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Home My WebLink About218-066Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' 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: ESP Swap 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): 13,500' N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng SCHRADER BLUFF OIL N/A 3,759' 13,485' 3,759' 813 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-54 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/28/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0025515 218-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23607-00-00 Hilcorp Alaska LLC C.O 477.05 6,904' 6,708' Length Size Proposed Pools: 114' 114' TVD Burst MILNE POINT 6,791' 6,708' MD N/A 9,020psi 5,750psi 6,890psi 3,960' 3,947' 3,759'13,490' See Schematic See Schematic 2-7/8" 114' 16" 9-5/8" 7-5/8" 6,904' 4-1/2" BOT SLZXP and N/A 6,699 MD/ 3,946 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): 6.5 / L-80 / EUE 8rd 5,388' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:34 pm, Oct 13, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.10.13 13:09:13 - 08'00' Taylor Wellman (2143) 325-625 10-404 If reservoir pressure exceeds 8.55 ppg EMW, ESP packer will be required per CO 390A. A.Dewhurst 14OCT25 BJM 10/15/25 X BOP test to 2000 psi 10/16/2025 Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Well Name:MPL-54 API Number:50-029-23607-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:10/25/25 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:218-066 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,163 psi @ 3,498 TVD DH Gauge 8/28/24 | 6.4 EMW, 6.9 KWF Max Potential Surface Pressure: 813 psi Gas Column Gradient (0.1 psi/ft) Max Angle:70°+ Sail Angle from 6,163 MD Brief Well Summary: MPU L-54 is a Schrader Nb producer. It was drilled and the 1st ESP installed July 2018. This well has had 2 ESP installs. August 2024, it failed from a downhole electrical failure in the motor. February 2025 this ESP was Balanced phase to phase but grounded Phase to ground. During the install the MLE/ cable splice got hung up and damaged and caused the failure. March 2025 the ESP was replaced and grounded electrically in September 2025. Objectives: Pull failed ESP completion, run an ESP with a gas handling pump between the intake and gas separator. Notes Regarding Wellbore Condition: - 7 casing test to 1,500 psi on 7/3/2018 at 6,699 MD. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Attempt to pull dummy valve from GLM at 5,154 MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 202 MD. 5. Run SBHPS. We will use the updated data to determine KWF. There is no reason to believe this well will require an ESP packer but will confirm with data. 6. Caliper from the discharge head to surface. 7. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water. Run SBHPS. We will use the updated data to determine KWF. There is no reason to believe this well will require an ESP packer but will confirm with data. Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel 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. Test BOPE to 250 psi low/ 2,000 psi high. Test annular to 250 psi low/ 2,000 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 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. 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. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC Gen 5, 11" x 2-7/8" EUE Box top & bottom, 2-1/2" H BPVG b. 2025 tubing PU weight on ASR recorded as 40 kip. Slack off weight recorded as 23 kip. c. 2-7/8 L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8 tubing. a. Re-use all visibly good tubing. 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. Recorded Clamp Totals: i. Canon Clamps: 94 ii. Protectolizer Clamps: 5 10. Lay Down ESP. Collect any solids sample and get them to chemical guys Cole or Mitch for analysis. Make sure the ESP tech posts all pictures to the Centrilift folder on the Hilcorp drive. 2-7/8 ESP Completion: 11. RIH with used 2-7/8 6.5# L-80 ESP completion to +/- 5,400 and obtain string weights. a. Run a cap string 3/8, confirm with Justin Bailey based on clamps. Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 b. Check electrical continuity every 1000. c. Note PU and SO weights on tally. d. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 17 Motor - 350HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 3 INTAKE GPXARCINT FER H6 35 5.38 6 PMP 538PMCSHD 08 GH7000 CG1 HS 5.38 6 Gas Separator 52 5.38 10 PMP 538PMSXD 20 GINPSHH H6 FER 12CRC 45 5.38 13 PMP 538PMSXD 66 FLEX47 HS 12CRC 45 5.38 24 PMP 538PMSXD FLEX27 82 FER H6 12CRC 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 4,950 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 12. Land tubing hanger. Use extra caution to not damage cable. 13. Lay down landing joint. 14. Set BPV. 15. RDMO ASR. Post-Rig Procedure: Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. 11 Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 4/16/2025 SCHEMATIC Milne Point Unit Well: MPU L-54 Last Completed: 3/19/2025 PTD: 218-066 TD =13,500(MD) /TD =3,759 (TVD) 4 & 5 16 Orig. KB Elev.:33.7/ GL Elev.:15.4 7-5/8 12 4 17 9-5/8 1 2 3 18 See Screen Liner Detail PBTD =13,485 (MD) /PBTD =3,759 (TVD) 9-5/8 ES Cementer @ 2,501 MD 6 & 7 4-1/2 Shoe @ 13,490 14 1315 16 2-7/8 8 & 9 10 & 11 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B/ Weld N/A Surface 114 N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904 0.0758 7-5/8 Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708 0.0459 4-1/2 Liner 250 Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699 13,490 .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,388 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 Lead - 555 sx / Tail 400 sx Stg 2 Lead 461 sx / Tail 270 sx Class G (229 bbls to surface) 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 252 Max Hole Angle = 95.1° @ 7,302 MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/2018 ESP Completion by ASR#1 - 8/26/2024 ESP Completion by ASR#1 - 3/19/2025 JEWELRY DETAIL No. Top MD Item ID 1 202 GLM #2: PATCO, 2-7/8" x 1" KBMM with 1/4'' DPSOV installed 2.347 2 5,154 GLM #1: PATCO, 2-7/8" x 1" KBMM with DV installed 2.347 3 5,247 XN Nipple:2.205 Min ID 2.205 4 5,301 Discharge Head: B/O PMP 513 5 5,301 Zenith Ported Sub: PRESS PORT 513/538P 6 5,302 Pump #2: 538PMSXD FLEX27 135 FER H6 12CRC 7 5,330 Pump #1: 538PMSXD 20 GINPSHH H6 FER 12CRC 8 5,340 Gas Separator: 538 GM2T HV E V X MT HS FER STD 9 5,345 Bolt On Intake: Intake GPXARCINT FER H6 10 5,346 Upper Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 11 5,353 Lower Tandem Seal: GS3 B/B/L SB H6 PFSA HL FER 12CRC 12 5,360 Motor: 562XP 350/2440/88/14R 12CRC 13 5,383 Zenith Sensor & Centralizer:Bottom @ 5,388 14 6,699 BOT SLZXP LTP / Liner Hanger 7 x 9-5/8(TVD 3,946)6.190 15 6,708 7-5/8 Tieback Assy. 6.151 16 6,721 7 H563 x 4.5 Hyd 625 XO 3.850 17 13,453 4-1/2 Drillable Packoff Sub 2.390 18 13,485 WIV Valve LTC BxB (1 Ball on Seat/Closed) - 4-1/2 SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890 3,959 7,014 3,963 12 Bkr/HES 7,175 3,957 7,670 3,936 59 HES 7,793 3,930 10,232 3,845 17 HES 10,354 3,839 11,056 3,831 24 HES 11,218 3,823 12,209 3,791 26 HES 12,333 3,785 13,407 3,759 _____________________________________________________________________________________ Revised By: TDF 10/10/2025 PROPOSED Milne Point Unit Well: MPU L-54 Last Completed: 3/19/2025 PTD: 218-066 TD =13,500(MD) /TD =3,759 (TVD) 4 16 Orig. KB Elev.:33.7/ GL Elev.:15.4 7-5/8 13 4 18 9-5/8 1 2 3 19 See Screen Liner Detail PBTD =13,485 (MD) /PBTD =3,759 (TVD) 9-5/8 ES Cementer @ 2,501 MD 5, 6 & 7 4-1/2 Shoe @ 13,490 15 1416 17 2-7/8 8, 9 & 10 11 & 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B/ Weld N/A Surface 114 N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904 0.0758 7-5/8 Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708 0.0459 4-1/2 Liner 250 Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699 13,490 .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface ±5,388 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 Lead - 555 sx / Tail 400 sx Stg 2 Lead 461 sx / Tail 270 sx Class G (229 bbls to surface) 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 252 Max Hole Angle = 95.1° @ 7,302 MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/2018 ESP Completion by ASR#1 - 8/26/2024 ESP Completion by ASR#1 - 3/19/2025 JEWELRY DETAIL No. Top MD Item ID 1 ±200 GLM #2: 2-7/8" x 1" with 1/4'' OV installed 2.347 2 ±X,XXX GLM #1: 2-7/8" x 1 with DV installed 2.347 3 ±X,XXX XN Nipple: 2.313: 2.205 Min ID 2.205 4 ±X,XXX Ported Discharge Head 5 ±X,XXX