 7,320.99 Total Depth : 13943.34' MD, 4333.2' TVD - 6 518" x 8112" Halliburton Standard Proposal Report Well Plan: MPU E-37 MPE-37 wp03 @ 48.20usft MPE-37 wp03 @ 48.20usft Tme Minimum Curvature llYWO18 11:53.'52AM Page 7 COMPASS 5000.15 Build 91 Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 4,281.19 -3,141.19 6,021,849.96 566,194.47 0.00 6,394.45 -3,151.62 6,021,855.00 566,184.00 0.00 6,405.06 -3,229.96 6,021,895.13 566,105.29 3.00 6,486.46 -3,316.26 6,021,944.82 566,018.53 3.00 6,580.36 -3,399.83 6,021,998.92 565,934.46 3.00 6,675.92 -3,472.96 6,022,051.60 565,860.85 3.00 6,763.64 -3,480.47 6,022,057.28 565,853.29 0.00 6,772.85 -3,559.83 6,022,117.35 565,773.37 0.00 6,870.29 -3,639.20 6,022,177.42 565,693.44 0.00 6,967.73 -3,718.57 6,022,237.49 565,613.52 0.00 7,065.17 -3,797.93 6,022,297.56 565,533.60 0.00 7,162.61 -3,877.30 6,022,357.63 565,453.68 0.00 7,260.05 -3,950.47 6,022,413.00 565,380.00 0.00 7,349.88 -3,956.68 6,022,417.68 565,373.74 3.00 7,357.49 -4,037.83 6,022,475.31 565,292.05 3.00 7,454.20 -4,121.93 6,022,528.60 565,207.47 3.00 7,549.47 -4,208.73 6,022,577.42 565,120.22 3.00 7,643.02 -4,289.13 6,022,617.48 565,039.44 3.00 7,725.71 4,297.99 6,022,621.64 565,030.55 0.00 7,734.62 -4,388.19 6,022,663.96 564,939.95 0.00 7,825.36 4,478.40 6,022,706.27 564,849.36 0.00 7,916.09 -4,568.60 6,022,748.59 564,758.77 0.00 8,006.83 -4,658.81 6,022,790.91 564,668.17 0.00 8,097.57 -4,749.01 6,022,833.22 564,577.58 0.00 8,188.30 -4,839.22 6,022,875.54 564,486.98 0.00 8,279.04 -4,929.42 6,022,917.86 564,396.39 0.00 8,369.78 -5,019.63 6,022,960.17 564,305.80 0.00 8,460.52 -5,109.83 6,023,002.49 564,215.20 0.00 8,551.25 -5,200.03 6,023,044.81 564,124.61 0.00 8,641.99 -5,290.24 6,023,087.13 564,034.01 0.00 8,732.73 -5,380.44 6,023,129.44 563,943.42 0.00 8,823.47 -5,470.65 6,023,171.76 563,852.83 0.00 8,914.20 -5,560.85 6,023,214.08 563,762.23 0.00 9,004.94 -5,651.06 6,023,256.39 563,671.64 0.00 9,095.68 -5,741.26 6,023,298.71 563,581.05 0.00 9,186.41 -5,831.46 6,023,341.03 563,490.45 0.00 9,277.15 -5,921.67 6,023,383.34 563,399.86 0.00 9,367.89 -6,011.87 6,023,425.66 563,309.26 0.00 9,458.63 -6,050.97 6,023,444.00 563,270.00 0.00 9,497.95 llYWO18 11:53.'52AM Page 7 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Targets Target Name - hiVmiss target - Shape MPE-37 wp07 CP3 - plan hits target center - Circle (radius 50.00) MPE-37 wp07 Toe 0.00 - plan hits target center - Circle (radius 50.00) MPE-37 wp07 CP2 0.00 - plan hits target center - Circle (radius 50.00) MPE-37 wp07 CPi 0.00 - plan hits target center - Circle (radius 50.00) MPE-37 wp07 Heel 0.00 - plan hits target center - Circle (radius 50.00) Casing Points Measured Vertical Depth Depth (usft) (usft) 7,653.10 4,375.20 95/8"x121/4" 13,943.34 4,333.20 6 5/8" x 8 1/2" Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-37 TVD Reference: MPE-37 wp03 @ 48.20usft MD Reference: MPE-37 wp03 @ 48.20usft North Reference: True Survey Calculation Method: Minimum Curvature Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing (°) (°) (usft) (usft) (usft) (usft) 0.00 0.00 4,338.20 6,270.28 -3,950.46 6,022,413.00 Formations Measured Vertical Vertical Depth Depth Depth SS (usft) (usft) 5,585.20 3,748.20 LA3 3,440.66 2,504.20 SVt 2,426.01 1,915.20 BPRF 7,678.65 4,377.20 SB OA 6,695.66 4,241.20 SB NA Easting (usft) 565,380.00 0.00 4,333.20 7,320.99 -6,050.97 6,023,444.00 563,270.00 0.00 4,329.20 5,704.77 -3,151.62 6,021,855.00 566,184.00 0.00 4,348.20 5,192.78 -2,087.24 6,021,353.00 567,253.00 0.00 4,375.20 4,703.81 Name Name -379.56 6,020,880.00 568,965.00 Casing Hole Diameter Diameter 9-5/8 12-1/4 6-5/8 8-1/2 Dip Dip Direction Lithology (°) (1 11/92018 11:53.,52AM Page 8 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-37 Wellbore: MPE-37 Design: MPE-37 wp07 Plan Annotations Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-37 MPE37 wp03 @ 48.20usft MPE-37 wp03 @ 48.20usft True Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 280.00 280.00 0.00 0.00 Start Dir 3°/100' : 280' MD, 280'TVD 550.00 549.10 14.60 12.25 Start Dir 4°/100' : 550' MD, 549.1'TVD 700.00 696.38 38.43 27.13 Start Dir 4.5°/100' : 700' MD, 696.38'TVD 1,200.00 1,147.42 230.76 106.98 Start Dir 4°/100': 1200' MD, 1147.42'TVD 1,665.59 1,473.78 541.90 214.47 End Dir : 1665.59' MD, 1473.78' TVD 4,984.67 3,400.49 3,114.01 1,044.12 Start Dir40/100' : 4984.67' MD, 3400.49'TVD 7,203.10 4,335.98 4,581.30 51.66 End Dir : 7203.1' MD, 4335.98' TVD - Start ESP Tangent 7,653.10 4,375.20 4,703.81 -379.56 Start Dir 4°/100' : 7653.1' MD, 4375.2'TVD 7,806.73 4,380.36 4,745.69 -527.20 End Dir : 7806.66' MD, 4380.37' TVD 9,290.21 4,350.72 5,149.82 -1,954.27 Start Dir4°/100': 9326.27'MD, 4350.07'TVD 9,637.86 4,344.86 5,274.34 -2,278.29 End Dir : 9637.86' MD, 4344.86' TVD 10,611.63 4,329.20 5,704.77 -3,151.62 Start Dir 3°/100' : 10611.63' MD, 4329.2'TVD 10,990.54 4,329.04 5,904.39 -3,472.96 End Dir : 10990.54' MD, 4329.04' TVD 11,592.19 4,338.20 6,270.29 -3,950.47 Start Dir 3°/100' : 11592.19' MD, 4338.2'TVD 11,990.18 4,340.50 6,477.95 -4,289.13 End Dir : 11990.18' MD, 4340.5' TVD 13,943.34 4,333.20 7,320.99 -6,050.97 Total Depth : 13943.34' MD, 4333.2' TVD 11/9/2018 11:53.52AM Page 9 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-37 MPE-37 MPE-37 wp07 Sperry Drilling Services Clearance Summary Anticollision Report 09 November, 2018 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Well Coordinates: 6,016,180.37 N, 569,388.31 E (70° 27'16.41 " N, 149' 26.01.54" W) Datum Height: MPE-37 wp03 @ 48.20usft Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE37 - MPE-37 wp07 Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Hilcorp Alaska, LLC Milne Point Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt B Pad MPB-06 - MPB-06 - MPM6 6,460.45 472.60 6,460.45 340.27 5,753.07 3.571 Centre Distance Pass - MPB-06 - MPB-06 - MPB-06 6,601.50 496.69 6,601.50 303.99 5,780.36 2.561 Ellipse Separation Pass - MPB-06-MPB-06-MP&06 6,726.50 559.44 6,726.50 325.32 5,808.68 2.390 Clearance Factor Pass - MPB-07- MPB-07- MPB-07 7,653.10 1,186.22 7,653.10 863.75 6,203.01 3.679 Clearance Factor Pass - MPB-09 - MPS -09 - MPB-09 7,551.50 678.10 7,551.50 429.86 6,115.06 2.732 Clearance Factor Pass - MPB-09 - MPB-09 - MPB-09 7,653.10 653.51 7,653.10 417.29 6,184.80 2.767 Ellipse Separation Pass - MPB-22 - MPB-22 - MPB-22 6,173.50 507.62 6,173.50 299.86 5,928.36 2.443 Centre Distance Pass - MPB-22 - MPB-22 - MPB-22 6,301.50 528.08 6,301.50 269.05 5,905.18 2.039 Ellipse Separation Pass - MPB-22 - MPB-22 - MPB-22 6,376.50 557.75 6,376.50 277.31 5,894.20 1.989 Clearance Factor Pass - MPB-22-MPB-22A-MPB-22A 6,173.50 507.62 6,173.50 299.86 5,928.36 2.443 Centre Distance Pass - MPB-22 - MPB-22A- MPB-22A 6,301.50 528.08 6,301.50 269.05 5,905.18 2.039 Ellipse Separation Pass - MPB-22 - MPB-22A- MPB-22A 6,376.50 557.75 6,376.50 277.31 5,894.20 1.989 Clearance Factor Pass - MPB-22 - MPB-22APB1 - MPB-22APB1 6,173.50 507.62 6,173.50 299.86 5,928.36 2.443 Centre Distance Pass - MPB-22 - MPB-22APB1 - MPB-22APB1 6,301.50 528.08 6,301.50 269.05 5,905.18 2.039 Ellipse Separation Pass - MPB-22 - MPB-22APB1 - MPB-22APB1 6,376.50 557.75 6,376.50 277.31 5,894,20 1.989 Clearance Factor Pass - M Pt E Pad MPE-04 - MPE-04 - MPE-04 1,377.80 194.59 1,377.80 175.73 1,416.65 10.320 Ellipse Separation Pass - MPE-04 - MPE-04 - MPE-04 1,426.50 197.91 1,426.50 178.42 1,452.59 10.153 Clearance Factor Pass - MPE-05 - MPE-05 - MPE-05 1,168.87 200.86 1,168.87 183.51 1,179.41 11.578 Centre Distance Pass - MPE-05 - MPE-05 - MPE-05 1,176.50 200.92 1,176.50 183.51 1,185.62 11.536 Ellipse Separation Pass - MPE-05 - MPE-05 - MPE-05 1,226.50 204.41 1,226.50 186.54 1,225.93 11.442 Clearance Factor Pass- MPE-06 - MPE-06 - MPE-06 1,139.72 172.22 1,139.72 155.21 1,148.82 10.129 Centre Distance Pass - MPE-06 - MPE-06 - MPE-06 1,151.50 172.30 1,151.50 155.19 1,160.11 