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Home My WebLink About218-0501. 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): 14,330' N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT L-56 MILNE POINT SCHRADER BLUFF OIL N/A 3,696' 14,226' 3,696' 813 N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/25/2025 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0025514 & ADL0025515 218-050 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23604-00-00 Hilcorp Alaska LLC C.O. 477B Length Size Proposed Pools: 114' 114' Dual Cap String TVD Burst 4,979' 8,430psi MD N/A 9,020psi 5,750psi 6,890psi 3,938' 3,920' 3,809' 7,182' 6,910' 3,696'4-1/2" 114' 16" 9-5/8" 7-5/8" 7,182' 4-1/2"4,007' 6,910' 14,231' Perforation Depth MD (ft): 10,917' See Schematic 3,314' See Schematic 3/8" BOT SLZXP and N/A 6,901 MD / 3,918 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 6.5# / L-80 / EUE 8rd 4,979' 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 9:28 am, Oct 15, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.10.15 09:16:00 - 08'00' Taylor Wellman (2143) 325-631 A.Dewhurst 15OCT25 * BOPE pressure test to 2000 psi. 24 hour notice to AOGCC. 10-404 DSR-10/15/25MGR15OCT25 10/16/2025 Well: MPL-56 PTD: 218-050 API: 50-029-23604-00-00 Well Name:MPL-56 API Number:50-029-23604-00-00 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:218-050 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 L-54 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 6,168 MD Brief Well Summary: MPU L-54 is a Schrader Nb producer. It was drilled and the 1st ESP installed June 2018. This was the 1st ESP run and it became grounded and unbalanced in October 2025 after a 7+ yr run life. Objectives: Pull failed ESP completion, run new ESP Notes Regarding Wellbore Condition: - 7-5/8 x 9-5/8 annulus test to 1,500 psi on 6/13/2018 at 6,901 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 4,718 MD and leave open. 4. Pull GLV and set dummy valve in upper GLM at 136 MD. 5. Run SBHPS. We will get an updated pressure survey prior to RWO. 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 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-56 PTD: 218-050 API: 50-029-23604-00-00 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 joints. e. Test 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. 2018 tubing PU weight on Doyon recorded as 175 kip (included 40K Blocks), still seems abnormally high. Slack off weight recorded as 55 kip with blocks. 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 and dual 3/8 cap strings. a. Toss the cap string. b. Re-use tubing based on caliper results. Ask OE for confirmation. c. Keep ported discharge head and centralizer for future use. d. Note any sand or scale inside or on the outside of the ESP on the morning report. e. Recorded Clamp Totals: i. Canon Clamps = 157 ii. Motor Clamps = 4 iii. Seal Clamps =4 iv. Pump Clamps = 14 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:If there is fill on the discharge head and we think a cleanout is warranted. 11. MU 2.88 VACS tool BHA with 500 of 2-3/8 snorkel pipe, VACS engine, +-7,200 2-3/8 xo to 3- 1/2 workstring. 12. TIH and clean out to 14,150 Well: MPL-56 PTD: 218-050 API: 50-029-23604-00-00 13. TOOH laying down cleanout BHA 14. Prep to run ESP completion 2-7/8 ESP Completion: 15. RIH with used 2-7/8 6.5# L-80 ESP completion to +/- 4,980 and obtain string weights. a. Run a cap string 3/8, confirm with Justin Bailey 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 3 INTAKE GPXARCINT FER H6 35 5.38 13 PMP -45 5.38 24 PMP -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" ~4,600 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 16. Land tubing hanger. Use extra caution to not damage cable. Well: MPL-56 PTD: 218-050 API: 50-029-23604-00-00 17. Lay down landing joint. 18. Set BPV. 19. 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. 