Pump #3: 538PMSXD FLEX27 82 FER H6 12CRC 6 ±X,XXX Pump #2: 538PMSXD 66 FLEX47 HS 12CRC 7 ±X,XXX Pump #1: 538PMSXD 20 GINPSHH H6 FER 12CRC 8 ±X,XXX Gas Separator 9 ±X,XXX PMP 538PMCSHD 08 GH7000 CG1 HS 10 ±X,XXX INTAKE GPXARCINT FER H6 11 ±X,XXX Upper Tandem Seal 12 ±X,XXX Lower Tandem Seal 13 ±X,XXX Motor - 350HP 14 ±X,XXX Sensor & Centralizer: Btm @ ±X,XXX 15 6,699 BOT SLZXP LTP / Liner Hanger 7 x 9-5/8(TVD 3,946)6.190 16 6,708 7-5/8 Tieback Assy. 6.151 17 6,721 7 H563 x 4.5 Hyd 625 XO 3.850 18 13,453 4-1/2 Drillable Packoff Sub 2.390 19 13,485 WIV Valve LTC BxB (1 Ball on Seat/Closed) - 4-1/2 SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890 3,959 7,014 3,963 12 Bkr/HES 7,175 3,957 7,670 3,936 59 HES 7,793 3,930 10,232 3,845 17 HES 10,354 3,839 11,056 3,831 24 HES 11,218 3,823 12,209 3,791 26 HES 12,333 3,785 13,407 3,759 Milne Point ASR Rig 1 BOPE 2025 Updated 7/31/2025 11 BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head 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: ESP Swap 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): 13,500'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng BOT SLZXP and N/A 6,699 MD/ 3,946 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): 6.5 / L-80 / EUE 8rd 5,400' 13,490' See Schematic See Schematic 2-7/8" 114' 16" 9-5/8" 7-5/8" 6,904' 4-1/2"6,791' 6,708' MD N/A 9,020psi 5,750psi 6,890psi 3,960' 3,947' 3,759' 6,904' 6,708' Length Size Proposed Pools: 114' 114' TVD Burst MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0025515 218-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23607-00-00 Hilcorp Alaska LLC C.O 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3/25/2025 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 L-54 SCHRADER BLUFF OIL N/A 3,759' 13,485' 3,759' 813 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 325-108 By Gavin Gluyas at 8:53 am, Feb 27, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.02.26 21:30:23 - 09'00' Taylor Wellman (2143) * BOPE test to 2000 psi. MGR04MAR25 A.Dewhurst 03MAR25 DSR-2/28/25 10-404 *&: 03/13/25 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.13 14:06:35 -08'00' RBDMS JSB 031825 Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Well Name:MPL-54 API Number:50-029-23607-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:3/25/25 Estimated Duration:5days Regulatory Contact:Tom Fouts Permit to Drill Number:218-066 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,163 psi @ 3,498’ TVD DH Gauge 8/28/24 | 6.4 EMW, 6.9 KWF Max Potential Surface Pressure: 813 psi Gas Column Gradient (0.1 psi/ft) Max Angle:70°+ Sail Angle from 6,163’ MD Brief Well Summary: MPU L-54 is a Schrader Nb producer. It was drilled and the 1st ESP installed July 2018. This well has had 2 ESP installs. August 2024, it failed from a downhole electrical failure in the motor. February 2025 this ESP was Balanced phase to phase but grounded Phase to ground. During the install the MLE/ cable splice got hung up and damaged so an armor repair was performed. That is the suspected culprit of the short run life. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 1,500 psi on 7/3/2018 at 6,699’ MD. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Attempt to pull dummy valve from GLM at 5,142’ MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 171’ MD. 5. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel 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. Test BOPE to 250 psi low/ 2,000 psi high. Test annular to 250 psi low/ 2,000 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 3-1/2” test joint. e. Test single rams on 2-3/8” test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. 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. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC Gen 5, 11" x 2-7/8" EUE Box top & bottom, 2-1/2" H BPVG b. 2024 tubing PU weight on ASR recorded as 38 kip. Slack off weight recorded as 23 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use all visibly good tubing. 