10.071 Ellipse Separation Pass - MPE-06 - MPE-06 - MPE-06 1,201.50 174.64 1,201.50 157.10 1,207.38 9.958 Clearance Factor Pass - MPE-07 - MPE-07 - MPE-07 827.07 168.55 827.07 154.57 828.17 12.053 Centre Distance Pass - MPE-07 - MPE-07 - MPE-07 851.50 168.73 851.50 154.54 851.20 11.888 Ellipse Separation Pass - MPE-07 - MPE-07 - MPE-07 951.50 174.22 951.50 159.17 943.51 11.577 Clearance Factor Pass - 09 November, 2018 - 11:37 Page 2 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Hileorp Alaska, LLC Milne Point 09 November, 2018 - 11:37 Page 3 of 9 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-08 - MPE-08 - MPE-08 1,643.29 363.07 1,643.29 340.36 1,665.93 15.988 Centre Distance Pass - MPE-08 - MPE-08 - MPE-08 1,651.50 363.12 1,651.50 340.35 1,672.51 15.942 Ellipse Separation Pass - MPE-08 - MPE-08 - MPE-08 1,751.50 371.12 1,751.50 347.47 1,745.90 15.697 Clearance Factor Pass - MPE-11 - MPE-11 - MPE-11 26.50 238.62 26.50 237.70 32.11 259.681 Centre Distance Pass - MPE-11 - MPE-11 - MPE-11 326.50 239.43 326.50 234.51 330.99 48.627 Ellipse Separation Pass - MPE-11 - MPE-11 - MPE-11 801.50 278.98 801.50 267.83 800.98 25.030 Clearance Factor Pass - MPE-12 - MPE-12 - MPE-12 260.60 59.44 260.60 54.67 269.75 12.456 Centre Distance Pass - MPE-12 - MPE-12 - MPE-12 926.50 60.59 926.50 49.39 931.52 5.407 Ellipse Separation Pass - MPE-12 - MPE-12 - MPE-12 951.50 60.91 951.50 49.60 956.34 5.389 Clearance Factor Pass - MPE-14 - MPE-14 - MPE-14 220.74 168.41 220.74 165.42 230.24 56.337 Centre Distance Pass - MPE-14 - MPE-14 - MPE-14 301.50 168.63 301.50 164.66 310.54 42.423 Ellipse Separation Pass - MPE-14 - MPE-14 - MPE-14 701.50 210.25 701.50 201.38 706.10 23.698 Clearance Factor Pass - MPE-14 - MPE-14A - MPE-14A 220.74 168.41 220.74 165.71 230.24 62.187 Centre Distance Pass - MPE-14 - MPE-14A- MPE-14A 301.50 168.63 301.50 164.94 310.54 45.653 Ellipse Separation Pass - MPE-14 - MPE-14A- MPE-14A 701.50 210.25 701.50 201.66 706.10 24.474 Clearance Factor Pass - MPE-14 - MPE-14APB1 - MPE-14AP81 220.74 168.41 220.74 165.42 230.24 56.337 Centre Distance Pass - MPE-14 - MPE-14APB1 - MPE-14APB1 301.50 168.63 301.50 164.66 310.54 42.422 Ellipse Separation Pass - MPE-14 - MPE-14APB1 - MPE-14AP91 701.50 210.25 701.50 201.38 706.10 23.698 Clearance Factor Pass - MPE-15 - MPE-15 - MPE-15 101.50 160.63 101.50 158.74 107.20 84.965 Centre Distance Pass - MPE-15 - MPE-15 - MPE-15 276.50 162.53 276.50 157.21 279.42 30.577 Ellipse Separation Pass - MPE-15 - MPE-15 - MPE-15 701.50 216.18 701.50 202.51 697.00 15.812 Clearance Factor Pass - MPE-16 - MPE-16 - MPE-16 1,185.19 126.45 1,185.19 112.92 1,182.09 9.351 Centre Distance Pass - MPE-16 - MPE-16 - MPE-16 1,201.50 126.47 1,201.50 112.87 1,199.35 9.296 Ellipse Separation Pass - MPE-16 - MPE-16 - MPE-16 1,276.50 127.67 1,276.50 113.70 1,277.34 9.141 Clearance Factor Pass - MPE-17 - MPE-17 - MPE-17 7 601.28 17.67 601.28 9.8 607.10 2.252 Centre Distance Pass - MPE-17 -MPE-17 -MPE-17 601.50 17.67 601.50 9.82 607.32 2.251 Ellipse Separation Pass - /7\ MPE-17 -MPE-17 -MPE-17 626.50 18.07 626.50 9.90 632.11 2.213 Clearance Factor Pass - MPE-18-MPE-18-MPE-18 26.50 217.70 26.50 216.35 35.97 161.323 Centre Distance Pass - MPE-18 - MPE-18 - MPE-18 226.50 218.64 226.50 215.58 233.30 71.535 Ellipse Separation Pass - MPE-18 - MPE-18 - MPE-18 701.50 268.65 701.50 259.85 681.07 30.539 Clearance Factor Pass - 09 November, 2018 - 11:37 Page 3 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE-37 - MPE.37 Wp07 Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Hilcorp Alaska, LLC Milne Point 09 November, 2018 - 11:37 Page 4 of 9 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-19 - MPE-19 - MPE-19 210.88 89.21 210.88 86.33 221.23 31.024 Centre Distance Pass - MPE-19 - MPE-19 - MPE-19 326.50 90.13 326.50 85.85 335.32 21.055 Ellipse Separation Pass - MPE-19 - MPE-19 - MPE-19 701.50 105.09 701.50 96.20 701.01 11.826 Clearance Factor _ Pass - MPE-20 - MPE-20 - MPE-20 237.69 197.37 237.69 193.95 245.50 57.766 Centre Distance Pass - MPE-20 - MPE-20 - MPE-20 326.50 197.72 326.50 193.21 334.59 43.811 Ellipse Separation Pass - MPE-20 - MPE-20 - MPE-20 776.50 243.46 776.50 233.74 775.61 25.045 Clearance Factor Pass - MPE-20 - MPE-20A- MPE-20A 237.69 197.37 237.69 194.19 248.05 62.122 Centre Distance Pass - MPE-20 - MPE-20A - MPE-20A 326.50 197.72 326.50 193.45 337.14 46.267 Ellipse Separation Pass - MPE-20 - MPE-20A - MPE-20A 776.50 243.46 776.50 233.98 778.16 25.677 Clearance Factor Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 237.69 197.37 237.69 194.32 248.05 64.777 Centre Distance Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 326.50 197.72 326.50 193.58 337.14 47.721 Ellipse Separation Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 776.50 243.46 776.50 234.11 778.16 26.034 Clearance Factor Pass - MPE-20-MPE-20AL1 PB1 - MPE-20ALl PBI 237.69 197.37 237.69 193.67 248.05 53.448 Centre Distance Pass - MPE-20-MPE-20AL1 PB1 - MPE-20ALl PB1 326.50 197.72 326.50 192.94 337.14 41.286 Ellipse Separation Pass - MPE-20-MPE-20AL1 P81-MPE-20AL1 P131 751.50 238.66 751.50 228.85 755.17 24.343 Clearance Factor Pass - MPE-21 - MPE-21 - MPE-21 1,013.31 164.08 1,013.31 154.26 1,023.77 16.709 Ellipse Separation Pass - MPE-21 - MPE-21 - MPE-21 1,051.50 165.27 1,051.50 155.26 1,057.01 16.514 Clearance Factor Pass - MPE-23 - MPE-23 - MPE-23 736.37 109.58 736.37 99.02 738.69 10.377 Centre Distance Pass - MPE-23 - MPE-23 - MPE-23 751.50 109.65 751.50 98.94 753.25 10.240 Ellipse Separation Pass - MPE-23 - MPE-23 - MPE-23 801.50 111.00 801.50 99.82 801.01 9.928 Clearance Factor Pass- �- MPE-24 - MPE-24 - MPE-24 216.83 181.04 216.83 178.08 225.73 61.058 Centre Distance Pass - MPE-24 - MPE-24 - MPE-24 276.50 181.25 276.50 177.57 284.11 49.140 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 701.50 245.00 701.50 236.22 677.16 27.914 Clearance Factor Pass - MPE-24 - MPE-24A- MPE-24A 216.83 181.04 216.83 178.19 222.33 63.397 Centre Distance Pass - MPE-24 - MPE-24A- MPE-24A 276.50 181.25 276.50 177.68 280.71 50.642 Ellipse Separation Pass - MPE-24 - MPE-24A- MPE-24A 701.50 245.00 701.50 236.33 673.76 28.266 Clearance Factor Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 216.83 181.04 216.83 178.29 222.33 65.797 Centre Distance Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 276.50 181.25 276.50 177.78 280.71 52.160 Ellipse Separation Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 701.50 245.00 701.50 236.44 673.76 28.610 Clearance Factor Pass - MPE-3O - MPE-30 - MPE-30 945.99 244.66 945.99 234.72 928.03 24.636 Centre Distance Pass - 09 November, 2018 - 11:37 Page 4 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Hileorp Alaska, LLC Milne Point 09 November, 2018 - 11:37 Page 5 of 9 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-30 - MPE-30 - MPE-30 951.50 244.67 951.50 234.72 932.33 24.589 Ellipse Separation Pass - MPE-30 - MPE-30 - MPE-30 5,401.50 1,163.55 5,401.50 1,028.97 5,710.81 8.646 Clearance Factor Pass- MPE-30 - MPE-30A- MPE-30A 945.99 244.66 945.99 234.79 928.03 24.805 Centre Distance Pass - MPE-30 - MPE-30A - MPE-30A 951.50 244.67 951.50 234.78 932.33 24.757 Ellipse Separation Pass - MPE-30 - MPE-30A - MPE-30A 5,401.50 1,163.55 5,401.50 1,028.69 5,710.81 8.628 Clearance Factor Pass - MPE-30 - MPE-30AL1 - MPE-30AL1 945.99 244.66 945.99 234.81 928.03 24.857 Centre Distance Pass - MPE-30 - MPE-30ALl - MPE-30ALl 951.50 244.67 951.50 234.80 932.33 24.810 Ellipse Separation Pass - MPE-30-MPE-30AL1-MPE-30AL1 5,401.50 1,163.55 5,401.50 1,028.68 5,710.81 8.627 Clearance Factor Pass - MPE-30-MPE-30AL1PB1-MPE-30AL1PB1 945.99 244.66 945.99 234.72 928.03 24.636 Centre Distance Pass - MPE-30-MPE-30AL1 PB1 -MPE-30AL1PB1 951.50 244.67 951.50 234.72 932.33 24.589 Ellipse Separation Pass - MPE-30-MPE-30AL1 PB1 -MPE-30AL1 PB1 5,401.50 1,163.55 5,401.50 1,028.34 5,710.81 8.605 Clearance