11 Triple BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 10-14-2025 SCHEMATIC Milne Point Unit Well: MPU L-56 Last Completed: 6/13/18 PTD: 218-050 TD =14,330(MD) /TD =3,696 (TVD) 4 16 Orig. KB Elev.: 34.1 / GL Elev.: 15.2 7-5/8 7 8/9 10 4 16 9-5/8 1 2 3 17 See Screen/ Solid Liner Detail PBTD =14,226 (MD) /PBTD =3,696 (TVD) 9-5/8 ES Cementer @ 2,582 MD 5/6 4-1/2 Shoe @ 14,230 11 13 1214 15 2-7/8CASING 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 7,182 0.0758 7-5/8 Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,910 0.0459 4-1/2Liner 250 Screens Detail below 13.5 / L-80 / Hydril 625/521(13CR-110) 12.6 / L-80 / Hyd 521/DWC/C 3.920 6,901 14,230 .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 4,979 0.0058 3/8 Dual Cap String 3/8 N/A Surface 4,979 N/A OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 Lead - 625 sx / Tail 400 sx Stg 2 Lead 390 sx / Tail 270 sx Class G (265 bbls to surface) 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 354 Max Hole Angle = 94.24° @ 10,231 MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23604-00-00 Completion Date: 6/13/18 4-1/2 SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 6,929 3,923 7,090 3,939 JEWELRY DETAIL No. Top MD Item ID 1 136 GLM: 2-7/8 x 1 Side Pocket KPMGw/DPSOV 2.347 2 4,718 GLM w/Dummy: 2-7/8 x 1 2.347 3 4,839 XN Nipple, 2.205 no go 2.205 4 4,892 Discharge Head: FPDIS 5 4,894 Upper Tandem Pump: 134 STG FLEX 17.5 6 4,917 Lower Tandem Pump: 134 STG FLEX 17.5 7 4,941 Gas Separator: GRS FER N AR 8 4,944 Upper Tandem Seal: GSB3DBUT SB/SB PFSA 9 4,951 Lower Tandem Seal: GSB3DBUT SB/SB PFSA 10 4,958 Motor: CL5 XP 250hp / 2505V / 61A 11 4,974 Sensor, Zenith 12 4,977 Centralizer:Bottom @ 4,979 13 6,901 BOT SLZXP LTP / Liner Hanger 7 x 9-5/8(TVD 3,920)6.190 14 6,910 7-5/8 Tieback Assy. 6.151 15 6,923 7 H563 x 4.5 Hyd 625 XO 3.850 16 14,193 4-1/2 Drillable Packoff Sub 2.390 17 14,226 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) 12 Hyd 625 13.5 7,090 3,939 7,588 3,920 92 Hyd 521 13.5 7,588 3,920 10,917 3,810 35 Hyd 521 12.6 10,917 3,810 12,414 3,761 41 DWC/C 12.6 12,414 3,761 14,144 3,697 _____________________________________________________________________________________ Revised By: TDF 10-14-2025 PROPOSED Milne Point Unit Well: MPU L-56 Last Completed: 6/13/18 PTD: 218-050 TD =14,330(MD) /TD =3,696 (TVD) 4 16 Orig. KB Elev.:34.1/ GL Elev.:15.2 7-5/8 7 8/9 1 0 4 16 9-5/8 1 2 3 17 See Screen/ Solid Liner Detail PBTD =14,226 (MD) /PBTD =3,696 (TVD) 9-5/8 ES Cementer @ 2,582 MD 5/6 4-1/2 Shoe @ 14,230 11 13 1214 15 2-7/8CASING 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 7,182 0.0758 7-5/8 Tieback 29.7 / L-80 / Vam STL SMLS 6.875 Surface 6,910 0.0459 4-1/2Liner 250 Screens Detail below 13.5 / L-80 / Hydril 625/521(13CR-110) 12.6 / L-80 / Hyd 521/DWC/C 3.920 6,901 14,230 .0149 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE-8rd 2.441 Surface 4,979 0.0058 3/8 Cap String 3/8 N/A Surface 4,979 N/A OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4"Stg 1 Lead - 625 sx / Tail 400 sx Stg 2 Lead 390 sx / Tail 270 sx Class G (265 bbls to surface) 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 354 Max Hole Angle = 94.24° @ 10,231 MD TREE & WELLHEAD Tree Cameron 2-9/16" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23604-00-00 Completion Date: 6/13/18 4-1/2 SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 6,929 3,923 7,090 3,939 JEWELRY DETAIL No. Top MD Item ID 1 ±200 GLM #2: 2-7/8 x 1 w/ ¼OV 2.347 2 ±X,XXXGLM #1: 2-7/8 x 1 w DV Installed 2.347 3 ±X,XXX 2-7/8 XN Nipple: 2.313 / 2.205 no go 2.205 4 ±X,XXX Ported Discharge Head: 5 ±X,XXX Upper Tandem Pump: 6 ±X,XXX Lower Tandem Pump: 7 ±X,XXX Intake: GPXARCINT FER H6 8 ±X,XXX Upper Tandem Seal: 9 ±X,XXX Lower Tandem Seal: 10 ±X,XXX Motor: CL5 XP 250hp 11 ±X,XXX Intake Sensor: 12 ±X,XXX Centralizer: Bottom @ ±4,980 13 6,901 BOT SLZXP LTP / Liner Hanger 7 x 9-5/8(TVD 3,920)6.190 14 6,910 7-5/8 Tieback Assy. 6.151 15 6,923 7 H563 x 4.5 Hyd 625 XO 3.850 16 14,193 4-1/2 Drillable Packoff Sub 2.390 17 14,226 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) 12 Hyd 625 13.5 7,090 3,939 7,588 3,920 92 Hyd 521 13.5 7,588 3,920 10,917 3,810 35 Hyd 521 12.6 10,917 3,810 12,414 3,761 41 DWC/C 12.6 12,414 3,761 14,144 3,697 Updated 2/20/2024 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 2.375" Pipe Ram Milne Point ASR 11 BOP w/ Jacks 05/17/2017 Milne Point ASR 11 BOP (Triple) 7/28/2025