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. Recorded Clamp Totals: i. Canon Clamps: 95 ii. Flatguard Clamps: 2 iii. Protectolizer Clamps: 7 iv. Pump Clamps: 3 10. Lay Down ESP. Collect any solids sample and get them to chemical guys Cole or Mitch for analysis. Make sure the ESP tech posts all pictures to the Centrilift folder on the Hilcorp drive. Contingency Cleanout Run: 1) MU and TIH w/ VACS Cleanout BHA: 2) TIH to cleanout well to 31’ past the last screen, 13,438’ MD. 3) Upon successful cleanout, TOOH laying down workstring and cleanout BHA 2-7/8” ESP Completion: Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 11. RIH with used 2-7/8” 6.5# L-80 ESP completion to +/- 5,400’ and obtain string weights. a. Run a cap string ¼” or 3/8”, confirm with engineer based on clamps. b. Check electrical continuity every 1000’. c. Note PU and SO weights on tally. d. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 17 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 6 Gas Separator 52 5.38 10 Pumps – 400 PMSXD 024 GINPSHL 45 5.38 13 Pumps – 400 PMSXD 069 MVPER 45 5.38 24 Pumps – 400 PMXSD 134 FLEXER 45 5.38 24 Pumps – 400 PMXSD 134 FLEXER 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 4,500 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 12. Land tubing hanger. Use extra caution to not damage cable. 13. Lay down landing joint. 14. Set BPV. 15. RDMO ASR. Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. 11” Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 10/3/2024 SCHEMATIC Milne Point Unit Well: MPU L-54 Last Completed: 8/26/2024 PTD: 218-066 TD =13,500’ (MD) / TD =3,759’ (TVD) 4 & 5 16” Orig. KB Elev.: 33.7’ / GL Elev.: 15.4’ 7-5/8” 14 4 19 9-5/8” 1 2 3 20 See Screen Liner Detail PBTD =13,485’ (MD) / PBTD =3,759’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,501’ MD 6, 7, 8 & 9 4-1/2” Shoe @ 13,490’ 16 1517 18 2-7/8” 10 & 11 12 & 13 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B / Weld N/A Surface 114’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699’ 13,490’ .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,398’ 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 –Lead - 555 sx / Tail –400 sx Stg 2 – Lead – 461 sx / Tail – 270 sx Class G (229 bbls to surface) 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 252’ Max Hole Angle = 95.1° @ 7,302’ MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/2018 ESP Completion by ASR#1 - 8/26/2024 JEWELRY DETAIL No. Top MD Item ID 1 171’ GLM #2: PATCO, 2-7/8" x 1" KBMM with 1/4'' DPSOV installed 2.347” 2 5,142’ GLM #1: PATCO, 2-7/8" x 1" KBMM with DV installed 2.347” 3 5,233’ XN Nipple:2.205” Min ID 2.205” 4 5,285.6’ Discharge Head: B/O PMP 513 5 5,286’ Ported Discharge Flange: PRESS PORT 513/538P 6 5,287’ Pump #4: 400 PMSXD 024 GINPSHL H6 FER STD PNT 7 5,310’ Pump #3: 400 PMSXD 069 MVPER H6 FER NO PNT 8 5,334’ Pump #2: 400 PMXSD 134 FLEXER HF H6 FE 9 5,346’ Pump #1: 400 PMXSD 134 FLEXER HF H6 FE 10 5,357’ Gas Separator: 538 GSTHVEVX MT H6 FER STD PNT 11 5,362’ Intake: Bolt On 12 5,363’ Upper Tandem Seal: GSB BL SB H6 PFSA HL FER 12CRC 13 5,370’ Lower Tandem Seal: GSB BL SB H6 PFSA HL FER 12CRC 14 5,377’ Motor: 562XP S CS 250/2505/61 10R 15 5,396’ Zenith Sensor & Centralizer: Bottom @ 5,398’ 16 6,699’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3,946’)6.190” 17 6,708’ 7-5/8” Tieback Assy. 6.151” 18 6,721’ 7” H563 x 4.5” Hyd 625 XO 3.850” 19 13,453’ 4-1/2” Drillable Packoff Sub 2.390” 20 13,485’ WIV Valve LTC BxB (1” Ball on Seat/Closed) - 4-1/2” SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890’ 3,959’ 7,014’ 3,963’ 12 Bkr/HES 7,175’ 3,957’ 7,670’ 3,936’ 59 HES 7,793’ 3,930’ 10,232’ 3,845’ 17 HES 10,354’ 3,839’ 11,056’ 3,831’ 24 HES 11,218’ 3,823’ 12,209’ 3,791’ 26 HES 12,333’ 3,785’ 13,407’ 3,759’ _____________________________________________________________________________________ Revised By: DH 2/25/2025 PROPOSED Milne Point Unit Well: MPU L-54 Last Completed: 8/26/2024 PTD: 218-066 TD =13,500’(MD) /TD =3,759’ (TVD) 4 16” Orig. KB Elev.:33.7’/ GL Elev.:15.4’ 7-5/8” 11 4 17 9-5/8” 1 2 3 18 See Screen Liner Detail PBTD =13,485’ (MD) / PBTD =3,759’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,501’ MD 5,6 & 7 4-1/2” Shoe @ 13,490’ 14 12 & 13 15 16 2-7/8” 8 19 & 10 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B / Weld N/A Surface 114’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699’ 13,490’ .