Factor Pass - MPE-30 - MPE-30APB1 - MPE-30APB1 945.99 244.66 945.99 234.72 928.03 24.636 Centre Distance Pass - MPE-30 - MPE-30APB1 - MPE-30APB1 951.50 244.67 951.50 234.72 932.33 24.589 Ellipse Separation Pass - MPE-30-MPE-30APB1-MPE-30APB1 5,401.50 1,163.55 5,401.50 1,028.53 5,710.81 8.618 Clearance Factor Pass - MPE-31 - MPE-31 - MPE-31 1,676.50 168.22 1,676.50 150.53 1,658.86 9.509 Clearance Factor Pass - MPE-31 - MPE-31 - MPE-31 1,751.50 163.64 1,751.50 146.98 1,723.04 9.824 Ellipse Separation Pass - MPE-31 - MPE-31 - MPE-31 1,753.24 163.64 1,753.24 147.01 1,724.57 9.840 Centre Distance Pass - MPE-31 - MPE-31PB1 - MPE-31 PB1 1,676.50 168.22 1,676.50 150.53 1,658.86 9.509 Clearance Factor Pass - MPE-31 - MPE-31 PB1-MPE-31 PB1 1,751.50 163.64 1,751.50 146.98 1,723.04 9.824 Ellipse Separation Pass- _ MPE-31-MPE-31PB1-MPE-31 PB1 1,753.24 163.64 1,753.24 147.01 1,724.57 9.840 Centre Distance Pass - MPE-32 - MPE-32 - MPE-32 1,442.14 318.87 1,442.14 304.89 1,434.24 22.811 Ellipse Separation Pass - MPE-32 - MPE-32 - MPE-32 1,501.50 321.08 1,501.50 306.87 1,483.45 22.593 Clearance Factor Pass - MPE-32 - MPE-321-1 - MPE-321-1 1,442.14 318.87 1,442.14 304.89 1,434.24 22.811 Ellipse Separation Pass - MPE-32-MPE-321-1-MPE-32L1 1,501.50 321.08 1,501.50 306.87 1,483.45 22.593 Clearance Factor Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 1,442.14 318.87 1,442.14 304.89 1,434.24 22.811 Ellipse Separation Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 1,501.50 321.08 1,501.50 306.87 1,483.45 22.593 Clearance Factor Pass - MPE-33 - MPE-33 - MPE-33 1,168.48 483.87 1,168.48 472.71 1,100.97 43.379 Centre Distance Pass - MPE-33 - MPE-33 - MPE-33 1,176.50 483.89 1,176.50 472.70 1,106.19 43.236 Ellipse Separation Pass - MPE-33 - MPE-33 - MPE-33 7,653.10 1,399.46 7,653.10 1,165.34 7,596.69 5.978 Clearance Factor Pass - Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09a 276.50 60.58 276.50 56.60 276.50 15.187 Centre Distance Pass - 09 November, 2018 - 11:37 Page 5 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Scan Range: 26.50 to 7,653.10 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Hilcorp Alaska, LLC Milne Point From (usft) 26.50 750.00 7,660.00 To (usft) 750.00 MPE-37 wp07 7,660.00 MPE-37 wp07 13,943.34 MPE-37 wp07 Survey/Plan Survey Tool 2_Gyro-SR-GSS 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag 09 November, 2018 - 11:37 Page 6 of 9 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 576.50 61.40 576.50 53.70 578.26 7.973 Ellipse Separation Pass - Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 701.50 67.50 701.50 58.22 702.95 7.272 Clearance Factor Pass - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 551.50 30.44 551.50 20.34 552.36 3.012 Centre Distance Pass - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 601.50 30.87 601.50 19.86 602.56 2.805 Ellipse Separation Pass - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 701.50 34.19 701.50 21.35 702.87 2.663 Clearance Factor Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 864.79 149.37 864.79 138.27 919.62 13.462 Ellipse Separation Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 901.50 150.39 901.50 139.17 952.46 13.398 Clearance Factor Pass - Plan: MPU E-40 - MPE-40i - MPE-40 wp01 276.50 181.96 276.50 178.10 276.50 47.170 Centre Distance Pass - Plan: MPU E40 - MPE401- MPE40 wp01 301.50 182.08 301.50 177.91 301.50 43.711 Ellipse Separation Pass - Plan: MPU E-40 - MPE401- MPE-40 wp01 701.50 238.59 701.50 229.64 681.28 26.678 Clearance Factor Pass - Plan: MPU E-41 - MPE-41 - MPE-41 wp01 276.50 169.07 276.50 165.08 276.50 42.381 Centre Distance Pass - Plan: MPU E-41 - MPE-41 - MPE41 wp01 301.50 169.19 301.50 164.89 301.50 39.373 Ellipse Separation Pass - Plan: MPU E-41 - MPE-41 - MPE-41 wp01 651.50 216.73 651.50 208.29 629.51 25.667 Clearance Factor Pass - Prelim DualLatPlan: MPU E-39 - MPU E -39i - MPU E-: 276.50 161.30 276.50 157.44 276.50 41.813 Centre Distance Pass - Prelim DualLatPlan: MPU E-39 - MPU E -39i - MPU E-: 301.50 161.42 301.50 157.25 301.50 38.752 Ellipse Separation Pass - Prelim Duall-atPlan: MPU E-39 - MPU E -39i - MPU E-: 601.50 201.52 601.50 193.82 579.21 26.162 Clearance Factor Pass - From (usft) 26.50 750.00 7,660.00 To (usft) 750.00 MPE-37 wp07 7,660.00 MPE-37 wp07 13,943.34 MPE-37 wp07 Survey/Plan Survey Tool 2_Gyro-SR-GSS 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag 09 November, 2018 - 11:37 Page 6 of 9 COMPASS HALLIBURTON REFERENCE INFORMATION WELL DETAILS:Phn: MPU E-37 NAD 1927(NADCON COWS) Alaska Zone D4 Project: Milne Point Coordirete(WE) Refeream: war Plan: MPU EaT, True NoM Site: M Pt E Pad VC V,u,1(WD) Reference: MPE27 mD3 Q4a.W0 ft Gmund levet 21 ]0 Well: Plan: MPU E-37 Measured Depth Refarerope'. MPEJ7 mD3@4 Mmft +NLS +V_w Notlhing EhI Latittude Longitude leper" Orllling Wellbore: MPE-37 calculation Method: Minimum curvature ODD 0.00 60161BU37 569388.31 70°27'16,412N 149°26'1542W Plan: MPE-37 wp07 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 2001 100/1000 of reference Date: 2018-101 VeRdeted: Yes Version: 26.50 To 13943.34 Depth From Depth To Survey/Plan Tool CASING DETAILS Ladder S.F. Plots If 2650 750.00 MPE-37 wp07(MPE-37) 2_Gyro-SR-GSS TVD TVDSS MD Size Namp SH(1 of 2) MPE-37) 75000 766000 MPE-37 apOT(MPE-37) 2_MWD+IFR2+MS+Sag 8375.20 4327.00 7fi53.10 9-5/R 95/R"x121/4" ]660.00 13943.34 MPE-37 Wp07(2MWD+IFR2+MS+Seg 4333.20 4285.00 13943.34 6-5/8 6 5/8" n 8 1/2" J MPE 07 4FI c_ I X150.00 I N MPE-1 0 o MPE-23 MPE-23 I i rE, 20.OD E-18 — ----- ---"------ -- c 0 MPE-19 - M E-36 wp0E o. 90.00 — —___ _._ _}... ...-------- ._------ —. ....... .....__-__._ fA MPU E-35 wp09 ` ."MPE- 2 _ MPU -35 wp09 N 60.00 U MPE-12 0 N MPE-36 wpO8 M E-36 wp0 C 30.00 U MPE-17 0.00 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Measured Depth (800 usfUin) 4.50 .... I __.....___ `o T m 3.00 LL C O n Collision Risk Procedures Req. N 1,50 Collision Avoidance Req. No -Go Zone - Stop rilling 0.06 0 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 Measured Depth HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Hilcorp Alaska, LLC Milne Point 09 November, 2018 - 11:37 Page 7 of 9 COMPASS Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-37 MPE-37 MPE-37 wp07 Sperry Drilling Services Clearance Summary Anticollision Report 09 November, 2018 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E37 - MPE-37 - MPE-37 wp07 Well Coordinates: 6,016,180.37 N, 569,388.31 E (70° 27' 16.41" N, 149' 26'01.54" W) Datum Height: MPE-37 wp03 @ 48.20usft Scan Range: 7,653.10 to 13,943.34 usft. Measured Depth. Scan Radius Is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,000.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E37 - MPE-37 - MPE-37 wp07 Scan Range: 7,653.10 to 13,943.34 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt B Pad MPB-06 - MPB-06 - MPB-06 MPB-07 - MPB-07 - MPB-07 MPB-07 - MPB-07 - MPB-07 MPB-07 - MPB-07 - MPB-07 MPB-09 - MPB-09 - MPB-09 MPB-09 - MPB-09 - MPB-09 MPB-09 - MPB-09 - MPB-09 MPB-25 - MPB-25 - MPB-25 MPB-25 - MPB-25 - MPB-25 MPB-25 - MPB-25 - MPB-25 M Pt E Pad MPE-33 - MPE-33 - MPE-33 MPE-33 - MPE-33 - MPE-33 MPE-33 - MPE-33 - MPE-33 Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Plan: MPU E-36 - MPE-36 - MPE-36 wp08 From (usft) 26.50 750.00 7,660.00 Hilcorp Alaska, LLC Milne Point Separation Warning 7,653.10 1,365.88 7,653.10 1,059.25 6,096.41 4.455 Clearance Factor Pass - 8,178.10 1,006.87 8,178.10 696.83 6,500.00 3.248 Clearance Factor Pass - 8,328.10 984.54 8,328.10 688.42 6,568.32 3.325 Ellipse Separation Pass - 8,494.12 976.24 8,494.12 697.79 6,663.98 3.506 Centre Distance Pass - 7,653.10 653.51 7,653.10 417.29 6,184.80 2.767 Clearance Factor Pass - 7,678.10 648.81 7,678.10 416.94 6,201.62 2.798 Ellipse Separation Pass - 7,803.29 637.68 7,803.29 431.79 6,274.18 3.097 Centre Distance Pass - 10,278.10 738.05 10,278.10 