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,398’ 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 –Lead - 555 sx / Tail –400 sx Stg 2 – Lead – 461 sx / Tail – 270 sx Class G (229 bbls to surface) 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 252’ Max Hole Angle = 95.1° @ 7,302’ MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/2018 ESP Completion by ASR#1 - 8/26/2024 JEWELRY DETAIL No. Top MD Item ID 1 ±XXX’GLM STA# 1:GLM/w .25" OV 2.347” 2 ±X,XXX’GLM STA# 2:Dummy 2.347” 3 ±X,XXX’ 2.313” XN Nipple, 2.205” No-Go 2.205” 4 ±X,XXX’ Ported Discharge Head: ±X,XXX’ Pump 4 5 ±X,XXX’ Pump 3: 6 ±X,XXX’ Pump 2: 7 ±X,XXX’ Pump 1: 8 ±X,XXX’ Gas Separator: 9 ±X,XXX’ Upper Tandem Seal: 10 ±X,XXX’ Lower Tandem Seal: 11 ±X,XXX’ Motor: 250HP 12 ±X,XXX’ Intake Sensor: 13 ±X,XXX’ Centralizer: Bottom @ ±X,XXX’ 14 6,708’ 7-5/8” Tieback Assy. 6.190” 15 6,721’ 7” H563 x 4.5” Hyd 625 XO 6.151” 16 13,453’ 4-1/2” Drillable Packoff Sub 3.850” 17 13,485’ WIV Valve LTC BxB (1” Ball on Seat/Closed) 2.390” 18 6,708’ 7-5/8” Tieback Assy. - 4-1/2” SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890’ 3,959’ 7,014’ 3,963’ 12 Bkr/HES 7,175’ 3,957’ 7,670’ 3,936’ 59 HES 7,793’ 3,930’ 10,232’ 3,845’ 17 HES 10,354’ 3,839’ 11,056’ 3,831’ 24 HES 11,218’ 3,823’ 12,209’ 3,791’ 26 HES 12,333’ 3,785’ 13,407’ 3,759’ Updated 10/9/2024 11” BOPE INTEGRATED 11'’-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 2-3/8" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 10/9/2024 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,500 feet N/A feet true vertical 3,759 feet N/A feet Effective Depth measured 13,485 feet 6,699 feet true vertical 3,759 feet 3,946 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 / EUE 8rd 5,398' 3,501' Packers and SSSV (type, measured and true vertical depth)BOT SLZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 324-463 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 48 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 504 Gas-Mcf MD 114' 350 Size 114' 3,960' 321 30033 524 376181 372 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-066 50-029-23607-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509 & ADL0025515 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT L-54 Plugs Junk measured Length 6,791' Casing Conductor 3,759'13,490' 6,708' 6,904'Surface Tieback Liner 16" 9-5/8" 7-5/8" 114' 6,904' 8,540psi 5,750psi 6,890psi 9,020psi 6,708' 3,947' Burst N/A Collapse N/A 3,090psi 4,790psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:19 am, Oct 03, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.10.03 10:23:44 - 08'00' Taylor Wellman (2143) RBDMS JSB 100324 DSR-10/10/24WCB 2-10-2025 _____________________________________________________________________________________ Revised By: TDF 10/3/2024 PROPOSED Milne Point Unit Well: MPU L-54 Last Completed: 8/26/2024 PTD: 218-066 TD =13,500’(MD) /TD =3,759’ (TVD) 4& 5 16” Orig. KB Elev.: 33.7’ / GL Elev.: 15.4’ 7-5/8” 14 4 19 9-5/8” 1 2 3 20 See Screen Liner Detail PBTD =13,485’ (MD) / PBTD = 3,759’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,501’ MD 6, 7, 8 & 9 4-1/2” Shoe @ 13,490’ 16 1517 18 2-7/8” 10 & 11 12 & 13 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B / Weld N/A Surface 114’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699’ 13,490’ .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,398’ 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead - 555 sx / Tail – 400 sx Stg 2 – Lead – 461 sx / Tail – 270 sx Class G (229 bbls to surface) 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 252’ Max Hole Angle = 95.1° @ 7,302’ MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/2018 ESP Completion by ASR#1 - 8/26/2024 JEWELRY DETAIL No. Top MD Item ID 1 171’ GLM #2: PATCO, 2-7/8" x 1" KBMM with 1/4'' DPSOV installed 2.347” 2 5,142’ GLM #1: PATCO, 2-7/8" x 1" KBMM with DV installed 2.347” 3 5,233’ XN Nipple: 2.205” Min ID 2.205” 4 5,285.6’ Discharge Head: B/O PMP 513 5 5,286’ Ported Discharge Flange: PRESS PORT 513/538P 6 5,287’ Pump #4: 400 PMSXD 024 GINPSHL H6 FER STD PNT 7 5,310’ Pump #3: 400 PMSXD 069 MVPER H6 FER NO PNT 8 5,334’ Pump #2: 400 PMXSD 134 FLEXER HF H6 FE 9 5,346’ Pump #1: 400 PMXSD 134 FLEXER HF H6 FE 10 5,357’ Gas Separator: 538 GSTHVEVX MT H6 FER STD PNT 11 5,362’ Intake: Bolt On 12 5,363’ Upper Tandem Seal: GSB BL SB H6 PFSA HL FER 12CRC 13 5,370’ Lower Tandem Seal: GSB BL SB H6 PFSA HL FER 12CRC 14 5,377’ Motor: 562XP S CS 250/2505/61 10R 15 5,396’ Zenith Sensor & Centralizer: Bottom @ 5,398’ 16 6,699’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3,946’)6.190” 17 6,708’ 7-5/8” Tieback Assy. 6.151” 18 6,721’ 7” H563 x 4.5” Hyd 625 XO 3.850” 19 13,453’ 4-1/2” Drillable Packoff Sub 2.390” 20 13,485’ WIV Valve LTC BxB (1” Ball on Seat/Closed) - 4-1/2” SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890’ 3,959’ 7,014’ 3,963’ 12 Bkr/HES 7,175’ 3,957’ 7,670’ 3,936’ 59 HES 7,793’ 3,930’ 10,232’ 3,845’ 17 HES 10,354’ 3,839’ 11,056’ 3,831’ 24 HES 11,218’ 3,823’ 12,209’ 3,791’ 26 HES 12,333’ 3,785’ 13,407’ 3,759’ Well Name Rig API Number Well Permit Number Start Date End Date MP L-54 ASR#1 & WH 50-029-23607-00-00 218-066 8/23/2024 8/27/2024 8/23/2024 - Friday Accept rig at 23:00 on 8-23-2024. Start testing BOPE as per approved sundry. AOGCC waived witness to testing, Test to 250 psi low & testing new double gates to 5,000 psi for proof test. 8/21/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/22/2024 - Thursday No operations to report. WELLHEAD; MU tubing hanger, terminate the ESP cable and splice to the TB hanger penetrator and plug 3/8 control line. Land hanger to RKB RILDS, Set BPV with T-bar, NU tree, test hanger void to 500 low 5000 high 5/10 min (good test). Pull BPV with T- bar and secure well. Cont. testing BOPE as per approved sundry. AOGCC waived witness to testing, Test to 250 psi low & testing new double gates to 5,000 psi for proof test. Completed BOPE testing with no failures. Preform accumulator drawdown test. P/U Tee bar. With wellhead rep. remove CTS plug, & BPV. No pressure. P/U landing joint engage hanger. BOLDS. Pull hanger to rig floor. Hanger offseat at 38K. Full pick up wt = 42K no drag observed. L/D hanger. Pump 30 bbls to IA. no returns. POOH w/ 2-7/8" 6.5# L-80 ESP completion F/ 5,400' - T/ 1,024'. Pumping double displacement. No returns. P/U wt = 15K 8/24/2024 - Saturday Cont. RIH w/ 2-7/8" 6.5# L-80 ESP completion T/ 5,347' S/O wt = 23 K P/U wt = 38K Pumping double displacement to well. No returns. Checking ESP cable every 1000' P/U & M/U hanger. Complete hanger splice. Land hanger Final wts P/U = 38K S/O = 23K RILDS. Test ESP with umbilical (good). Final end of ESP centralizer depth = 5398'. P/U tee bar & install BPV in hanger. L/D Tee bar. Blow down fluid lines. Remove all remaining source water from pits, & rig. Begin RDMO. 8/27/2024 - Tuesday 8/25/2024 - Sunday Cont. POOH w/ 2-7/8" 6.5# L-80 ESP completion F/ 1,024'. Pumping double displacement. No returns. P/U wt = 15K Begin ESP disassembly. Top pump rotation restricted, binding due to sand, Motor electrically grounded. Completed ESP disassembly. P/U & M/U new ESP assy. with ALS rep. Completed ESP assembly. Re-shielded splice. Electrically test ESP (good) RIH w/ 2-7/8" 6.5# L-80 ESP completion F/ 230' T/ 3,142' S/O wt = 17 K P/U wt = 23K. Pumping double displacement to well. No returns. Checking ESP cable every 1000'. 8/26/2024 - Monday AOGCC waived witness to testing Cont. POOH w/ 2-7/8" 6.5# L-80 ESP completion MU tubing hanger, terminate the ESP cable and splice to the TB hanger penetrator and plug 3/8 control line. Land hanger to RKB RILDS Cont. RIH w/ 2-7/8" 6.5# L-80 ESP completion T/ 5,347' S/O wt = 23 K P/U wt = 38K Pumping double displacement to well. No returns. Checking ESP cable every 1000' P/U & M/U hanger. Complete hanger splice. Land hanger Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 9/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240909 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 24 50133206390000 214112 8/22/2024 AK E-LINE PPROF BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/9/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 8/17/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 7/20/2024 AK E-LINE PPROF MPU L-54 50029236070000 218066 8/14/2024 READ Caliper Survey Please include current contact information if different from above. T39522 T39523 T39524 T39525 T39525 T39526MPU L-54 50029236070000 218066 8/14/2024 READ Caliper Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.09 12:37:48 -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: ESP Swap 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): 12,500'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng SCHRADER BLUFF OIL N/A 3,759' 13,485' 3,759' 1,081 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT L-54 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 