468.40 7,758.43 2.737 Clearance Factor Pass - 10,428.10 709.18 10,428.10 456.39 7,868.74 2.805 Ellipse Separation Pass - 10,739.18 688.62 10,739.18 494.51 8,103.79 3.547 Centre Distance Pass - 8,828.10 431.74 8,828.10 204.77 7,793.00 1.902 Clearance Factor Pass - 8,878.10 413.20 8,878.10 199.10 7,793.00 1.930 Ellipse Separation Pass - 9,009.74 391.67 9,009.74 226.32 7,793.00 2.369 Centre Distance Pass - 9,516.64 970.09 9,516.64 831.69 8,493.05 7.010 Centre Distance Pass - 9,578.10 971.07 9,578.10 830.34 8,554.50 6.900 Ellipse Separation Pass - 13,943.34 1,177.46 13,943.34 837.36 12,976.86 3.462 Clearance Factor Pass - To (usft) 750.00 MPE-37 wp07 7,660.00 MPE-37 wp07 13,943.34 MPE-37 wp07 Survey/Plan Survey Tool 2_Gyro-SR-GSS 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag 09 November, 2018 - 11:48 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-37 - MPE-37 wp07 Ellipse error terms are correlated across survey tool tie<m points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Hilcorp Alaska, LLC Milne Point 09 November, 2018 - 11:48 Page 3 of 5 COMPASS ( ( ; i ]» ) \ I _ _ �\ (/ / ) Z0, / t ( e �& _ ( \ ^ j);}! )LbUJ6/ 9! i E&( , )$K/ \ t )$%% «)) CO 2 - Q' : 0 \LP \� z / �\ �c«_}me_/me `gym_\ 9 ° TRANSMITTAL LETTER CHECKLIST WELL NAME: /I%DV r- ---3 % PTD: zlv ✓ Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: < ( c , h 7 POOL: 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 th_e original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -_) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. %. P 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 {s I Com an Name in the attached application, the follow' g well logs are also required for this well: d4l'67& may Well Logging �� tt< ,41—"�" �otS�J� Requirements U Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 I WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 PTD#:2181580 Company HILCORF_ALNW_ l LC Initial Class/Type Well Name: MILNE PT UNIT E-37 Program DEV Well bore seg ❑ DEV / PEND Geoi 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.03QQ.1.A),G•2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ . _ ............... _ ........... Surface -casing protects all known_USDWs............ ......... ... 1 Permit fee attached__... ------- ------.NA.. ------------------------ ---- ---- _. C.MT.vol, adequate to circulateop eonductor& surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Surface Location lies within ADLOQ25518; Top Productive Interval &.TOlie in ADL0047437. CMT vol adequate to tie-in long string to.surf csg.. _ _ _ _ _ _ _ _ _ _ _ 3 Unique well name and number. ... .. _...__ _______________ Yes...__. 22 CMT will cover all known productive horizons _ 4 Well located in a defined pool . . ....... . . . . . . _ _ _ _ _ _ _ _ _ _ _ Yes _ Milne Point Schrader Bluff Oil Pool (525140), governed by CO 477, amended by CO 477,05. Casing designs adequate for QJ, B &_permafrost _ _ _ _ _ _ _ _ _ _ _ 5 .Well located proper distance from drilling unit boundary ... Yes _ CO 477.05 species: "There are no restrictions as to well spacing except that no pay shall Adequate tankage. or reserve pit _ _ _ 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."_ If a re-drilL has_a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in drilling unit.. _ ..... _ . Yes .. _ _ Well bore conforms to spacing requirements.. Adequate wellbore separationproposed _ _ _ ...... . .... . ......... 8 If deviated, is wellbore plat. included _ _ _ _ _ _ _ _ _ .. - - . _ Yes 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ __ _ _ _ ____ _ _ _ _ 9 Operator only affected part... - - - - - - - - - - - - - - - - - - Yes 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 Operator has appropriate_ bond in force .. _ ... Yes 29 Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ _ Yes 30 BOPS press rating appropriate; test to (put psig in comments)... _ ...... 12 Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 31 SFD 11/28/2018 _ . _ Yes _ Gen 5 slim_ hole wellhead 32 Work will occur without operation shutdown... - .. _ . _ _ _ _ 13 Can permit be approved before 15 -day -wait .............. . _ ............ Yes 33 Is presence of H2$ gas probable _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ 14 Well located within area and strata authorized by. Injection Order # (put. 10# in. comments) (For. NA 34and 34 Mechantcal condition of wells within AOR verified. (Forservice well Only) 15 All wells.within 1(4. mile area of review identified (For service well only). _ _ _ _ _ _ _ NA.. 35 Permit can be issued w/o hydrogen_ sulfide measures _ _ _ .. _ _ 16 Pre -produced injector; duration of pre -production less than 3 months (For service well only) _ NA. _ _ _ _ _ ........ Geologic 18 Conductor string provided . . . . . . . . . . . . . . . . ......................... Yes ...... 20" conductor set at 107ft. Cemented.. Engineering 19 Surface -casing protects all known_USDWs............ ......... ... ..... .. NA. .. No Aquifers 20 C.MT.vol, adequate to circulateop eonductor& surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ 2 stage_ cement_job, ES at 2500 ft. 21 CMT vol adequate to tie-in long string to.surf csg.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ lateral will be OH with pre perfed 6 5/8" liner 22 CMT will cover all known productive horizons _ ...... Yes 23 Casing designs adequate for QJ, B &_permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ BTC supplied._ No issues 24 Adequate tankage. or reserve pit _ _ _ _ _ _ Yes _ .. _ Rig has Steel tanks 25 If a re-drilL has_a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ ........... . 26 Adequate wellbore separationproposed _ _ _ ...... . .... . ......... Yes _ NO issues with collision._ E-17 is close at about 600 ft md, 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ __ _ _ _ ____ _ _ _ _ _ _ _____ Yes Innovation has 16" diverter line. Schematic provided.. , Appr Date 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ Max form pressure =.1925 psi (8,45 ppg EMW) will drill with.8.9- 9.5 ppg mud GLS 12/6/2018 29 BOPEs, do they meet regulation _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ Rig has 13 518" 5000 psi BOPE 3 1W choke/Kili lines..... 30 BOPS press rating appropriate; test to (put psig in comments)... _ ...... ...... Yes MASP = 14Wpsi Will test BOPE to 3000 psi 31 Choke. manifold complies w/API_ RP -53 (May 84)_ _ _ _ _ _ _ _ .. _ . _ Yes _ Gen 5 slim_ hole wellhead 32 Work will occur without operation shutdown... - .. _ . _ _ _ _ _ Yes _ _ _ _ . .......................... . . . . . . . . 33 Is presence of H2$ gas probable _ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ _ _ _ ...... Yes _ _ _ H2S on pad, Rig has sensors -------- 34and 34 Mechantcal condition of wells within AOR verified. (Forservice well Only) 35 Permit can be issued w/o hydrogen_ sulfide measures _ _ _ .. _ _ _ No _ _ _ H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms..... _ .... Geology 36 Data presented on potential overpressure zones _ _ _ _ . _ _ _ _ _ _ _ _ Yes _ _ _ _ Hydrates expected at base permafrost; mitigation dispussed in Drilling Hazards section. Operator's. Appr Date 37 Seismic analysis of shallow gas zones .................. . . _ NA _ _ _ planned mud weights appear sufficient to, control expected formation pressures. Operator will have. SFD 11/28/2018 38 Seabed condition survey (if off -shore) _ _______ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ onsite materials sufficient to build active system to 1 ppg above highest anticipated mud weight 39 Contact name/phone for weekly_ progress reports. [exploratory only] ..... .. ........ NA... Geologic Engineering Public ESP producer... running Tieback casing for additional monitoring annulus. GIs Commissioner: Date: Commissioner: Date o ssioner Date S� 6C �� `� rr2/%//Q / t Z ( b ire,