9/1/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0025515 218-066 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23607-00-00 Hilcorp Alaska LLC C.O 477.05 6,904' 6,708' Length Size Proposed Pools: 114' 114' TVD Burst MILNE POINT 6,791' 6,708' MD N/A 9,020psi 5,750psi 6,890psi 3,960' 3,947' 3,759'13,490' See Schematic See Schematic 2-7/8" 114' 16" 9-5/8" 7-5/8" 6,904' 4-1/2" BOT SLZXP and N/A 6,699 MD/ 3,946 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): 6.5 / L-80 / EUE 8rd 5,400' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2024.08.09 14:23:06 - 08'00' Scott Pessetto (9864) 324-463 By Grace Christianson at 7:52 am, Aug 12, 2024 10-404 MGR15AUG24 13,500' SFD DSR-8/12/24 BOPE test to 2000 psi. SFD 8/14/2024 1,081 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.16 08:45:09 -08'00'08/16/24 RBDMS JSB 081624 Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 Well Name:MPL-54 API Number:50-029-23607-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:9/1/2024 Estimated Duration:4 days Regulatory Contact:Tom Fouts Permit to Drill Number:218-066 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 948 psi @ 3,500’ TVD DH Gauge 8/7/24 | 5.3 EMW, 5.5 KWF Max Bottom Hole Pressure: 1431 psi @ 3,500’ TVD 7/8/2018 30-day SI | 7.9 EMW, 8.1 KWF Max Potential Surface Pressure: 1,081 psi Gas Column Gradient (0.1 psi/ft) Max Angle:70°+ Sail Angle from 6,163’ MD Brief Well Summary: MPU L-54 is a Schrader Nb producer. It was drilled and the 1st ESP installed July 2018. August 2024, it failed from a downhole electrical failure. Objectives: Pull failed ESP completion, run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 1,500 psi on 7/3/2018 at 6,699’ MD. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from 5,314’ to surface. 4. Attempt to pull dummy valve from GLM at 5,139’ MD and leave open. 5. Pull GLV and set dummy valve in upper GLM at 138’ MD. 6. Run SBHPS with 10 min stops at 5,314’ MD and 4,800’ MD 7. RDMO. Coiled Tubing (Contingency) 1. Pressure test PCE to 250 psi low / 2,500 psi high. 2. PU 1.75” jet nozzle. 3. Jet down to discharge head at 5,314’ MD. 4. Following best practices in PE manual, pump gel sweeps to clean up tubing. 5. Chase gel out of hole. 6. PU tubing punch. 7. RIH and tag discharge head. 8. Pump down ball to fire tubing punch. 9. Confirm circulation by pumping down backside of coil. 10. Freeze protect tubing as POOH. 11. RDMO. Pumping & Well Support Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water brine. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel 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. Test BOPE to 250 psi low/ 2,000 psi high. Test annular to 250 psi low/ 2,000 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” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. 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. 5. Call out Centrilift for ESP pull. 6. RU spoolers to handle ESP cable and Dual 3/8” capillary strings. a. Use extreme care in spooling the capillary string to promote reuse of the string. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC Gen 5, 11" x 2-7/8" EUE Box top & bottom, 2-1/2" H BPVG b. 2018 tubing PU weight on Doyon 14 recorded as 80 kip. Slack off weight recorded as 57 kip. Block weight 40K. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use all visibly good tubing. Contact OE for updated info based on Caliper data. 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. Recorded Clamp Totals: Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 i. Canon Clamps: 172 ii. Motor Clamps:4 iii. Seal Clamps:4 iv. Pump Clamps: 16 10. Lay Down ESP. Collect any solids sample and get them to chemical guys Cole or Mitch for analysis. Make sure the ESP tech posts all pictures to the Centrilift folder on the Hilcorp drive. 11. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 12. RIH with used 2-7/8” 6.5# L-80 ESP completion to +/- 5,400’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 250HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 57 Pumps – Flex-17.5 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 4,500 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 13. Land tubing hanger. Use extra caution to not damage cable. 14. Lay down landing joint. Well: MPL-54 PTD: 218-066 API: 50-029-23607-00-00 15. Set BPV. 16. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 8-8-2024 SCHEMATIC Milne Point Unit Well: MPU L-54 Last Completed: 7/5/18 PTD: 218-066 TD =13,500’ (MD) / TD =3,759’ (TVD) 4 16” Orig. KB Elev.: 33.7’ / GL Elev.: 15.4’ 7-5/8” 7 8/9 1 0 4 16 9-5/8” 1 2 3 17 See Screen Liner Detail PBTD = 13,485’ (MD) / PBTD =3,759’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,501’ MD 5/6 4-1/2” Shoe @ 13,490’ 11 13 1214 15 2-7/8” Capstring CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B / Weld N/A Surface 114’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699’ 13,490’ .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 5,400’ 0.0058 3/8” Dual Cap String 3/8” N/A Surface 5,400’ N/A OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead - 555 sx / Tail – 400 sx Stg 2 – Lead – 461 sx / Tail – 270 sx Class G (229 bbls to surface) 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 252’ Max Hole Angle = 95.1° @ 7,302’ MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/18 JEWELRY DETAIL No. Top MD Item ID 1 138’ GLM: 2-7/8” x 1” Side Pocket KPMG w/DPSOV 2.347” 2 5,139’ GLM w/Dummy: 2-7/8” x 1” 2.347” 3 5,261’ XN Nipple, 2.205” no go 2.205” 4 5,314’ Discharge Head: FPDIS 5 5,315’ Upper Tandem Pump: 134 STG FLEX 17.5 6 5,338’ Lower Tandem Pump: 134 STG FLEX 17.5 7 5,362’ Gas Separator: GRS FER N AR 8 5,365’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 5,372’ Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 5,379’ Motor: CL5 XP – 250hp / 2505V / 61A 11 5,396’ Sensor, Zenith 12 5,398’ Centralizer:Bottom @ 5,400’ 13 6,699’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3,946’)6.190” 14 6,708’ 7-5/8” Tieback Assy. 6.151” 15 6,721’ 7” H563 x 4.5” Hyd 625 XO 3.850” 16 13,453’ 4-1/2” Drillable Packoff Sub 2.390” 17 13,485’ WIV Valve LTC BxB (1” Ball on Seat/Closed) - 4-1/2” SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890’ 3,959’ 7,014’ 3,963’ 12 Bkr/HES 7,175’ 3,957’ 7,670’ 3,936’ 59 HES 7,793’ 3,930’ 10,232’ 3,845’ 17 HES 10,354’ 3,839’ 11,056’ 3,831’ 24 HES 11,218’ 3,823’ 12,209’ 3,791’ 26 HES 12,333’ 3,785’ 13,407’ 3,759’ _____________________________________________________________________________________ Revised By: TDF 8-8-2024 PROPOSED Milne Point Unit Well: MPU L-54 Last Completed: 7/5/18 PTD: 218-066 TD =13,500’ (MD) / TD =3,759’ (TVD) 4 16” Orig. KB Elev.: 33.7’ / GL Elev.: 15.4’ 7-5/8” 7 8/9 1 0 4 16 9-5/8” 1 2 3 17 See Screen Liner Detail PBTD = 13,485’ (MD) / PBTD =3,759’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,501’ MD 5/6 4-1/2” Shoe @ 13,490’ 11 13 1214 15 2-7/8”CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 16" Conductor 164 / A53B / Weld N/A Surface 114’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.835 Surface 6,904’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,708’ 0.0459 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hydril 625 (Baker/HES) 3.920 6,699’ 13,490’ .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface ±5,400’ 0.0058 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 – Lead - 555 sx / Tail – 400 sx Stg 2 – Lead – 461 sx / Tail – 270 sx Class G (229 bbls to surface) 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 252’ Max Hole Angle = 95.1° @ 7,302’ MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23607-00-00 ESP Completion by Doyon 14 - 7/5/18 JEWELRY DETAIL No. Top MD Item ID 1 ±138’ GLM #2 2.347” 2 ±5,139’ GLM #1 2.347” 3 ±5,261’ XN Nipple, 2.205” no go 2.205” 4 ±5,314’ Discharge Head: 5 ±5,315’ Upper Tandem Pump: 6 ±5,338’ Lower Tandem Pump: 7 ±5,362’ Gas Separator: 8 ±5,365’ Upper Tandem Seal: 9 ±5,372’ Lower Tandem Seal: 10 ±5,379’ Motor: 11 ±5,396’ Sensor, Zenith 12 ±5,398’ Centralizer: Bottom @ ±5,400’ 13 6,699’ BOT SLZXP LTP / Liner Hanger 7” x 9-5/8”(TVD 3,946’)6.190” 14 6,708’ 7-5/8” Tieback Assy. 6.151” 15 6,721’ 7” H563 x 4.5” Hyd 625 XO 3.850” 16 13,453’ 4-1/2” Drillable Packoff Sub 2.390” 17 13,485’ WIV Valve LTC BxB (1” Ball on Seat/Closed) - 4-1/2” SCREEN LINER DETAIL Jts Thread Top (MD)Top (TVD) Btm (MD) Btm (TVD) 3 Bkr Excluder 6,890’ 3,959’ 7,014’ 3,963’ 12 Bkr/HES 7,175’ 3,957’ 7,670’ 3,936’ 59 HES 7,793’ 3,930’ 10,232’ 3,845’ 17 HES 10,354’ 3,839’ 11,056’ 3,831’ 24 HES 11,218’ 3,823’ 12,209’ 3,791’ 26 HES 12,333’ 3,785’ 13,407’ 3,759’ Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR