Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
194-153
2025-0422_Surface_Abandon_MPU_E-15_ae Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4-23-2025 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector MPU E-15 Hilcorp Alaska LLC PTD 1941530; Sundry 324-717 4/22/2025: I traveled to Milne Point Unit for a surface abandonment inspection on MPU E-15. Matt Ross was the Hilcorp representative on the job. The well was cut off at 4.5 feet below tundra grade. Hard cement was found in all strings and the marker plate had all the correct information welded on. Field approval was given to weld the marker plate to the casing stub and bury. Attachments: Pictures (3) 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.06 12:41:03 -08'00' 2025-0422_Surface_Abandon_MPU_E-15_ae Page 2 of 3 Surface Abandonment – MPU E-15 (PTD 1941530) Photos by AOGCC Inspector A. Earl 4/22/2025 2025-0422_Surface_Abandon_MPU_E-15_ae Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 25 Township: 13N Range: 10E Meridian: Umiat Drilling Rig: Rig Elevation: Total Depth: 5410 ft MD Lease No.: ADL0025518 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: O.D. Shoe@ Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5391 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Retainer 3335 ft 3231 ft 7.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1670 1570 1533 IA 1661 1560 1522 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: A slick tag was performed with a 2-inch bailer. Small hard pieces of cement mixed with a clay were brought to surface. January 31, 2025 Bob Noble Well Bore Plug & Abandonment MPU E-15 Hilcorp Alaska, LLC PTD 1941530, Sundry 324-717 none Test Data: P Casing Removal: Jess Hall Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0131_Plug_Verification_MPU_E-15_bn 9 9 9 9 9 9 999 9 9 9 9 9 999 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.07 15:44:57 -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: P&A 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): 5,410'N/A Casing Collapse Conductor N/A Production 5,410psi 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 WSW 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 N/A 4,673' 4,058' 3,477' 967 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 E-15 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/15/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 194-153 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22528-00-00 Hilcorp Alaska LLC N/A Size Proposed Pools: 112' 112' 9.3# / L-80 / EUE 8rd TVD Burst 2,001' MILNE POINT UGNU UNDEF WTRSP, SCHRADER BLUFF OIL 112' 20" 7"5,391' MD N/A 7,240psi4,656'5,391' Length 7" Gravel Packer & 7" HES EZSV 3,447 MD/ 3,000 TVD & 4,872 MD/ 4,191 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 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 Todd Sidoti DN: cn=Todd Sidoti Reason: For Taylor Wellman Date: 2024.12.30 13:27:27 - 09'00' Todd Sidoti By Grace Christianson at 9:24 am, Dec 31, 2024 324-717 DSR-1/8/25 * AOGCC to witness CMIT-TXIA to 1500 psi. 24 hour notice. * AOGCC to witness slickline tag of TOC ~ 3250' MD. 24 hour notice. * AOGCC to witness top of cement in all annuli before welding marker plate. * Photo document as described. SFD 1/2/2025 10-407 MGR02JAN2025&': &':IRU-/& Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.01.09 13:33:13 -09'00'01/09/25 RBDMS JSB 011025 Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 Well Name:MPU E-15 API Number:50-029-22528-00-00 Current Status:SI WSW Rig:Coil/SL/Pumping Estimated Start Date:1/15/25 Estimated Duration:10 days Regulatory Contact:Tom Fouts Permit to Drill Number:194-153 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Taylor Wellman 907-947-9533 AFE Number:TBD Current Bottom Hole Pressure:1250 psi @ 2835’ TVD gauge data | 8.48 PPGE MPSP:967 psi Gas Column Gradient (0.1 psi/ft) Max Inclination:47° @ 3104’ MD Brief Well Summary MPU E-15 was an ESP producer in the Schrader OA and N sands. The well was originally completed in September of 1995. The well was produced with multiple ESP’s and saw declining oil rate until the final ESP failed in 2015. Due to the limited value as a production well this well was converted to a water source well for the E-Pad development. In 2023 the ESP began to show signs of deterioration, and an ESP swap was approved. During the April 2023 ESP swap, casing damage/buckling was identified @ ~285’ and only part of the ESP was recovered after getting stuck with the ESP @ 303’ and having to jar it free. The ESP components below the discharge head were LIH. The well was left with a kill string in place to a depth of 2,001’. Notes Regarding Wellbore Condition x 3 ½” Kill string was ran to 2,001’ x Casing obstruction @ ~285’ x Liner cemented to ~4,058’ TOC (confirmed w/ tag on 2/15/2019) x During original completion the 7” casing was cemented with 370 bbls of cement, with calculated cement to surface w/ 30% washout. The plug was bumped and floats held. A 26 bbl cement top job was also performed. Objective: x To perform a complete P&A of the well. Procedure Fullbore 1. Pump 150 bbls produced water to establish injectivity (FP w/ diesel as necessary). Slickline 1.D&T to top of fish w/ fullbore LIB/Blind box. ESP fish presumably fell to top of packer @ 3,447’. Coil 1.RIH w/ 3 ½” x 7” inflatable cement retainer. Set retainer ~50’ above top of fish tagged by SL in step #2 (~3,350’). 2.RIH w/ cement stinger and pump below: 3.Pump 42 bbls of 14-15.8 ppg Class G cement per pump schedule below placing TOC @ ~3250’. Cement volume based on bottom perf @ 3910’ in 7” casing with 50% excess below retainer. Lay in ~100’ of cement above cement retainer. a.5 bbls methanol Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 b. 10 bbl freshwater spacer c. Pump 42 bbls of 14-15.8 ppg Class G cement (10 bbls excess) d.After 38 bbls away, unsting and lay in ~4 bbls cement on top of retainer (~100’) e.Lay in 48 bbls of 9.8 ppg brine from 3250’ (TOC) to tubing tail @ ~2001’. f.FP tubing w/ diesel as necessary (~18 bbls) Slickline/Fullbore (Wait 3 days on cement) 1. AOGCC Witnessed CMIT-TxIA to 1500 psi 2.AOGCC Witnessed D&T (Est TOC ~3250’) Fullbore 1. Rig up to the tubing. 2.Circulate 150 bbls of seawater followed by 20 bbls of surfactant wash down tubing taking returns from the IA. 3.Pump 5 bbl freshwater spacer. 4. Mix 14-15.8 ppg Permafrost cement. 5.Pump 80 bbls of cement (16 bbls excess) down tubing taking returns from the IA to a tank until clean cement returns are observed at surface. Operations 1. Photo document all steps 2. Cut off all casings and wellhead >3’ below tundra. 3. Top off tubing and annuli with cement if needed. AOGCC to witness cement tops before grouting. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a.Hilcorp Alaska, LLC b. PTD# 194-153 c.MPE-15 d. API # - 50-029-22528-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised By: TDF 5/8/2023 SCHEMATIC Milne Point Unit Well: MP E-15 Last Completed: 4/22/2023 PTD: 194-153 TD =5,410 (MD) / TD = 4,673’(TVD) 20” Orig. RKB Elev.: 53.9’/ GL: 24.3’ Nabors 22E 7” PBTD =5,302’ (MD) / PBTD = 4,577’(TVD) 1 N Sands OA Sands 3 7” Casing Buckling at ~290’ RA Tag @ 4,835’ WLM 2 ESP Fish Left in Hole 4 TOC @ 4,058’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.4 / H-40 / PE 19.124 Surface 112' 0.355 7" Production 26 / L-80 / BTC 6.276 Surface 5,391’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface 2,001’ 0.0087 4” Tubing 14 / S-135 / HT-38 3.561 3,447’ 3,923’ N/A PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ugnu 3,775’ 3,910’ 3,250’ 3,356’ 135’ 3/6/2019 Open N Sands 4,990’ 5,028’ 4,297’ 4,331’ 38’ 9/09/95 Isolated - Cemented OA Sands 5,136’ 5,166’ 4,428’ 4,455’ 30’ 9/06/95 Isolated - Cemented Ugnu Perforations: 4-5/8”, 12spf 30/50 Degree Phasing WELL INCLINATION DETAIL KOP @ 1,000’ Max Hole Angle = 47 deg. @ 2,818’ Hole Angle Thru Perfs= 26 Deg. TREE & WELLHEAD Tree Cameron 2-9/16”5M Wellhead FMC 11” Unibore x 2-7/8” EUE 8rd (Top & Bottom) TC-3-EC Hanger w/ 2.5” ‘H’ profile. GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack – 9/13/1995 ESP Change-out w/ Nabors 4ES – 12/27/2002 ESP Change-out w/ Doyon 16 – 4/29/2011 ESP Change-out w/ Nordic #3 – 1/20/2016 Convert to WSW w/ Innovation – 3/10/2019 Install Kill String w/ ASR – 4/22/2023 OPEN HOLE / CEMENT DETAIL 20” 250sks Arcticset I in a 24” hole 7”800sks of Permafrost “E”, 300 sx Trinity Lite in a 8.5” Hole STIMULATION DETAIL Interval: 4,990’ to 5,028’ Frac w/ 44,200lbs of Carbo Lite Interval: 5,136’ to 5,166’ Frac w/ 108,000lbs of Carbo Lite JEWELRY DETAIL No Depth Item 1 1,971’ 3-1/2” Mule Shoe – Bottom @ 2,001 2 3,447’ 7” Gravel Pack Packer 3 3,674’ 0.012 ga screen w/ 3.561” ID / 247.82’ in length – Gravel Pack X-Sands, 20/40 Pro-Carb 4 4,872’ 7” HES EZSV Cmt Retainer * Note: All tubing/ESP jewelry depths based on Doyon #16 RKB 23.35’ to Tbg Hanger All sand control jewelry depths based on Nabors 22E RKB 29.6’ to GL _____________________________________________________________________________________ Revised By: TDF 5/8/2023 PROPOSED Milne Point Unit Well: MP E-15 Last Completed: 4/22/2023 PTD: 194-153 TD =5,410 (MD) / TD = 4,673’(TVD) 20” Orig. RKB Elev.: 53.9’/ GL: 24.3’ Nabors 22E 7” PBTD =5,302’ (MD) / PBTD = 4,577’(TVD) 1 N Sands OA Sands 3 7” Casing Buckling at ~290’ RA Tag @ 4,835’ WLM 2 ESP Fish Left in Hole 4 TOC @ 4,058’ MD Est TOC ±3,250’ Cement Retainer @ ±3,300’ 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.4 / H-40 / PE 19.124 Surface 112' 0.355 7" Production 26 / L-80 / BTC 6.276 Surface 5,391’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface 2,001’ 0.0087 4” Tubing 14 / S-135 / HT-38 3.561 3,447’ 3,923’ N/A PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ugnu 3,775’ 3,910’ 3,250’ 3,356’ 135’ 3/6/2019 Open N Sands 4,990’ 5,028’ 4,297’ 4,331’ 38’ 9/09/95 Isolated - Cemented OA Sands 5,136’ 5,166’ 4,428’ 4,455’ 30’ 9/06/95 Isolated - Cemented Ugnu Perforations: 4-5/8”, 12spf 30/50 Degree Phasing WELL INCLINATION DETAIL KOP @ 1,000’ Max Hole Angle = 47 deg. @ 2,818’ Hole Angle Thru Perfs= 26 Deg. TREE & WELLHEAD Tree Cameron 2-9/16”5M Wellhead FMC 11” Unibore x 2-7/8” EUE 8rd (Top & Bottom) TC-3-EC Hanger w/ 2.5” ‘H’ profile. GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack – 9/13/1995 ESP Change-out w/ Nabors 4ES – 12/27/2002 ESP Change-out w/ Doyon 16 – 4/29/2011 ESP Change-out w/ Nordic #3 – 1/20/2016 Convert to WSW w/ Innovation – 3/10/2019 Install Kill String w/ ASR – 4/22/2023 OPEN HOLE / CEMENT DETAIL 20” 250sks Arcticset I in a 24” hole 7”800sks of Permafrost “E”, 300 sx Trinity Lite in a 8.5” Hole STIMULATION DETAIL Interval: 4,990’ to 5,028’ Frac w/ 44,200lbs of Carbo Lite Interval: 5,136’ to 5,166’ Frac w/ 108,000lbs of Carbo Lite JEWELRY DETAIL No Depth Item 1 1,971’ 3-1/2” Mule Shoe – Bottom @ 2,001 2 3,447’ 7” Gravel Pack Packer 3 3,674’ 0.012 ga screen w/ 3.561” ID / 247.82’ in length – Gravel Pack X-Sands, 20/40 Pro-Carb 4 4,872’ 7” HES EZSV Cmt Retainer * Note: All tubing/ESP jewelry depths based on Doyon #16 RKB 23.35’ to Tbg Hanger All sand control jewelry depths based on Nabors 22E RKB 29.6’ to GL 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: P&A 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): 5,410'N/A Casing Collapse Conductor N/A Production 5,410psi 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 WSW 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 N/A 4,673' 4,058' 3,477' 967 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 E-15 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/15/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025518 194-153 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22528-00-00 Hilcorp Alaska LLC N/A Size Proposed Pools: 112' 112' 9.3# / L-80 / EUE 8rd TVD Burst 2,001' MILNE POINT UGNU UNDEF WTRSP, SCHRADER BLUFF OIL 112' 20" 7"5,391' MD N/A 7,240psi4,656'5,391' Length 7" Gravel Packer & 7" HES EZSV 3,447 MD/ 3,000 TVD & 4,872 MD/ 4,191 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 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 Todd Sidoti DN: cn=Todd Sidoti Reason: For Taylor Wellman Date: 2024.12.20 10:35:14 - 09'00' Todd Sidoti By Grace Christianson at 2:33 pm, Dec 20, 2024 324-716 DSR-12/20/24 SUPERSEDED REJECTED 12/23/24 Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 Well Name:MPU E-15 API Number:50-029-22528-00-00 Current Status:SI WSW Rig:Coil/SL/Pumping Estimated Start Date:1/15/25 Estimated Duration:10 days Regulatory Contact:Tom Fouts Permit to Drill Number:194-153 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Taylor Wellman 907-947-9533 AFE Number:TBD Current Bottom Hole Pressure:1250 psi @ 2835’ TVD gauge data | 8.48 PPGE MPSP:967 psi Gas Column Gradient (0.1 psi/ft) Max Inclination:47° @ 3104’ MD Brief Well Summary MPU E-15 was an ESP producer in the Schrader OA and N sands. The well was originally completed in September of 1995. The well was produced with multiple ESP’s and saw declining oil rate until the final ESP failed in 2015. Due to the limited value as a production well this well was converted to a water source well for the E-Pad development. In 2023 the ESP began to show signs of deterioration, and an ESP swap was approved. During the April 2023 ESP swap, casing damage/buckling was identified @ ~285’ and only part of the ESP was recovered after getting stuck with the ESP @ 303’ and having to jar it free. The ESP components below the discharge head were LIH. The well was left with a kill string in place to a depth of 2,001’. Notes Regarding Wellbore Condition x 3 ½” Kill string was ran to 2,001’ x Casing obstruction @ ~285’ x Liner cemented to ~4,058’ TOC (confirmed w/ tag on 2/15/2019) x During original completion the 7” casing was cemented with 370 bbls of cement, with calculated cement to surface w/ 30% washout. The plug was bumped and floats held. A 26 bbl cement top job was also performed. Objective: x To perform a complete P&A of the well. Procedure Fullbore 1. Pump 150 bbls produced water to establish injectivity (FP w/ diesel as necessary). Slickline 1. D&T to top of fish w/ fullbore LIB/Blind box. ESP fish presumably fell to top of packer @ 3,447’. Coil 1. RIH w/ 3 ½” x 7” inflatable cement retainer. Set retainer ~50’ above top of fish tagged by SL in step #2 (~3,350’). 2. RIH w/ cement stinger and pump below: 3. Pump 42 bbls of 14-15.8 ppg Class G cement per pump schedule below placing TOC @ ~3250’. Cement volume based on bottom perf @ 3910’ in 7” casing with 50% excess below retainer. Lay in ~100’ of cement above cement retainer. a. 5 bbls methanol Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 b. 10 bbl freshwater spacer c. Pump 42 bbls of 14-15.8 ppg Class G cement (10 bbls excess) d. After 38 bbls away, unsting and lay in ~4 bbls cement on top of retainer (~100’) e. Lay in 48 bbls of 9.8 ppg brine from 3250’ (TOC) to tubing tail @ ~2001’. f. FP tubing w/ diesel as necessary (~18 bbls) Slickline/Fullbore (Wait 3 days on cement) 1. AOGCC Witnessed CMIT-TxIA to 1500 psi 2. AOGCC Witnessed D&T (Est TOC ~3250’) Fullbore 1. Rig up to the tubing. 2. Circulate 150 bbls of seawater followed by 20 bbls of surfactant wash down tubing taking returns from the IA. 3. Pump 5 bbl freshwater spacer. 4. Mix 14-15.8 ppg Permafrost cement. 5. Pump 80 bbls of cement (16 bbls excess) down tubing taking returns from the IA to a tank until clean cement returns are observed at surface. Operations 1. Photo document all steps 2. Cut off all casings and wellhead >3’ below tundra. 3. Top off tubing and annuli with cement if needed. AOGCC to witness cement tops before grouting. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC b. PTD# 194-153 c. MPE-15 d. API # - 50-029-22528-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Proposed Schematic Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 Plug and Abandon Well: MPE-15 PTD: 194-153 API: 50-029-22528-00-00 Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728 MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT E-15 JBR 05/22/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Good test. Looked over their winterization well to make sure nothing would freeze up. Rig looked to be in good condition. Test Results TEST DATA Rig Rep:zgreubOperator:Hilcorp Alaska, LLC Operator Rep:Haberthur Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1941530 DATE:4/20/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopRCN230422133723 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 967 Sundry No: 323-186 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 11"P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0 none NA BOP Misc 0 none NA System Pressure P3050 Pressure After Closure P1750 200 PSI Attained P14 Full Pressure Attained P56 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2212 psi ACC Misc NA NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P6 #2 Rams P5 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 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: Install Kill String 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 5,410 feet N/A feet true vertical 4,673 feet N/A feet Effective Depth measured 4,058 feet 3,447 & 4,872 feet true vertical 3,477 feet 3,000 & 4,191 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 2,001' 1,955' 7" Gravel Packer Packers and SSSV (type, measured and true vertical depth)7" HES EZSV 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: 323-186 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WSW WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 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) 0 Gas-Mcf MD 112' 140 Size 112' 4,656' 0 1400 0 6002837 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-153 50-029-22528-00-00 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: ADL0025518 MILNE POINT / UGNU UNDEF WTRSP & SCHRADER BLUFF OIL MILNE PT UNIT E-15 Plugs Junk measured LengthCasing Conductor 5,391'Production 20" 7" 112' 5,391' 7,240psi Burst N/A Collapse N/A 5,410psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 10:07 am, May 09, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.08 16:32:58 - 08'00' Taylor Wellman (2143) MILNE PT UNIT E-15 MILNE POINT / UGNU UNDEF WTRSP & SCHRADER BLUFF OIL 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Kill String 194-153 _____________________________________________________________________________________ Revised By: TDF 5/8/2023 SCHEMATIC Milne Point Unit Well: MP E-15 Last Completed: 4/22/2023 PTD: 194-153 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 91.4 / H-40 / PE 19.124 Surface 112'0.355 7"Production 26 / L-80 / BTC 6.276 Surface 5,3910.0383 TUBING DETAIL 3-1/2Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface 2,0010.0087 4Tubing 14 / S-135 / HT-38 3.561 3,4473,923N/A PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ugnu 3,775 3,910 3,250 3,356 1353/6/2019 Open N Sands 4,990 5,028 4,297 4,331 389/09/95 Isolated - Cemented OA Sands 5,136 5,166 4,428 4,455 309/06/95 Isolated - Cemented Ugnu Perforations: 4-5/8, 12spf 30/50 Degree Phasing WELL INCLINATION DETAIL KOP @ 1,000 Max Hole Angle = 47 deg. @ 2,818 Hole Angle Thru Perfs= 26 Deg. TREE & WELLHEAD Tree Cameron 2-9/165M Wellhead FMC 11 Unibore x 2-7/8 EUE 8rd (Top & Bottom) TC-3-EC Hanger w/ 2.5 H profile. GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack 9/13/1995 ESP Change-out w/ Nabors 4ES 12/27/2002 ESP Change-out w/ Doyon 16 4/29/2011 ESP Change-out w/ Nordic #3 1/20/2016 Convert to WSW w/ Innovation 3/10/2019 Install Kill String w/ ASR 4/22/2023 OPEN HOLE / CEMENT DETAIL 20250sks Arcticset I in a 24 hole 7800sks of Permafrost E, 300 sx Trinity Lite in a 8.5 Hole STIMULATION DETAIL Interval: 4,990 to 5,028 Frac w/ 44,200lbs of Carbo Lite Interval: 5,136 to 5,166 Frac w/ 108,000lbs of Carbo Lite JEWELRY DETAIL No Depth Item 1 1,9713-1/2 Mule Shoe Bottom @ 2,001 2 3,4477 Gravel Pack Packer 3 3,6740.012 ga screen w/ 3.561 ID / 247.82 in length Gravel Pack X-Sands, 20/40 Pro-Carb 4 4,8727 HES EZSV Cmt Retainer * Note: All tubing/ESP jewelry depths based on Doyon #16 RKB 23.35 to Tbg Hanger All sand control jewelry depths based on Nabors 22E RKB 29.6 to GL Well Name Rig API Number Well Permit Number Start Date End Date MP E-15 ASR 50-029-22528-00-00 194-153 4/20/2023 4/23/2023 No operations to report. Continue RIH with kill string to 2,001'. P/U M/U landing joint. Land well, 18K up weight 12K down weight. RILDS. Rig down rig floor equipment. bleed down koomey. blow down all fluid lines. Clean and clear rig floor. rig down sheave. disconnect fluid lines. rig down spacer spools and flow spool. Suck out pits Install new service hose wrap. Rig down pipe shed. pull pipe shed out of the way. rig down catwalk and remove. Remove insulation from koomey lines. rig down glycol heater. Scrub outside of rig floor. Lay down rig floor stairs. Send loads to L-pad. Pull rack pins. Drop guy lines. Rig released. 4/22/2022 - Saturday No operations to report. 4/25/2023 - Tuesday 4/23/2023 - Sunday WELLHEAD BOP stack pulled, clean hgr void, install RX54 gasket and FMC seal sub. PU tree/adapter, land and torqued to spec. Test hgr void to 500/5000 (PASS). Pull Bpv with dry rod, all valves in correct position. 4/24/2023 - Monday 4/21/2022 - Friday Work stuck pipe @ 303'. pull up 12K over (20K). Swivel up, hook up kelly hose. Push 12K down to free on the down. Start pumping @ 3 BPM 650 psi, working pipe up to 303'. Shut down pump Continue to work pipe. Cut cable and secure to pipe with clamps. Turn pipe quarter turn at a time changing orientation. total of 3 turns. Mix lube pill and pump while working pipe up to 303'. shut down pump and continue working pipe. working pipe up to 9K over. (17K). came down, came back up and no hang up. POOH 1 joint to ensure free. Splice cable . disconnect and blow down kelly hose and lay down. POOH with 3-1/2 EUE and ESP from 303' to discharge head. ESP equipment from below discharge head was missing, full recovery of Cross collar clamps and ESP cable. + 1 protectralizer. Discuss options with OE. Call out for string mill and scrapper. decided on running Caliper log with slickline. Clean and clear rig floor. Wrap up cable into spooler. move spooler out of the way for slickline, load pipe shed with workstring. Trouble shoot Hyd pump on rig. Replace Hyd pump on rig. Spot in slickline while working on rig. R/U wireline unit, Run 3.6" gauge ring to 1000'. Run 7" caliper log to 1000' to surface. R/D wireline. Wait on caliper data analysis and discuss plan forward with engineering. Load pipe shed with pulled 3 1/2" tubing and tally same. Cut mule shoe jt. RIH with 3 1/2" kill string. 4/19/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/20/2022 - Thursday Rig accepted at 08:00 4/20/2023. Test as per approved sundry 250 low/2500 high with 3-1/2 test joint. Test witness by AOGCC Rep Bob Noble. Rig down test equipment. blow down lines. Weight up fluid in pits. Troubleshoot carriage. Hang sheave and elephant trunk. spot cap line spooler. run ropes to spooler. Troubleshoot carriage and repair same. Pull CTS and BPV, BOLDS. Install landing jt. Pull hanger to floor 39K to unseat, 35K up wt. Cut ESP cable and work over sheave. no capillary installed. Cont. to POOH with ESP completion. Rig accepted at 08:00 4/20/2023. Test as per approved sundry 250 low/2500 high with 3-1/2 test joint. Test witness by Work stuck pipe @ 303'. pull up 12K over (20K). Swivel up, hook up kelly hose. Push 12K down to free on the down. Start pumping @ 3 BPM 650 psi, working pipe up to 303'. Shut down pump Continue to work pipe. Cut cable and secure to pipe with clamps. Turn pipe quarter turn at a time changing orientation. total of 3 turns. Mix lube pill and pump while working pipe up to 303'. shut down pump and continue working pipe. working pipe up to 9K over. (17K). came down, came back up and no hang up. POOH 1 joint to ensure free. Splice cable . disconnect and blow down kelly hose and lay down. POOH with 3-1/2 EUE Continue RIH with kill string to 2,001'. P/U M/U landing joint. Land well, 18K up weight 12K down weight. RILDS. Rig down rig rig floor. Lay down rig floor stairs. Send loads to L-pad. Pull rack pins. Drop guy lines. Rig released. hang up. POOH 1 joint to ensure free. Splice cable . disconnect and blow down kelly hose and lay down. POOH with 3-1/2 EUE and ESP from 303' to discharge head. ESP equipment from below discharge head was missing, full recovery of Cross collar 10-404 MGR28MAR23 BOPE test to 2500 psi. GCW 04/05/23 04/05/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.05 12:01:36 -08'00' RBDMS JSB 040623 Lubricate BPV if risk of pressure below.mgr n 1lilcorp Alaaka, LLC Wig. RKB Elev.: 53.5/ GL: 24.3' Nabors 22E TD = 5,410 (MD) / TO= 4,673'(ND) PBTD = 5,302' (N4D) / PBTD = 4,577M) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MP E-15 Last Completed: 3/10/2019 PTD: 194-153 Tree Cameron 2-9/16"5M Wellhead FMC 11" Unibore x 2-7/8" EUE 8rd (Top & Top Bottom) TC -3 -EC Hanger w/ 2.5"'H' profile. OPEN HOLE / CEMENT DETAIL 20" 2505ks Arcticset I in a 24" hole 7„ 800sks of Permafrost "E", 300 Top 5x Trinity Lite in a 8.5" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 0.355 7" Production 26/L-80/BTC 6.276 Surface 5,391' 0.0383 TUBING DETAIL 3-1/2" Tubing 19.2 / L-80/ EUE 8rd 2.992 Surface 3,214' 0.0087 4" Tubing 14/S-135/HT-38 3.561 3,447' 3,923' 1 N/A WELL INCLINATION DETAIL KOP @ 1,000' Max Hale Angle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No Depth Item 1 3,122' XN-Nipple: MIN ID 2.750" No -Go 2 3,123' Discharge Head: B/O PMP 513 3 3,164' Pump: 44FLEX80 4 3,178' Gas Separator: GPXARCINT 5 3,179' Upper Tandem Seal: GSB3DBUTSB/SB PFSA 6 3,186' Lower Tandem Seal: GSB3DBLTSB/SB PFSA 7 3,193' Motor: XP 250-250Hp/2,505V/63A 8 3,210' Sensor: Zenith 9 3,212' 6 -fin Centralizer - Bottom @ 3,214' 10 Isolated -Cemented Gravel Pack Packer it 3,674' 0.012 ga screen w/3.561" ID/ 247.82' in length -Gravel Pack X -Sands, 20/40 Pro -Garb 12 4,872' 7" HES EZSV Cmt Retainer * Note: All tubing/ESP jewelry depths based on Doyon M36 RKB 23.35'to Tbg Hanger All sand controljewelry depths based on Nabors 22E RKB 29.6'to GL PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status ik- Ugnu 3,775' 3,910' 3,250' 3,356' 135' 3/6/2019 Open N Sands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Isolated -Cemented OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Isolated -Cemented Ugnu Perforations: 4-5/8", 12spf 30/50 Degree Phasing STIMULATION DETAIL Interval: 4,990' to 5,028' Frac w/ 44,200lbs of Carbo Lite Interval: 5,136' to 5,166' Frac w/ 108,000[bs of Carbo Lite GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack -9/13/1995 ESP Change -out w/ Nabors 4ES - 12/27/2002 ESP Change -out w/ Doyon 16 - 4/29/2011 ESP Change -out w/ Nordic #3 -1/20/2016 Convert to WSW w/ Innovation - 3/10/2019 Revised By: TDF 3/15/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP E-15 Innovation 1 50-029-22528-00-00 194-153 3/4/19 3/10/19 Daily Operations. 3/6/2019 - Wednesday Displace wellbore @ 4,072' MD w/ heated 8.6 seawater. 9.5 bpm, 1,450psi, 47% flow (430 bbls total). Chase w/ 231 bbls heated 8.5 filtered 3% KCL brine. 5 bpm, 490psi, 35% flow. Final NTU's @ 27. Monitor well (static). R/U Weatherford casing. POOH laying 2-7/8" tubing F/ 4,072'- T/ surface. Hole took proper displacement. R/D Weatherford. R/U and test 7" BTC, 26#, L-80 casing. 3,000psi w/ 30 min hold (chart and record). Test good. 2 bbls pumped, 2 bbls bled back. Install wear bushing, 6.75" ID. RILDS. Install 4" inserts in elevators. Pick up, drift (2.35") and single in the hole with 132 joints of drill pipe. POOH racking back drill pipe. PJSM. Rig up and RIH with TCP 12 SPF 25 gram 30/150 deg phasing perf guns: Bull plug, 134.6' TCP, safety spacer, firing head, ported sub. X0. to 141.62'. RIH with TCP assembly on drill pipe from 141' to 4,058' DP measurement, tag up x 2 with 3K. Mark pipe. Pick up 146.87' to put bottom shot at 3,910' top shot 3775.4' (12 SPF, 25 gram, 30/150 deg phasing, EHD 0.75"). P1SM. Break circulation. Shut pipe rams and pressure up to 3,000psi and hold for 30 seconds. Bleed pressure and open rams. Observe pipe jump and 2K bobble on wt after ^7 minutes indicating shots fired. Monitor well, flowing initial rate 22 bph. RIH and tag up at 4,039'. Perf interval 3,775.4' - 3,910'. Circulate hole 1.5 x annular volume at 3 - 4bpm/120-172psi. Observe gas breaking out at surface. Max gas 439U. 3/7/2019 - Thursday Monitor well (22 BPH initial flow the slowed to 9.5 BPH over 20 min w/ moderate amounts of gas breaking out @ surface, 8.5 ppg KCL brine. TIH and tag @ 4,033' (6' higher than previous tag). P/U and circulate STS dusting up from 8.5 to 8.6 ppg brine. Max gas @ btms up 439u. Starting seeing moderate losses w/ 8.6 1/2 way up annulus, 2-4 bpm, 100-170psi. Static loss rate w/ 8.6 in/out was 60 bph. Shut do and make final tag @ 4,028' (30' debris and fill from tag depth prior to firing guns). B/D TDS. Drop 2.375" drift on wire (stds 1-62). POOH F/ 4,028' - T/ surface racking back 62 stds and L/D perf guns. All shots fired. Drift recovered @port sub above perf guns. Continue monitoring across top of hole w/ 8.5 KCL brine. Bring tools and handling equipment for gravel pack assy to rig floor. R/U becket w/ 3.5" elevators, false table. Run 6ea 4" 9.5# screens (Bull Plug on btm 1st screen), Sea 4" blanks (tea 6" OD welded centralizers on each blank), 14ea 2.875" inner string wash pipe w/ full mule shoe on btm. M/U gravel packer assy to inner string and screen assy. 484.67' total length w/ packer running tool. TIH w/ drifted 4" drill pipe out of derrick F/ 484'- T/ 4,018'. tag up with 3K down. 60 fpm running speed. Easy on/off slips. Static loss rate slowed to 22 BPH. 84K up, 71Kdn. Rig down elevators and bails. Rig up to long bails. Reverse circulate to ensure no pipe dope in DP. Pick up and put packer on depth at 3446.81. screens at 3,674.48'- 3.922.3'. Drop 1.44" OD brass setting ball. PJSM. Rig up hard line, manifold and choke. Flood lines and PT 500/5,000psi - good. Set packer. Pressure up in 500psi increments and hold for 1-3 minutes, pressure up to 3300psi. Bleed pressure. Pick up 20K over, slack off 20K. Pressure up to 3,300psi and hold for 1 minute, bring pressure up to 3500psi and hold for 5 minutes. Bleed off pressure. Line up and PT packer, pressure up to 1,000psi on backside and hold for 10 min - good test. Continue pressuring up and observe rupture disk shear at 2,650psi. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-15 Innovation 50-029-22528-00-00 194-153 3/4/19 3/10/19 Daily Operations. 3/8/2019 - Friday Psi up several times from 4780psi staging up to 6000psi to blow ball seat. S/O to block wt (33k on string wt), P/U to neutral wt. Close annular and apply 500psi backside. P/U and establish reverse circ position. PJSM w/ HES and Supreme svcs, wet lines w/ 60/40 Methanol. P/T lines 5000 (test good). Establish circ, pump 5 bbls acid, 15 bbls 3% KCL brine, 15 bbls 60/40. 2.7 bpm, 1660psi. Lineup and reverse circulate pickle out of pipe taking returns to flowback tank until PH reached 6.5. Divert and take returns back to pits. Observed 2 leaking gland nuts on wellhead during acid 'lob. Shut down circulating and C troubleshoot leaks. Backed LDS for wear bushing and re -tightened gland nuts. Tested good. Continue with gravel pack operations. Set do 35k putting pkr in compression and gravel pack postion. Establish injection rates w/ a max flow rate of 6 bpm, 805 tbg, 206 csg. Hard shut down and monitorpsi's, stabilize @ 225 tbg / 83 csg. Begin Gravel Pack. Pump a total of 9600# w 5 bbls left of flush before sanding out. 5 bpm avg pump rate w/ 560psi tbg, 106psi csg and +/- 20% returns. Once sandout observed we shut do and bled off tbg. Shut annular w/ reduce bagpsi (800psi).psi up on annulus T/ 700psi and stripped up to reverse circulate position. Ended up having to strip up 2' higher than previously marked to establish good circulation reversing. Reverse circulated @ 5 bpm, 335 until returns were clean of sand. B/D manifold and lines. B/O and L/D same. Pull 10 stds racking back in derrick to clear washpipe from packer assy. Saw 30k bobbles while pulling out. Pulled clean @ 81k up, 74k dn. C/O long bails to short bails and install hydraulic 4" elevators. 13 bph static losses. POOH laying down drill pipe. Change out pipe handling equipment to 2-7/8". L/D service tool and 2-7/8" tubing. 32 bbls lost during trip. Pull wear bushing. Spot ESP spooler, and load ESP cable. Rig up handling equipment. Rig up weatherford. Bring Centrilift equipment to rig floor. Bring 135 cannon clamps to rig floor. Hang sheave in derrick. Install snake on ESP cable and pull through sheave. Inspect and measure all handling equipment. R/U safety valve. PJSM. Pick up ESP assembly, Centrilizer, Zenith sensor, tandem seals, intake, pump and discharge head. Fill motor with oil and service tandem seals. Attach cable, install 2 flatguard clamps, 4 neck seal clamps. Meg cable - good. Continue to RIH with 3-1/2" ESP assembly as per detail to 487', PUW/SOW 47K. 3/9/2019 -Saturday Continue RIH w/ ESP on 3.S" EUE 8rd, L-80 tbg F/ 487' - T/ 967' MD. 7-9 bph static loss rate. Test cable @ 967' (test failed). Prepare to POOH. POOH racking back 3.5" tubing in derrick F/ 967'- T/ surface. No damage to ESP cable observed during trip out. Test mtr (test failed). Test cable (test good). B/O and L/D ESP assy. Centrilift left to build another ESP for replacement. Perform rig maintenance while waiting for new ESP motor. Centrilift on location @ 14:00 hrs. Load new ESP equipment in shed. P/U and M/U ESP 5.65" diameter centralizer, Zenith sensor, XP motor w/ upper tandem seal. M/U intake, 44FLEX80 pump w/ 513 discharge head. Wire ESP to cable and test fail. Perform rig maintenance, inventory parts and supplies, work on hitch paper work while waiting for new ESP motor. Static loss rate 6 bph. Pull ESP cable to rig floor. Cut off motor lead and splice new motor lead. L/D bad motor and pick up new motor. Prime with oil and test - good. Install ESP wire to motor and test - good. RIH 1 stand to get motor lead and splice into fluid and test again - good. Static loss rate 6 bph. RIH with 3-1/2" ESP completion out of the derrick to 965'. Test motor - good. Continue to RIH picking up tubing from shed to 3187'testing motor every 1,000'. PUW 64K, SOW 57K. Loss rate 2-3 bph. Make up hanger and landing joint. Terminate ESP and splice to penetrator. 103 jts 3-1/2" 9.3# L-80 EUE tubing ran. 4 neck clamps and 2 flat guard on ESP assembly, 57 Canon Clamps used. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-15 Innovation 50-029-22528-00-00 194-153 3/4/19 3/10/19 Daily Operations. 3/10/2019 -Sunday Finish terminating ESP cable to penetrator, Install in tbg hanger. RIH and landout with a final tbg depth of 3214' MD. 64k up, 57k do (22k string wt on hanger). B/O and L/D landing jt. Install BPV. R/D Centrilift ESP sheaves and equipment from derrick. R/D weatherford casing tongs. Remove equipment from floor. Begin N/D BOP equipment. Observe BPV bleeding by fluid. Pull and re -seat BPV (no leak). Continue N/D BOP equipment. Remove 4 point chains, N/D choke, kill, riser. Bleed down and isolate koomey. Stage new wellhead tree in cellar. Break stack from wellhead. N/D BOPE and sapcer spool. Test ESP penetrator - good. Nipple up tree. Test tubing void 500psi/5 min, 5,000psi/15 minute - good. Pull BPV, set TWC and test tree 500/5,000psi - good. Pull TWC, set BPV. 3/11/2019 - Monday No activity to report. 3/12/2019 -Tuesday No activity to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-15 Permit to Drill Number: 194-153 Sundry Number: 319-073 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o o g c c .a T a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner, DATED this � day of February, 2019. RBDMS -t�' MAR 0 5 2019 K Hilswp Alaska. LU Convert to WSW Well: MPU E-15 Date: 02/12/2019 Well Name: MPU E-15 API Number: 50-029-22528-00 Current Status: SI - ESP Prodcuer Pad: MP E -Pad Estimated Start Date: February 27, 2019 Rig: Innovation Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-153 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type; Convert to WSW Current Bottom Hole Pressure: 1,664 psi @ 4,000' TVDss (Last BHP measured 9/04/2015, 8.0 ppg) Maximum Expected BHP: 1,664 psi @ 4,000' TVDss (Last BHP measured 9/04/2015, 8.0 ppg) MPSP: 1,264 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU E-15 is an ESP producer in the Schrader OA and N sands. The well was originally completed in September of 1995. The well was produced with multiple ESP's and saw declining oil rate until the final ESP failed in 2015. Due to the limited value as a production well this well is proposed to be converted to a water source well for the E -Pad development and longer horizontal Schrader Bluff injector/producer pairs. Notes Regarding Wellbore Condition • Deviation down to gravel pack (max angle 47.25° @ 2,818'). • Casing last tested to 2,150 psi for 30 min down to -4,100' on 1/25/2019. • Well is isolated from any hydrocarbon zone with cement retainer at 4,872' and and -772' and of cement on top of the retainer.c su A) 09-L, 3f8 - S YJ Objective: Convert the well to a 3-1/2" Water Source Well in the Lower or Upper Prince Creek sand by perforating and performing a gravel pack before completing with an ESP. i Brief RWO Procedure: Pre -Rig Procedure: 1. MIRU slickline. Pressure test PCE to 250psi low/ 2,500 psi high. 2. Drift & tag TOC. Log GR/CCL up from TOC. RD Slickline unit. 3. Clear and level pad area in front of well. Spot rig mats and containment. 4. RD well house and flowlines. Clear and level area around well. WO Rig Procedure: 5. MIRU Innovation 6. Check for pressure and if needed, bleed off any residual pressure off tubing and casing. If needed, circulate well w/±8.5ppg seawater. 7. Set BPV. ND tree / NU BOPE. Set TWC. 8. Test BOPE to 250 psi Low/ 3,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per Innovation BOPE Test Procedure. Convert to WSW Well: MPU E-15 Hikorp Alaska, LU Date: 02/12/2019 b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4" DP and 2-7/8" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 9. Contingency: (If the tubing hanger won't pressure test due to either a control line leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 10. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Circulate out freeze protect from the well w/±8.5ppg seawater to returns tank. Confirm well has zero pressure. 11. MU 2-7/8" landing joint or spear and BOLDS. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 2 12. POOH and lay down the 2-7/8" kill string from 2,306' md. L There are 73 full joints of 2-7/8" in the kill string. / 13. PU 4" drill pipe and MU TCP BHA w/±137' of 4-5/8", 12spf, RDX guns. 14. TIH and tag TOC. PU to place guns at: 3,773'-3,910' md. '\ a. Correlation to be based off of the GR/CCL off of the TOC performed in pre-rig step #2. 15. Pressure up on drill pipe to initiate firing guns. a. Approximate firing delay of 6 minutes from the time pressure is reached to guns firing. b. Well should go on slight vac when guns are fired. 16. Monitor pressures and circulate well to 8.6ppg brine if needed. 17. TIH to tag bottom. Note difference between previous tag and now. a. This differential (pert derbis/influx of solids) will be used in calculating space out for screens on the next run. 18. Contingency - If well goes onto extreme vac and high losses are experienced, pump a K -Max pill to allow for future circulating to happen. 19. TOOH and lay down the TCP assembly. 20. P/U gravel pack assembly on 4"work string. n Hik,arp Alaska, LG Convert to WSW Well: MPU E-15 Date:02/12/2019 a. ±326 ft of 3-'/:" Petroguard 0.020 gauge screen. Inspect screen prior to RIH for general weld quality, box and pin threads, centralizers (OD and condition), and base pipe drift ID. Screens to be set from ±3,710'— ±3,950' MD. b. ±5 joints' of 4-'/:" Blank pipe NU box x pin. c. Gravel Pack Packer set @ -3,450' MD d. ±13 joints of 2-7/8", 6.4#, P-110 wash pipe (length as required). e. Halliburton setting tool. 21. Run the gravel pack assembly into the well slowly (max running speed of 60 fpm). 22. TIH to —1 stand above the top of the perforations at ±3,773' md. Reverse circulate to clear potential pipe dope from the work string. a. Max pump rate of 2BPM. At rates below this, you can't wash out or damage the gravel pack assembly. 23. TIH to tag the TOC. Use the TOC taken post perforating to account for perf debris/fill. PU hole to position the gravel pack assembly and upper packer above the perforations. a. Hold neutral weight for setting the packer. 24. Drop the 1.44" brass setting ball. Pump as needed to get ball on seat. Once on seat, increase pressure nJ in 500psi increments up to ±3,276psi. Hold final pressure for 3 minutes. a. Packer should begin to set at ±814psi and fully set at ±3,276psi. b. Adjust setting steps as per Halliburton Gravel Pack Supervisor. c. Contingency— If ball seat blows early. L Consult Halliburton Gravel Pack Supervisor about dropping 2.125" aluminum ball. 25. Bleed off the workstring pressure to Opsi. Pressure test the IA to 1,OOOpsi for 10 minutes (chart). 26. Pressure the IA to ±2,500psi to shear the rupture disk and bleed to Opsi. 27. Pressure the workstring to ±4,OOOpsi to shear release from the packer. PU on the workstring to verify released. a. There is a secondary release by overpulling 20k lbs. 28. PU above the reverse position and blow out the ball seat down the workstring at ±4,764psi. 29. Set down the service tool and set down 50k lbs. PU to string weight and apply 500psi on the IA. Strip up until pressure is observed on the workstring. Mark this position as the Reverse position. 30. Circulate tubing pickle down the workstring. a. ±5 bbls of 15%HCI to be used. 31. Reverse circulate out the tubing pickle acid to flowback tank. 32. Perform circulation test down the workstring while taking returns from the IA at the following rates: 0.5, 1.0, 1.5 and 2.0 bpm. 33. Contingency — If K -Max pill was pumped. a. Circulate ±15bbls of 15% HCI down the workstring while taking returns from the IA. n b. When the acid is 500' above the MCS sleeve, slow pumps. When acid make it to the tel`sleeve, shut in the IA and for into the K -Max pill to dissolve. 34. Set down into the circulating/gravel packing position and perform gravel pack with ±1� f 20/40 Pro -Ceramic. $ a. Volume of annular space below circulation point = 17.9bbls Convert to WSW Well: MPU E-15 Mkw1' Alaska, LIJ Date: 02/12/2019 b. Approximate proppant volume= 17.9 bbls x 599 Ib/bbl = 10,722lbs 35. PU on the workstring into the "Reverse" position. Reverse out slurry at max rate until clean returns are observed. a. Minimum volume to circulate is x2 BU. 36. PU slowly and monitor for shifting close of the MCS closing sleeve. Continue to POOH and LD all setting assembly. 37. PU new ESP with single cap string and RIH on 3-1/2" tubing. Set base of ESP assembly at ± 3,200' MD. a. 3-1/2" tubing b. 3-1/2" XN (2.725" No -Go) �S c. 1 joint of 3-1/2" tubing d. Downhole gauge e. Base of ESP centralizer @ ± 3,200' MD 38. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 39. Set BPV. 40. NO BOPE. NU 3-1/8" 5,000# tree/adapter flange. Pull BPV. Set TWC. Test tree to 500 psi low/5,000 psi high. Test tubing hanger void to 500 psi low/5,000 psi high. Pull TWC. 41. Replace gauge(s) if removed. 42. Rig down Innovation. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic (Prince Creek) 3. BOPE Schematic 4. Blank RWO MOC Form n mm Alaska. LLC Ong. RKB Bev.: 53.9"/ GL: 24.3' Nabors 22E 20' TOC@4,0Nmd. Tag W SL 2/11/2019 RA Tag @4,835 vtA. 1 i % _ _ _ .—.jj To= 5,410 (MID) / TD= 4,673'(TVD) PBTD= 5,302' (MD) / PBTD=4,577'(TVD) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MP E-15 Last Completed: 1/24/2019 PTD: 194-153 Tree Cameron 2-9/16"SM Wellhead FMC 11" Unibore x 2-7/8" EUE 8rd (Top & Top TBiTwEl Bottom) TC -3 -EC Hanger w/ 2.5"'H' profile. OPEN HOLE / CEMENT DETAIL 20" 25Osks Arcticset I in a 24" hole 7„ 800sks of Permafrost "E", 300 Top TBiTwEl sx Trinity Lite in a 8.5" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top TBiTwEl 7" HES EZSV Cm[ Retainer Date 20" Conductor 91.4 / H-40 / PE 19.124 Surface 112' 1 0.355 7" Production 1 26/L-80/BTC 6.276 Surface 5,391' 1 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE8rd 2.441 Surface 2,306' 0.00579 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle = 47 deg. @ 2,818' () Hole Angle Thru Perfs= 26 Deg. 5� JEWELRY DETAIL r JIM 2,1cp I�Lt I )°I No Depth Item 1 4,872' 7" HES EZSV Cm[ Retainer PERFORATION DETAIL Sands I Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date I Status NSands 1 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 1 Isolated - Cemented OASands 1 5,136' I 5,166' 4,428' I 4,455' 30' 9/06/95 1 Isolated - Cemented STIMULATION DETAIL Interval: 4,990' to 5,028' Frac w/ 44,200lbs of Carbo Lite Interval: 5,136'to 5,166' Frac w/ 308,000lbs of Carbo Lite GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack -9/13/1995 ESP Change -out w/ Nabors 4ES —12/27/2002 ESP Change -out w/ Doyon 16-4/29/2011 ESP Change -out w/ Nordic #3 —1/20/2016 De -complete w/ ASR —1/24/2019 Revised By: TDF 2/13/2019 K cora AlaxAa. LLC Orig. RKB Elev.: 53.9'/ GL 24.3' Nabors 22E 20" MN la 2250 @±3,Wn s&6 10 5 3�� 3 ,A, 3� PROPOSED TREE & WELLHEAD Milne Point Unit Well: MP E-15 Last Completed: 1/24/2019 PTD: 194-153 Tree Cameron 2-9/16"5M Wellhead FMC 11" Unibore x 2-7/8" EUE 8rd (Top & 7„ Bottom) TC -3 -EC Hanger w/ 2.5"'H' profile. OPEN HOLE/ CEMENT DETAIL 20" 250sks Arcticset I in a 24" hole Wt/Grade/Conn 800sks of Permafrost "E", 300 7„ 5x Trinity Lite in a 8.5" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 0.355 7" Production 26/L-80/BTC 6.276 Surface 5,391' 0.0383 TUBING DETAIL 3-1/2" Tubin 9.2/ L-80/ E U E 8rd 2.992 Surface ±3,200' 0.0087 4" Tubing 9.5/ L-80/ EUE 8rd 2.548 ±3,710' ±3,950' 0.0122 WELL INCLINATION DETAIL 00' KOP @ 1,0 Max Hole Angle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No LO Depth Item 1 ± XN-Nipple: MIN ID 2.250" No -Go 2 ± Discharge Head: 3 ± Pump: 4 ± Gas Separator: 5 ± Upper Tandem Seal: 6 ± Lower Tandem Seal: 7 ± Motor: 8 ± Sensor: 9 ± 6 fin Centralizer— Bottom @±3,200' 10 ±3,450' 7" Gravel Pack Packer 11 ±3,710' 0.020 ga screen w/X.XX" ID — XX.XX' in length — Gravel Pack X -Sands, 20/40 Pro -Garb * NO Aft tubing/ESP jewelry depths based on Doyon #16 RKB 23.35' to Tbg Hanger All san d control jewelry depths based on Nabors 22E RKB 29.6'to GL RA Tag @4,835 V,LM ---4F To = 5,410 (ND) / TD= 4,673(f V 'D) PM=5,302' (ND)/PBTD=4,577 VD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Fr Date Status Ugnu ±3,773' ±3,910' ±3,248' ±3,356' 300' Future Future NSands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Isolated - Cemented OASands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Isolated - Cemented Ugnu Perforations: 4-1/2", 12spf STIMULATION DETAIL Interval: 4,990' to 5,028' Frac w/ 44,20016s of Carbo Lite Interval: 5,136' to 5,166' Frac w/ 108,000lbs of Carbo Lite GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack -9/13/1995 ESP Change -out w/ Nabors 4ES —12/27/2002 ESP Change -out w/ Doyon 16-4/29/2011 ESP Change -out w/ Nordic #3 —1/20/2016 Revised By: TTW 2/13/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 1/05/2018 311 or Pipe Rams ind es HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: February 15th, 2019 Subject: Changes to Approved Sundry Procedure for Well MPU E-15 Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. HAK Step Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received 10.rson and Date Approval: Prepared: Operations Manager Date Operations Engineer Date RECEIVED FEB 2 0 2019 STATE OF ALASKA 1 _ U I �t / ALASKA OIL AND GAS CONSERVATION COMMISSION K� A OMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: pit ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 2MAG25.105 2MAC26.110 GINJ ❑ WINJ ❑ WAGE) WDSPL❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or Hilcorp Alaska, LLC Abend.: 11242019 tb. Well Class: Devieopment Exploratory ❑ Service ❑ Stratigmphic Test ❑ 14. Permit to Drill Number I Sundry: • 194 -153/318 -SM 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage AK 99503 7. Date Spudded: 5/16/1995 15. API Number: 50-029-22528-00-00 - 4a, Location of Well (Governmental Section): Surface: 1715' FNL, 1899' FEL, Sec 25, T13N, R10E, UM, AK Top of Productive Interval: 2257' FNL, 1352' FWL, Sec 25, T13N, R10E, UM, AK Total Depth: 2308' FNL, 1178' FWL, Sec 25, T13N, R10E, UM, AK 6. Date TO Reached: 15. 521/1995 Well Name and Number: MILNE PT UNIT SB E-15 9. Ref Elevations: KB: 53.9 17. GL:24.15 I BR Field / Pool(s): MILNE POINT/ SCHRADER BLUFF OIL 10. Plug Back Depth MD/TVD: 18. 5,302'. 4,577- Property Designation: AUL0025518 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569247.0893 y-6016102.614. Zone -4- TPI: x- 567224.4007 y- 6015542.324 Zone -4 Total Depth: x- 567050.0363 y- 8015489.195 Zone -4 11. Total Depth MD/TVD: 19. . 6,410114,673- • DNR Approval Number: NIA 12. SSSV Depth MDITVD: 20. WA Thickness of Permahast MD/TVD: 1,800' Approx. / 1,774' Approx. 5. Directional or Inclination Survey: Yes (attached) No E Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 21. WA (fl MSL) I Re-drill/Lateral Top Window MDRVD: 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 it necessary ci c 23. CASING, LINER AND CEMENTING RECORD AMOUNT CASING WF. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD FT GRADE TOP BOTTOM 70P BOTTOM PULLED 20" 91A H40 32' 112' 32' 112' 24" 250sx Arcticset 1 Approx. 7" 26 L-80 30' 5,391' 30' 5,391' 8-12° 800sx PF "E"1300sx Trinity Lt 24. Open to production or Injection? Yes ❑ No 0 If Yes, list each Interval open (MD/TVD of Top and Bottom; Perforation Sita Number; Date Perfd): 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MIand 2-7/8" 2 31W 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Per 20 AAC 25,283 Q)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27• PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Dale of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oft Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl; Gas -MCF: Water -Bbl: Oil Gravity -API (torr): Form 10-407 Revised 52017 CONTINUED ON PAGE 2 R13DMS Nh FEB 2 12919 Subrait ORIGINAL only _ 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑ If yes, list intervals and formations tested, briefly summarizing test results. Top Scrader Bluff 4,963' 4,219' N Sands 4,991' 4,244' Attach separate pages to this form, if needed, and submit detailed test OA Sands 5,137' 4,374' information, including reports, per 20 AAC 25.071. Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic & daily operations. 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: Chad Helgeson Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman hilCof .Com Authorized Contact Phone: 777-8449 Signature: Date: 2/15/2019 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only ..; 0.11, _. ��nu0"VE STATE OF ALASKA FEBI )' ALASKA OII ANT) r.AR ('.ON5dFR\/ATInN CnKAKAIQCInK1 Ef '1 20=0 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 2] 1b. Well Class: 20AAC 25.05 20AAC est to Suspended Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 1/24/2019 14. Permit to Drill Number / Sundry: 194-153 / 318-584 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 7. Date Spudded: 5/16/1995 15. API Number: 50-029-22528-00-00 4a. Location of Well (Governmental Section): Surface: Top of Productive Interval: Total Depth: 8. Date TO Reached: 5/21/1995 16. Well Name and Number: MILNE PT UNIT SB E-15 9. Ref Elevations: KB: 53.9 GL: BF: 17. Field / Pool(s): MILNE POINT / SCHRADER BLUFF OIL 10. Plug Back Depth MD/TVD: 5,302' . 4,577' 18. Property Designation: ADL0025618 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569247.0893 y- 6016102.614 Zone- TPI: x- 567050.0363 y- 6015489.195 Zone- Total Depth: x- 567226.009 y- 6015541.685 Zone- 11. Total Depth MDfTVD: 5,410' / 4,673' 19. DNR Approval bar: N/A 12. SSSV Depth MDITVD: N/A 20. Thicknof Permafrost MD/TVD: 1, 'Approx. / 1,774' Approx. 5. Directional or Inclination Survey: Yes LJ (attached) No ❑✓ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore:-drill/Lateral N/A (ft MSL) 21. Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic ata and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but ar not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, ce ant evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 1- �f_ 23. CASING, LINER AND C ENTING RECORD AMOUNT WT. PER SETTING DEPTH MD SETTIN DEPTH TVD HOLE SIZE CEMENTING RECORD CASING FT GRADE TOP BOTTOM TO BOTTOM PULLED 20" 91.4 H-40 32' 112' A, 112' 24" 250sx Arcticset I Approx. 7" 26 L-80 30' 5,391' 30' 5,391' 8-1/2" 800sx PF "E"/300sx Trinity Lt 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom erforation Size and Number; Date Perfd): 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2-7/8" 2,306' 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: 5/17/1996 Method of Operation (Flowing, gas lift, etc.): ES Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Top Scrader Bluff 4,963' 4,219' N Sands 4,991' 4,244' Attach separate pages to this form, if needed, and submit detailed test OA Sands 5,137' 4,374' information, including reports, per 20 AAC 25.071. sG��1..�' Formation at total depth: >"- 31. List of Attachments: 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: Chad Helgeson Contact Name: Taylor Wellman Authorized itla: Operations Manager Contact Email: twellman hi1C0r .00M Authorized Contact Phone: 777-8449 Signature: �'.:�.-,� H C „ Date: 2/13/2019 INSTRUCTIONS Genera . 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 1a: 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 5/2017 Submit ORIGINAL Only K HilrnrP Alaeke. LLC Orip, RKB Eley.: 53.9'/ GL 24.3' Nabors 22E P141 PA Tag 04.ai5 Whi 0111111111,111111i N S2-tls { i DA Smdn 7" j ,'', TD = 5,410 (MD) / TD= 4,673'(TVD) PBTD = 5,302' (MD) / PBTD= 4,577'(1V0) Milne Point Unit Well: MP E-15 SCHEMATIC Last Completed: 1/24/2019 PTD: 194-153 TREE & WELLHEAD OPEN HOLE/ CEMENT DETAIL 20" Tree Cameron 2-9/16"5M 800sks of Permafrost "E", 300 Top Wellhead FMC 11" Unibore x 2-7/8" EUE 8rd (Top & 20" Conductor 1 91.4/H-40/PE Bottom) TC -3 -EC Hanger w/ 2.5"'H' profile. Surface OPEN HOLE/ CEMENT DETAIL 20" 250sks Arcticset I in a 24" hole 7„ 800sks of Permafrost "E", 300 Top sx Trinity Lite in a 8.5" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 1 91.4/H-40/PE 19.124 Surface 112' 0.355 7" Production1 26/L-80/BTC 6.276 Surface 5,391' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 1 2.441 Surface 1 ±2,306 1 0.00579 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No Depth Item 1 1 4,872' 1 7" HES EZSV Cmt Retainer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date I Status NSands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Isolated - Cemented OASands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 1Isolated-Cemented STIMULATION DETAIL Interval: 4,990' to 5,028' Frac w/ 44,200lbs of Carbo Lite Interval: 5,136' to 5,166' Frac w/ 108,0001bs of Carbo Li[e GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack — 9/13/1995 ESP Change -out w/ Nabors 4ES —12/27/2002 ESP Change -out w/ Doyon 16 — 4/29/2011 ESP Change -out w/ Nordic #3 —1/20/2016 De -complete W/ ASR —1/24/2019 Revised By: TDF 2/13/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-15 ASR 50-029-22528-00-00 194-153 1/17/2019 1/25/2019 Daily Operations. 1/16/2019- Wednesday No activity to report. 1/17/2019 -Thursday Circulate 290 bbls 8.3 ppg Produced Water with Barraclean to clean and kill well. SIWP-130psi at conclusion of pumping. Calculated KW brine = 8.9ppg. Order 200 bbls 9.1 ppg brine from I-rig Baroid rep. Stand by for delivery of brine. Circulate 200 bbls 9.1 ppg NaCl brine @ 3 bpm and well on vacuum. SI well and stand for ASR to MIRU. ASR MIRU equipment. 1/18/2019 - Friday Cont. Move eq. from F-pad to E-pad, check well on vac. set well house, N/D tree, prep wellhead, check lift threads with sub good, install blanking sub, N/U BOPE, spot rig eq. raise mast, R/U floor, run surface lines & winterize same, Function test BOPE good. Check eq. & line temps good, fill lines & stack with test fluid, m/u test jt. 1/19/2019-Saturday Cont. work on shell test troubleshooting & repairing as needed till good, 250 low 3000 high. Test BOPE as per Hilcorp & AOGCC requirements, AOGCC witness waived by AOGCC inspector Bob Noble @ 16:49 on 1-17-19. Tested with 2-7/8" & 3- 1/2" test R's 250 low/ 3,000 high good. Blow down surface lines & r/d test eq. Prep to Pull ESP assy, hang sheaves c/o handling eq. Unload test fluids from pits & load with 9.1 brine. P/U retrieval tool for blanking sub, pull blanking sub and lay down, P/U 3.5" landing joint, swap elevators, pull BPV, back out lock down screws and POOH w/ hanger. Pulled free at 45K and pulling weight @44K, lay down hanger. Pump 6 bbls 9.1 brine down back side to load hole, found fluid level @ 154' , make up spooling lines onto power cable, start POOH . Heat trace cable pulled apart at splice and necessary to re-tie off to spooler. Continue POOH spooling control lines removing clamps, and laying down. Pumping double displacement every 15 joints. (2 bbls). Continue POOH t/2,704' laying down 2-7/8" tubing, pumping double displacement every 15 joints (2bbls) up wt 25k, do wt 18k. 1/20/2019-Sunday Cont. POOH I/d 2 7/8" tubing to esp assy, observed cable damage @ jt 145 & 150 (4,579'& 4,761') Had build up of scale on tubing. L/D ESP assy, had scale on outside of housing >1/8",. Clean & clear floor, c/o handling tools. P/U BHA- 6" bit, 7" scraper, bit sub =6.46. RIH w/ 6" bit and 7" casing scraper on 3.5" 9.5# work-string RIH to 4,916'. POOH w/ 6" bit and 7" scraper on 3.5" 9.5# work-string laying down. Swap out 3.5" work-string with 2-7/8" 6.5# L-80 EUE 8rnd tubing , swap out lifting gear, slips, tally tubing , prep to RIH w/ HES cement retainer. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MP E-15 ASR 50-029-22528-00-00 194-153 1/17/2019 1 1/25/2019 Daily Operations. 1/21/2019 - Monday Cont. Prep & P/U cmt retainer- HES EZSVB Cement Retainer 2.63, HES Mechanical Setting tool 4.45, X -over 3.5" IF pin to 2- 7/8 EUE Box = 8.51'. TIH p/u 2-7/8" EUE L 80 6.5# tubing, t/ 2,526'. R/U & break circulation (took 9bbls) @ 2613M 66psi, blow down lines. Cont. RIH w/retainer/ 4,880', up wt 28k, do wt 16k. R/U & break circulation 26PM, 66psi, took 5 bbls to fill,. Set retainer as per Halliburton hand setting @ 4,872', shearing out at 72k, sting back in & set 16k down. R/U & test annulus t/2,000psi, pump 1.5 bpm, pressure up t/ 1800, & leveled off, no returns up tubing, s/d pressure @ 1,200 & bled off t/1,000 in 1 min, check surface eq. good, attempt pressure up @ 1 bpm started leveled off at 1,200psi, cont. troubleshoot, fill tubing on losses inconclusive. cont. troubleshoot, un -sting from retainer, pressure up on annulus with same results. Consult with engineer for forward plan, blow down lines. Decision made to P/U and run test packer to find hole in casing. RDMO Cementers, Water truck, and associated equipment, prep to POOH with retainer running tool. Wait while electrician /mechanic work on electrical short on ASR rig. Start POOH w/ 2-7/8" 6.5# L-80 tubing, w/ retainer running tool. Laying Down. Break Out and lay down HES Retainer running tool. Swap elevators, slips, and handling equipment, move in 3.5" work string and prep to RIH. P/U 7" test packer & tih p/u 3-1/2" wk string t/1,726' up wt 16k, do wt 13k. 1/22/2019 -Tuesday Cont. TIH p/u 3-1/2" wk string t/4,103', set test packer. Test annulus t/surface, 2,000psi f/30 min good. Bleed down & blow down, release packer unable to move down hole, trouble shoot & re -sequence attempt to get in running position with no luck. POOH, found "1 pin assy sheared from mandrel. L/D 7" test packer, p/u 7" replacement packer. Tih w/ new 7" test packer p/u 3 1/2" wk string. Continue RIH w/ 7" test packer and 3.5" work -string to 4,500' and set packer. Pressure up on backside above test packer set @ 4,500' to 2,200psi. Monitor pressure and test casing at 4,500' for good test- 30 minutes. Test recorded on chart. Bleed off pressure blow down lines and prep to RIH w/ test packer to 4,740'. RIH w/ test packer to 4,740' and set packer. Pressure up on backside above test packer to 2,150psi. Monitor and chart for 30 minute test for good test. Bleed off pressure and prepare to pump down tubing to test casing below packer and above retainer. Start pumping down tubing with packer set @ 4,740', pressure up to 1,500psi pumping 2.0 bpm with significant pressure falling off, shut down pump and pressure fall to 500psi in 2 minutes, pressure back up to 1,300psi pumping in at 2bpm steady injection rate. SO pumping and pressure @ 416psi in 2 minutes and falling. Bleed off pressure and blow down lines, prep to POOH w/ test packer. POOH w/ 3.5" work -string and 7" test packer. L/D test packer, c/o handling eq. P/U cmt stinger w/xo= 5.64'. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-15 AS 50-029-22528-00-00 194-153 1/17/2019 1/25/2019 Daily Operations. 1/23/2019- Wednesday TIH w/ cmt stinger p/u 2-7/8" eue 8rd 6.5# L-80 tubing t/4,847', up wt 26k, do wt 17k. Sting into rtainer @ 4,872', r/u check inj rates, 500psi @ 1 BPM, 1,000psi @ 2BPM, 1,550psi @ 3bpm,. Housekeeping & rig maint. while waiting on cementers. Continue rig maintenance and wait on cementers. Cement pump truck on location, R/U cement pumper, walk down lines, stand by for cement lad analysis. prep job to pressure test and pump cement. Received Code Blue on radio. Suspend operations. Stand by for ok to restart. Start pumping @ 2bpm with 5 bbls FW lead @ 840psi. Increase rate to 3bpm @ 1,240psi. Start pumping cement @ 2-3bpm rate varying due to mixing and pump 25bbls 15.8 ppg Class G cement and swap to FW flush. Pump 3 bbls flush at 2 bpm with pressure 840psi and cement below retainer. Keep pumping flush @ 2 bpm with pressure climbing to 3,200psi at 8bbls cement below retainer. Tubing started getting light. Shut down pumping. Pull up 10' and sting out of retainer and spot 17bbls remaining cement on top of retainer- ETOC @ 4,427' . Pull 17 joints to put stinger @ 4362'. Spot 10bbl cement balanced plug from 4,362' to 4100' and pull tubing to 4,000'. Clean up tubing pump Ing 25 bbls long way and 84 bbls reverse for clean returns. RDMO cementers. Last pump time on cement 0200 hours. POOH with 2-7/8" tubing laying down. Continue cleaning up cementers and excess cement. Cont. POOH w/2-7/8" t/1,230'. 1/24/2019 -Thursday Service Rig, Cont. POOH I/d cmt stinger. TIH w 2-7/8" EUE 8 rd, 6.5# L-80 tubing t/4,006' up wt 20k, do wt 14k. Shut in well while waiting on CMT, work on prepping rig for move to F-107. R/U & test cmt t/ 2,000psi for 30 min Test show slight fall in pressure . Decision to circulate and POOH with tubing to allow cement to harden longer. Mix and circulate 40 bbl pill of Caustic Soda, 40 bbl pill Baraclean, and 40 bbl viscous pill, and circulate hole clean with 290 bbis F/W. Complete circulation, blow down lines, start hauling off circulated returns, prep to POOH. POOH w/ 2-7/8" 6.5# L-80 EUE tubing laying down. Lay down 56 joints leaving 73 joints 2-7/8" tubing in well for kill string. Prep to pressure test cement and casing. Pressure test cement and casing to 2,150psi for 30 minutes, charted test, for GOOD TEST, Bleed off pressure off casing , blow down lines . Pick up hanger, run and land hanger placing tubing tail @ 2,306', Lay down landing joint. BPV INSTALLED. Begin RDMO ASR. 1/25/2019 - Friday Cont. R/D e.q & move to F-107, Freeze protect well w/LRS, pump 80 bbls diesel filling tubing & annulus/2 tubing tail, N/d BOPE & N/U tree test void 250psi 5min 5,000psi 15 min. good, Pull BPV & secure wellhead, pull well -house & turn well over to production. 1/26/2019 -Saturday No activity to report. 1/27/2019 -Sunday No activity to report. 1/28/2019 - Monday No activity to report. 1/29/2019 -Tuesday No activity to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-15 Permit to Drill Number: 194-153 Sundry Number: 318-584 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276 7542 www.aogcc.ajaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Q3'_/ l Hollis S. French Chair 4L DATED this 6' day of January, 2019. RBDMS- JAN 0 91019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 V / 7-1 % / i 07-s- 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ tr 5�/.M Q • Perforate ❑ Other Stimulate ❑ Pull Tubing ❑d ' Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: De -complete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑r Stratigraphic ❑ Service ❑ 194-153 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22528-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑Q MILNE PT UNIT E-15 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025518 MILNE POINT/ SCHRADER BLUFF OIL ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,410' 4,673' 5,283' 4,560' 1,264 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 5,391' 7" 5,391' 4,656' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (li Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5#/ L-80/ EUE 8rd 4793 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES VTL (2) & HES BWD Sump and N/A 4,918(MD)/ 4,232(TVD), 5,041 (MD)/ 4,343'(TVD) & 5,171'(MD)/ 4,4591 and N/A 12. Attachments: Proposal Summary ,x Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Z Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/1/2018 OIL ❑ WINJ ❑ WDSPL ❑ uspendad GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative:S p GINJ ❑ Op Shutdown ❑ Water Source " 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York Contact Name: Taylor Wellman Authorized Title: Pperlations Manager Contact Email: twellman hilcor .Com � I' LL Contact Phone: 777-8449 Authorized Signatu v i�7�ete: 12/31/208 COMMISSION USE ONLY Conditions of appriva Notify Commission so that a representative may witness Sundry Number: `C/ LV Plug Integrity ❑ BOP Test R( Mechanical Integrity Test ❑ Location Clearance ❑ Other: k31 n��/r P 5 Post Initial Injection MIT Req'd? JYeNo ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: L APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: es! 1 q 1 /\% RBDMS JAN 9ppg ORIGINAL \/ 1 Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. /- y- l7 Submit Form and Attachments in Duplicate i, -r//9 U Hilwrp Alaska, LG Convert to WSW Well: MPU E-15 Date: 12/21/2018 Well Name: MPU E-15 API Number: 50-029-22528-00 Current Status: SI — ESP Producer Pad: MP Estimated Start Date: February 1, 2019 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-153 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Job Type: Convert to WSW Current Bottom Hole Pressure: 1,664 psi @ 4,000' TVDss (Last BHP measured 9/04/2015, 8.0 ppg) / Maximum Expected BHP: 1,664 psi @ 4,000' TVDss (Last BHP measured 9/04/2015, 8.0 ppg) MPSP: 1,264 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU E-15 is an ESP producer in the Schrader OA and N sands. The well was originally completed in September of 1995. The well was produced with multiple ESP's and saw declining oil rate until the final ESP failed in 2015. Due to the limited value as a production well this well is proposed to be converted to a water source well for OLSP the E -Pad development and longer horizontal Schrader Bluff injector/producer paairs.I C'. wr Co:. yfoA vct,o• �1aof dc��'aq® t?I Notes Regarding Wellbore Condition rN IOPA brl/� �'e, Pro d-UjATc'/yq/ 00-0/70- "4015• Deviation down to gravel pack (max angle 47.25° @ 2,818'). Prry 1to 9f 1-4e• Casing'last tested to 1,500 psi for 30 min down to 4,880'o4/29/2011. 4/29/2011. • Well has a history of scale production. ; A Jetf7,A0 [4illilk&fp eAO%l/;AlkI4 Obiedive: �� � Plugback the existing Schrader Bluff comple ion and cony rt the well to a 3--1/2" Water Source Well in the Lower or Upper Prince Creek sand by perforating and performing a gravel pack with an ESP completion. Brief RWO Procedure: Pre -Rig Procedure: 1. MIRU slickline. Pressure test PCE to 250psi low/ 2,500 psi high. 2. Drift obtain SBHP survey. RD slickline unit. 3. Clear and level pad area in front of well. Spot rig mats and containment. 4. RD well house and flowlines. Clear and level area around well. 5. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 6. Pressure test lines to 2,500 psi. VK -Iv ' 7. Circulate at least one wellbore volume with 8.5ppg seawater down tubing, taking returns up casing to 500 bbl returns tank. --7 8. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 9. RD Little Red Services and reverse out skid. 10. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. Convert to WSW Well: MPU E-15 Hilm" Alaska, W Date: 12/21/2018 11. NU BOPE house. Spot mud boat. WO Rig Procedure: ^5 V 12. MIRU ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 13. Check for pressure and if needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/± 8.5ppg seawater. Adjust brine weight as needed depending upon fluid loss. Pull BPV. Set TWC. 14. Test BOPE to 250 psi Low/ 3,500 psi High annular to 250 psi Low/ 2.500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4" DP and 2-7/8" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Contingency: (If the tubing hanger won't pressure test due to either a control line leak or the BPV ofile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking �,�✓}` anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 16. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/+ 8.5 as needed. 17. MU 4-1/2" landing joint or spear and BOLDS. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Note that during the 12/22/15 completion the PUW=80k. 18. POOH and lav down the 2-7/8" ESP completion. a. There is heat trace from surface —3,000' md. b. There are the following clamps in the completion: L 5' dual channel clamps= 474 ii. 2' dual channel clamps= 96 U Mlcary Alaska, LG iii. Pump clamps = 3 iv. Flat guards = 2 v. Protectolizers = 4 vi. SS bands = 3 Convert to WSW Well: MPU E-15 Date:12/21/2018 19. Send all ESP components to Baker to determine if anything can be salvaged. 20. RIH w/ 7", 26# scraper BHA to 4,900' and (just above the HESL VTL packer). 21. MU & RIH w/ 7", 26# cement retainter BHA to 4,875' md. Set retainer_ Pressure test the backside to 2,OOOpsi. 22. Test injectivity into the reservoir. Pick up out of retainer. 23. Begin mixing cement. Once up to weight pump ±ZSbbl6 of 15.8ppg class G cement down the drillpipe. With 4bbls of cement left in the drillpipe, PU out of the retainer and allow the last 2bbls of cement to lay in on top of the retainer. a. Estimated TOC at 4,771' md. 24. PU to 4,700' and and circulate until clean returns are observed. 25. Mix and pump the following cleaning pills (— 20 bbl per pill) while reciprocating pipe: a. Filtered heated seawater. b. Caustic soda. c. Baraklean. d. Hi -vis polymer. e. Filtered heated seawater. f. Repeat pills as needed to clean up returns (measure NTUs in returns). 26. POOH and WOC to gain compressive strength prior to performing pressure test of the 7" casing to j' 2,OOOpsi for 30min (charted). G 27. PU and run a 2-7/8" kill string to ±2,250' md. Land tubing and circulate freeze protect into the well. a. Approximate volume of freeze protect = 92bbls. 28. Land tubing in hanger. RILDS. Lay down landing joint. 29. Set BPV. Test tubing hanger to 250/5,000 psi thru test port. 30. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post -Rig Procedure: 31. RD mud boat. RD BOPE house. Move to next well location. 32. RU crane. Pull BPV. Set TWC. ND BOPE. 33. NU 2-9/16" dry hole 5,000# tree. Test tree to 250/2,500 psi. Pull TWC. RD crane. 34. Move 500 bbl returns tank and rig mats to next well location. 35. Replace IA& OA pressure gauges if removed. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form I K - Ililrnru Alaeke. LLC Orig. RKB Elev.: 53.9'/ GL: 24.3' Nabors 22E 2D' HeatTrace@a 3,om 2 MN ID=2.250 @4,741' 5..- 3 4 5 6 7&8 9 N Sands 04 Saws 1 RA Tag @4,815 tnLN1 12 13 14 15 17 Top d Fill TD = 5,410 (MD) / TD = 4,673'MO) PBTD = 5,302' (MD) / PBTD=4,57Y(TVD) Milne Point Unit Well: MP E-15 SCHEMATIC Last Completed: 12/22/2015 PTD: 194-153 TREE & WELLHEAD Tree Cameron 2-9/16"5M 7„ FMC 11" Unibore x 2-7/8" EUE 8rd (Top Wellhead & Bottom) TC -3 -EC Hanger w/2.5''H' BPF porfile OPEN HOLE / CEMENT DETAIL 20" 250sks Arcticset I in a 24" hole 7„ 800sks of Permafrost "E", 300 Top sx Trinity Lite in a 8.5" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 0.355 7" Production 26 / L-80 / BTC 6.276 Surfa 4,766' I0.0353 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80/ EUE 8rd 2.441 Surface 4,793' 0.00579 3/8" li Capstring Stainless Steel N/A Surface 4,793' N/A WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No Depth Item 1 198' GLM STA #2: w/ DG LV - I D= 2.50" (Set on 12/30/18)(1"BK) 2 4,600' GLM STA #1: ***EMPTY*-* w/ DV - ID=2.5" (Pulled on 12/30/18) (1" BK) 3 4,741' XN-Nipple: MIN ID 2.250" No -Go 4 4,752' Discharge Head: FPDIS 5 4,753' Pump: SXD 124-P4 6 4,766' Gas Separator: GRS FER N AR 7 4,769' Upper Tandem Seal: GSB3DBUT-SB/SB PFSA 8 4,776' Lower Tandem Seal: GSB3DBUT-SB/SB PFSA 9 4,782' Motor: CL5-MSP3-200 10 4,789' Sensor: Phoenix XT150 11 4,791 6 -fin Centralizer - Bottom @ 4,793' 12 4,918' HES V L Packer 13 4,984' 20 ga screen w/ 2.99" ID -54.57' in length -Gravel Pack N -Sands, 16/20 Carbolite 14 5,041' HESXN-Nipple (2.750" ID) 15 5,041' HES VTL Packer 16 5,128' 20 ga screen w/ 2.99" ID -43.49' in length -Gravel Pack OA -Sands, 16/20 Carbolite 17 5,171' HESBWDSump Packerw/4"ID -Note: All tubing/ESP Jewelry depths based on Doyon #16 RKB 23.35'to fig Hanger All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL PERFORATION DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status N Sands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Frac Pack, 12 spf OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack, 12 spf STIMULATION DETAIL Interval: 4,990' to 5,028' Frac w/ 44,200lbs of Carbo Lite Interval: 5,136! to 5,166' Frac w/ 108,000lbs of Carbo Lite GENERAL WELL INFO API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack -9/13/1995 ESP Change -out w/ Nabors 4ES-12/27/2002 ESP Change -out w/ Doyon 16-4/29/2011 ESP Change -out w/ Nordic #3 -1/20/2016 Revised By: JCM 12/30/2018 K Hilcorp Alaska, LLC Decomplete - PROPOSED Orig. RKB Elev.: 53.9'/ GL: 24.3' Nabors 22E ail Est TOC @ 4,771' and PA Tag @@4,835 v"LM N Sar,ds {; :-j �x OA Sands { TREE & WELLHEAD Milne Point Unit Well: MP E-15 Last Completed: 12/22/2015 PTD: 194-153 Tree Cameron 2-9/16"5M Wellhead FMC 11" Unibore x 2-7/8" EUE 8rd (Top & 7„ Bottom) TC -3 -EC Hanger w/ 2.5"'H' profile. OPEN HOLE / CEMENT DETAIL 20" 250sks Arcticset I in a 24" hole Type 800sks of Permafrost "E", 300 7„ sx Trinity Lite in a 8.5" Hole CASING DETAIL TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE8rd 2.441 Surface ±2,550 0.00579 �/ S�/t-�� WELL INCLINATION DETAIL KOP@ 1,0An001 Max Hole gle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No Size Type Wt/Grade/Conn ID Top Btm BPF 4 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 0.355 8 7" Production 26 / L-80 / BTC 6.276 Surface 5,391' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE8rd 2.441 Surface ±2,550 0.00579 �/ S�/t-�� WELL INCLINATION DETAIL KOP@ 1,0An001 Max Hole gle = 47 deg. @ 2,818' Hole Angle Thru Perfs= 26 Deg. JEWELRY DETAIL No Depth Item 1 ±4,875' 7" HES EZSV Cmt Retainer 2 ± 3 ± 4 ± 5 t 6 ± 7 t 8 ± 9 t 10 ± 11 ± 12 ± 13 ± 14 ± 15 ± 16 ± 17 ± * Note: All tubing/ESP jewelry depths based on Doyon #16 RKB 23.35'to Thy Hanger All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NSands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Isolated - Cemented OASands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Isolated - Cemented �11- STIMULATION DETAIL Interval: 4,9901 to 5,028' Frac w/ 44,200lbs of Carbo Lite t. Interval: 5,136' to 5,166' Frac w/ 108,000Ibs of Carbo Lite GENERAL WELL INFO TD = 5,410 (IVD) / TD = 4,673'UVD) PBTD = 5,302' (MD) / PBTD = 4,577'MO) API: 50-029-22528-00-00 Drill Nabors 22E/ Nabors 4ES Frak Pack -9/13/1995 ESP Change -out w/ Nabors 4ES —12/27/2002 ESP Change -out w/ Doyon 16 — 4/29/2011 ESP Change -out w/ Nordic #3 —1/20/2016 Revised By: TTW 12/28/2018 H 11" BOPE Milne Point ASR Rig 1 BOPE 2018 Updated 5/14/2018 311 or Pipe Rams ind es UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: December 31, 2018 Subject: Changes to Approved Sundry Procedure for Well MPU E-15 Sundry #: Pending Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date HAK Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Asset Team Operations Manager Prepared: Taylor Wellman Date First Call Operations Engineer Date 12-31-18 AF m d 7 U 100,000 10,000 1,000 100 10 1 Jan -1995 HILCORP ALASKA LLC, MILNE PT UNIT E-15 (194-153) MILNE POINT, SCHRADER BLFF OIL Monthly Production Rates Jan -2000 Jan -2005 Jan -2010 Jan -2015 100,000 10,000 1,000 100 10 1 Jan -2020 SPREADSHEET_Prod-I nject_Curves_W a II_V 117_1941530_MP U_E-15_20190104.xlsx 1/4/2019 STATE OF ALASKA ALI"OIL AND GAS CONSERVATION COMMON • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill El arforate New Pool ❑ Repair Well ❑Q Re-enter Susp Well❑ Other: ESP Change-out 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 194-153 3.Address: Stratigraphic❑ Service El 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22528-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025518 MILNE PT UNIT SB RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL JAN 2 1 2016 11.Present Well Condition Summary: I . Gefe Total Depth measured 5,410 feet Plugs measured N/A feet true vertical 4,673 feet Junk measured N/A feet Effective Depth measured 4,918,5,171 & p 5,283 feet Packer measured feet 4,232,4,343& true vertical 4,560 feet true vertical 4,459 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 5,391' 7" 5,391' 4,656' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic f ¢.E r' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,793' 4,120' HES VTL&(2) Packers and SSSV(type,measured and true vertical depth) HES BWD Sump N/A See"Packer"above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 300 0 Subsequent to operation: 0 0 0 60 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-693 ' Contact Stan Porhola Email sporhola(c�hilcorp.com Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 1/20/2016 RBDMS 0- JAN L 2 2016 ,4/��� Form 10-404 Revised 5/2015 /-- r'76 Submit Original Only Milne Point Unit III 0 Well: MP E-15 • 4 SCHEMATIC Last Completed: Proposed y Hilrorp Alaska,LLCPTD: 194-153 TREE&WELLHEAD Orig.RKB Elev.:53.9'/GL:24.3'Nabors 22E Tree Cameron 2-9/16"5M FMC 11"Unibore x 2-7/8"EUE 8rd(Top Wellhead &Bottom)TC-3-EC Hanger w/2.5"'H' porfile 2a OPEN HOLE/CEMENT DETAIL 1 20" 250sks Arcticset I in a 24"hole 7„ 800sks of Permafrost"E",300 sx Trinity Lite in a 8.5"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 0.355 7" Production 26/L-80/BTC 6.276 Surface 5,391' 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 4,793' 0.00579 g� 3/8" Capstring Stainless Steel N/A Surface 4,793' N/A 4--"."-.. WELL INCLINATION DETAIL KOP @ 1,000' Heat Trace @ Max Hole Angle=47 deg.@ 2,818' 3,00' Hole Angle Thru Perfs=26 Deg. JEWELRY DETAIL :A No Depth Item 2 1 198' GLM STA#2:w/Orifice-ID=2.50" MIN1I: 2.250" ,,,„ / ;. 2 4,600' GLM STA#1:GLM w/DV-ID=2.5" @4,741' 3 4,741' XN-Nipple: MIN ID 2.250"No-Go et t )3 4 4,752' Discharge Head: FPDIS 4 4, 5 4,753' Pump:SXD 124-P4 p° ...v6 4,766' Gas Separator:GRS FER N AR ,4.. MEW i) ,' 4 7 4,769' Upper Tandem Seal:GSB3DBUT-SB/SB PFSA 8 4,776' Lower Tandem Seal:G563DBUT-SB/SB PFSA 5 9 4,782' Motor:CL5-MSP3-200 l' . 10 4,789' Sensor:Phoenix XT150 hill{ _ 6 11 4,791 6-fin Centralizer-Bottom @ 4,7'93 I m 7&8 12 4,918' HES VTL Packer a` ' 13 4,984' 20 ga screen w/2.99"ID-54.57'in length-Gravel Pack N-Sands,16/20 Carbolite 14 5,041' HES XN-Nipple(2.750"ID) %, 9 15 5,041' HES VTL Packer 16 5,128' 20 ga screen w/2.99"ID-43.49'in length-Gravel Pack OA-Sands,16/20 Carbolite 10 1 17 5,171' HES BWD Sump Packer w/4"ID Np0� ` *Note:All tubing/ESP jewelry depths based on Doyon#16 RKB 23.35'to Tbg Hanger L' 11 All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL eyw � RATag ' @ 4,835' _ M PERFORATION DETAIL i Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status i,*........ ►. * 12 y,, N Sands 4,990' 5,028' 4,297 4,331' 38' 9/09/95 Frac Pack,12 spf w' OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack,12 spf NSands{ _' STIMULATION DETAIL Interval:4,990'to 5,028'Frac w/44,200Ibs of .i C'►�i 'a+ 15 Carbo Lite 1s a Interval:5,136'to 5,166'Frac w/108,000Ibs OASaids aof Carbo Lite t", „„ . •_. 17 GENERAL WELL INFO Top of Fill API:50-029-22528-00-00 "5' ' Drill Nabors 22E/Nabors 4ES Frak Pack-9/13/1995 7'tift t. - ESP Change-out w/Nabors 4ES-12/27/2002 TD=5,410(MD)/TD=4,67T(TVD) ESP Change out w/Doyon 16-4/29/2011 PBTD=5,302'(MD)/PBTD=4,577'(WD) ESP Change-out w/Nordic#3-1/20/2016 Revised By:TDF 1/20/2016 • • Hilcorp Alaska LLC Hilcorp Alaska,LLC Weekly Operations Summary Well Name Rig / API Number Well Permit Number Start Date End Date MPE-15 Nordic 3 d 50-029-22528-00-00 194-153 12/16/2015 12/22/2015 ` e I �saa �^�;uy w �r i r; Ali U ( iii�iMu iii 12/16/15-1 lednesday . n�N rltlrt�i��6i6 mnsi�k� „ nA=,�lm�l� � i ft i - i Pull rig off MPU K-30. Cleanup around K-30. Mobilize rig to E-pad. Spot rig over E-15. Pad operator and DSM witness spotting rig over well. Rig accepted @ 20:30 hrs.R/U on MPU E-15. PJSM. R/U kill tank hard line and cellar lines. Spot cuttings box. Berm cellar in. Offload 290 bbls 140 deg 8.5 ppg seawater in pits. R/U lubricator. Pull BPV. Tbg 350 psi,annulus 300 psi. Finish R/U cellar lines.Hold pre well kill spud meeting. Test lines to 2,500 psi. Bleed tbg and annulus to 0 psi,all gas. Move Nordic camp from K-pad to E-pad. Reverse circulate. Pump 8.5 ppg 120 deg seawater 2 bpm 470 psi. See oil returns in 3 bbls. 40 bbls away increase to 3 bpm 580 psi. Pressure slowly increasing up to 1,000 psi. Thick oil returns. Slow pump to 2 bpm 900 psi leveling off @ 1,000 psi.102 bbls away pressure decreasing to 600 psi.Increase pump to 3 bpm 780 psi.140 bbls away pressure stabilized @ 450 psi.200 bbls away start seeing traces of seawater. Continue to pump until clean 8.5 ppg returns. 450 FCP. 312 bbls total pumped. 308 bbls returned. Blow down hardline. Monitor well for 30 minutes. Static,well is dead. No losses during well kill. Blow down and R/D circ lines in cellar. Set TWC per wellhead rep. N/D tree and adaptor flange. Check hanger threads 2 7/8 EUE 8.5 turns. N/U BOPE. 12/14/15 Thursday EAk i'p9� j iAAa` N/U BOPs. Change lower pipe rams to 2 7/8 Solid.Test BOPS&all required components T/250/3,000 psi. Test Lower rams,VBRs&Annular on 2 7/8 Test joint.Test Witness waived by Brian Bixby with the AOGCC. Perform Accumulator Draw down. Good. 3,000 psi starting 1,850 after shut in. 18 sec 200 psi increase,94 sec full pressure. 4 btl N2 @ 1,980 psi. R/D testing equipment. Blow down all lines. Pull TWC monitor well static. PJSM M/U landing joint. B.O.L.D.S. Pull hanger off seat @ 85K. Circ oil cap off well while changing out ESP sheave in the derrick. Circ clean @ 5 bpm 730 psi 1.5 hole volumes. Well still dirty. Not cleaning up. Drain stack. Pull hanger to the rig floor. Terminate esp cable&Heat trace @ hanger. L/D Hanger. Pull pipe stringing cables over sheaves to ESP spooler on the ground. POH with ESP completion from 4,777'to 2,076'removing 6 dual channel clamps per jt. Spool heat trace and ESP cable. L/D jewelry. Inspect and rack 2 7/8 EUE tbg in derrick. SLM same. Continue POH with ESP completion from 2,076'to pump. Remove total 3,450'heat trace.49 stds in derrick. L/D 2 singles(149 jts total).Note:correct hole fill on trip out.L/D ESP pump assembly per centrilift. Drain oil from motor,upper and lower seals. Disconnect MLE. L/D pump assembly from mousehole. Note:upper seal contaminated with water and crude oil. Pump shaft turns freely but feels gritty turning. 12/18/15-FridaY = ;; '�'i''''''i;'s'�''w�k'w_ kl']h l'Iti Clean and clear floor. Count clamps. All clamps acounted for+20. Spool up esp cable and secure spooling unit. Set wear bushing. ID 8-13/16". M/U Mule shoe. 7"casing scraper,boot baskets and RIH. L/D 3 badly pitted joints. RIH T/4,832'.Picked up 10 new joints to tag. Tag @ 4,832'. Wash down @ 7 bpm 1,540 psi.2-3 Klb WOB. Getting fine sand back @ btm up. Wash down F/4,832'T/4,927'Pipe measurement. Pump 20 bbl high vis sweep. Brought back 0 increase in sand.Total sand recovered estimated 3.5 bbl. No losses during trip.Shut down.Monitor well. Slight flow. L/D 2 joints. Still flowing. Circ 1/2 btm up to balance well.Pull 3 stands. Monitor well for 30 min. Well flowing @ 10 BPH. RIH 3 stands T/4870'. Circ btm up @ 5 bpm 750 psi. Gained 6 bbls. Max gas 550u. Monitor well. Gaining to TT 1st bbl in 6 min. 2nd bbl in 5 min. 3rd bbls 8 min. 4th bbls in 7 min. Continue to monitor for 1 hr. Well flowing @ 9 bph. Close annular. Bullhead 5.75 bbls down tubing @ 1 bpm. 760 psi start,880 psi final. Pressure stabilized @ 70 psi on tbg. Bleed off thru choke 3/4 bbl bled back. Monitor well for 5 min flowing 7.5 bph. Circulate 1 hole volume. Pump 7 bpm @ 1490 psi. No losses or gains. Max gas 445u. Monitor well @ trip tank and record. Continues flowing 9 bph. Shut in well. Monitor tbg and casing pressure. Both stabilized @ 67 psi in 15 minutes. Continue to monitor shut in pressures while weighting up pits 3 and 4 from 8.5 ppg to 9 ppg with OF salt. Bleed off pressure thru choke. Open annular. Pump 9 ppg fluid around @ 3 bpm 290 psi. BU 447u gas. Pump 198 bbls seeing 9 ppg fluid in/out FCP 320 psi.240 bbls away increase to 4 bpm 570 psi. Pump total of 353 bbls with 0 losses and no gain. BGG 20u. Shut down pump. Monitor well on trip tank for 30 minutes. Well taking approx 1.5 to 2 bph. Get new SPR. Under balanced flowing out tbg pump 20 bbl 0.2#over dry job. POH from 4,870'to 4,589'racking 3 stands 2 7/8"tubing in derrick. Continue POH LID tubing from 4,589'to 4,252'. • • Hilcorp Alaska LLC Hileorp Alaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-15 Nordic 3 50-029-22528-00-00 194-153 12/16/2015 12/22/2015 12/19/15'1 Saturday . -, - - ' ��n�������� � POOH L/D 2 7/8"EUE tubing F/4589'T/BHA. L/D BHA. Clean boot baskets. Found small metal with part of pin threads. 3.2 bbl over calculated displacement while L/D DP. Pull wear bushing. Drain stack. Set test plug. R/U to test BOPs. Test BOPs as required for shutting in the well as per AOGCC. Test Annular,Choke valve 2,5,6&HCR. Kill to 250/3,000 psi. Test witnessed by Jeff Jones with AOGCC. All test good. Test PVT. Good. R/D testing equipment. Blow down lines. Pull test plug. Set Wear bushing. P/U 7" Halliburton champ packer. P/U 2 7/8 EUE tubing T/4911'.P/U 65K S/O 63K. Note:2.9 bbls under calculated displacement on trip in. M/U XO FOSV and top drive. Set packer @ 4,909'per HES rep. Close annular. Test 7"casing. Pump 1 bbl, pressure up to 1,500 psi. Note:packing gland nut dripping fluid,bleed off pressure. Attempt test again to 1,500 psi pumping 1 bbl. Bled off 250 psi in 2 min and continues to bleed off. Verify no surface leaks or tubing communication. Bleed off pressure. Open annular, release packer,let element relax. CBU 4 bpm 400 psi.Seen small amount of fine sand @ shaker. Note:7 bbl losses while circulating. Set packer @ 4,901'. Test 7"casing. Close annular. Pump 1 bbl and pressure up casing to 1,500 psi for 30 minutes. Charted good test. Bleed off 1 bbl. Open annular. Release packer let elements relax. Set packer @ 4,909'again and attempt to retest. Close annular. Pressure to 1,500 psi. Bled off 250 psi in 2 minutes and continue dropping. Bled off. Open annular. Release packer,let elements relax. Flowcheck well. Static loss rate 1.5 bph.LID XO and FOSV. POH with packer from 4,909'. L/D 17 jts 2 7/8"tubing. Rack 47 stds tbg in derrick. L/D packer,load out packer. Note:0.8 bbl over calculated displacement on trip out. R/U 2 1/16"handling equipment. M/U 2 1/16"mule shoe,14jts 2 1/16"CSH, 2 XOs=431.68'. Swap to 2 7/8"handling equipment.RIH with 2 7/8 tbg from derrick to 1,200'. RIH with 2 7/8 x 2 1/16 tapered string F/1,200' T/4,805'. Wash down on singles @ 8 bpm 2000 psi 9.0 Brine F/4805'T/5089. Started getting lbbl+ per min losses at the btm of the first set of perfs 5,028'. Solid sand. Using a kelly joint making conections 30 off btm. RIH with no pump to verify tag up sand. Fluid dropping 10'in the stack on connections. Wash down F/5,089'T/5,145'. Tag hard 2K. Attempt several times. No Go. Getting frac beads mixed with sand back. Max gas back @ 5,085'825 Units. Circ clean @ 8.5 bpm 2,500 psi. 3 btm up. Clean. Losing 60 bph while circulating. Displace to 8.5 Seawater @ 6 bpm. Shut down. Monitor well. Out of balance. Flowing out the tubing. Dropping in the annulus. Let well balance out. Well losing 5 Bph. POOH F/5,145'T/400'. Swap to 2 1/16"handling equip. L/D 2 XOs 14 jts 2 1/16"CSH and mule shoe. Note:18.6 bbls over calculated displacement on trip out. K/O 2 1/6"CSH and tools. Load hanger in pipeshed. Pull wear bushing. R/U handling equipment to run ESP completion. Monitor well with trip tank 4.5 bph static loss rate. PJSM with rig crew. Centrilift,DSM and TP for running ESP completion. M/U ESP pump assembly,service same. M/U and test cap string string cable thru sheave. M/U MLE. Install flat guard and protectolizer. Test ESP cable. M/U XN Nipple. Continue to monitor well with trip tank 4.5 bph static loss rate. RIH with ESP assembly with 2 7/8"6.5#L-80 EUE 8rd tubing with 3/8"cap line and ESP cable. Install cable and cap line clamps as necessary. RIH to 177' M/U GLM#1 with dummy valve. Continue to RIH @ 1,786'. M/U heat trace. Continue RIH @ 2,037'. Use trip tank for continuous hole fill running ESP completion. ry� m„- ? lir rq __ _ � y '_ 122/23.11*MOr Ieil #? av z 3.1,01 II _ ,0111k,, RIH with ESP assembly with 2 7/8"6.5#L-80 EUE 8rd tubing with 3/8"cap line. ESP cable and heat trace RIH from 2,307'to 3,170'. Use trip tank for continuous hole fill running ESP completion. Noticed damaged armor on ESP cable. Call out Centrilift supervisor. Make splice in armor on cable. Test Cable. Good. Re-rig cable through beaver slide with shackles and adjust. Good. RIH with ESP assembly with 2 7/8"6.5#L-80 EUE 8rd tubing with 3/8" cap line. ESP cable and heat trace RIH F/3,170'T/4,579'. M/U GLM#2. Run last std to 4,761'(ran 150 JTS 2 7/8"tbg total). Use trip tank for continuous hole fill running ESP completion. Well took 69.3 bbls on trip in the hole. M/U Pup hanger and landing jt. P/U 80k S/O 75k.(Note:35k top drive wt included)M/U ESP cable and heat trace penetrators on hanger. Terminate 3/8"cap line and pressure test same to 2,000 psi. Meg test ESP and heat trace cables. Splice ESP and heat trace cables. Install lower plugs for penetrators. M/U cables to hanger. Meg test same. Note:(5'dual channel clamps= 474) (2'dual channel clamps=96)(2'cannon clamps=33)(SS bands=3)(2'heat trace clamps=3)(pump clamps=2)(flat guards=2)protectolizers= 4)Drain stack,land hanger 27.2'in @ 7939.19'. RILDS per wellhead rep. L/D landing jt. Install TWC. R/U swizzle stick. Jet and suck out stack. Note: AOGCC� Rep Guy Cook waived witness for next BOP test on MPU E-19 @ 18:01 hrs on 12-21-2015. iiV222 Tue0ay i!r1 :;4111 til 17-474:40:04, yeti 1 Ii illi Continue to flush stack w/stack washing tool. RD same&suck out stack. ND BOPE and stand back same. NU Cameron 2 9/16"5M Tree. Test void&tree using diesel to 250 psi low 5000 psi high on chart. RD test equipment. Blow down lines. Prep rig to move off MP E-15.**NOTE:Released rig from MP E- 15 at 15:30 hrs. P 573 Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Saturday, December 19, 2015 3:52 PM ���4 (2,11016 To: Regg,James B (DOA) � Subject: RE: E-15 Clean out update. Jim, I told Sloan the same thing and since I was in Kuparuk for MIT's, I witnessed tests of the annular, kill HCR, CMV's 2,5,6 and the PVT's on the way back to D.H. and all passed. Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc: 907-659-2714 SCANNED Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: Regg, James B (DOA) Sent: Saturday, December 19, 2015 10:31 AM To: Sloan Sunderland; DOA AOGCC Prudhoe Bay; Schwartz, Guy L(DOA) Subject: RE: E-15 Clean out update. Thanks for the detailed description. What was used to close in the well? Did not see any reference to testing used BOPE - all used components - prior to reentry. Sent from my Samsung Galaxy smartphone. Original message From: Sloan Sunderland <ssunderland(a,hilcorp.corn> Date: 12/19/2015 6:34 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(aalaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay(&,,alaska.gov>, "Schwartz, Guy L (DOA)" <guy.schwartz cz,alaska.gov> Cc: Ted Kramer<tkramer@hilcorp.com>, Bo York<byork@hilcorp.com>, Alaska NS - Milne - Field Foreman <AlaskaNS-Milne-FieldForeman@hilcorp.com>, Paul Mazzolini <pmazzolini@hilcorp.com>, Paul Chan <pchan@hilcorp.com> Subject: E-15 Clean out update. 1 • S Regg, James B (DOA) From: Sloan Sunderland <ssunderland@hilcorp.com> Sent: Saturday, December 19, 2015 10:38 AM To: Regg,James B (DOA) Cc: Jones,Jeffery B (DOA);Ted Kramer; Paul Mazzolini Subject: RE: E-15 Clean out update. We closed in the annular against choke valves#2,5 &6. Kill HCR. We have been in contact with Jeff Jones on witnessing the BOP test. We are currently setting the test plug to test above described components. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Saturday, December 19, 2015 10:31 AM To: Sloan Sunderland; DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: E-15 Clean out update. Thanks for the detailed description. What was used to close in the well? Did not see any reference to testing used BOPE - all used components - prior to reentry. Sent from my Samsung Galaxy smartphone. Original message From: Sloan Sunderland <ssunderland@hilcorp.com> Date: 12/19/2015 6:34 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>, "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov> Cc: Ted Kramer<tkramer@hilcorp.com>, Bo York <byork(ahilcorp.com>, Alaska NS - Milne - Field Foreman <AlaskaNS-Milne-FieldForeman@hilcorp.com>, Paul Mazzolini <pmazzolini@hilcorp.com>, Paul Chan <pchan@hilcorp.com> Subject: E-15 Clean out update. After RIH with 7" casing scraper we tagged fill @ 4832'. We washed &Cleaned out sand down to the top of the packer @ 4927' by tubing measurement. Circulated clean. Monitored the well. Slight flow. Circulated well to balance fluid. Monitored well. Still slight flow @ 8-10 bph. We monitored the well recording flow for 1 hr. Well continued to flow the same @ 8-10 bph. Decided to bull head seawater down the btm perf. Bull headed 5.2 bbl down @ 1 bpm with the pressure climbing To 880 psi. We monitored the pressure bled down to 70 psi then stabilized. Open up well circ one hole volume @ 7 bpm. Had a max gas @ 445 units. Shut down and monitor well for 1 hr.Well flowing steady @ 8-10 bph. Decided to shut in and see what pressure builds up to. Pressure built to 67 psi. After calculating kill weight decide to weight up pits to 9.0 ppg. We left the well shut in while bringing wt up to 9.0 ppg in the pits. Pressures stayed @ 67 psi. Open up well &circ 9.0 ppg hole volume with max gas @ 447 units. Shut down and monitor well. Well dead. Slight losses @ 1-2 bph. Well out of balance on tubing. Pumped 0.2 ppg over slug to pull dry pipe. We are currently pulling out of the hole L/D tubing. Plan forward is to Pick up new tubing & RIH with a champ packer to test 7" casing. Total bbls gained during well monitoring 32 bbl. After circulating out several times during the night the flow is gas cut water. Sloan Sunderland ` North Slope i ! Drilling Foreman Office -907-670-3094 Cell 907-744-3622 Cell-907-715-0591 2 ' OF Th, • • evi 11/ s, THE STATE Alaska Oil and Gas of/\ J /\ sKA Conservation Commission •>� 333 West Seventh Avenue toptt T„,�t, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F jv ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov �E1 NO �°1 Bo York Operations Manager f 5 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-15 Sundry Number: 315-693 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i Cathy C. Foerster Chair DATED this /lay of November, 2015 Encl. '\%�� 0 • CC ` RG !V STATE OF ALASKA NOV 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION Os if(('T(j S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑I Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing LI Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ESP Change-out❑✓ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑- 194-153 a1�A=O 80 4.G.-- 3. � 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK,99503 50-029-22528-00-00- 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 477.05 Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT SB E-15 - 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025518 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): , Plugs(MD): Junk(MD): tO Z a t 5,410' - 4,673'- 5,283' ° 4,560' - ]96'� N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 5,391' 7" 5,391' 4,656' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic ; See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,807' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES VTL Packer x 2&HES BWD Sump Packer and N/A • 4,918(MD)/4,232(TVD),5,041(MD)/4,343'(TVD)&5,171'(MD)/4,459'(TVD and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic n X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development❑I - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/7/2015 OIL El' WINJ ❑ WDSPL ❑ Suspended [11 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email sporhola(u�hilcorp.com Printed Name Bo York Title Operations Manager Signatur i Phone 777-8345 Date tLi COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316—cog 3 Plug Integrity ❑ BOP Test 147O -rMecchhanical Integrity Test E] Location Clearance CI Other: ..X 3060 , sol( i G-+ cm P5%0 1102_14.1;.) n A -X 1.a s --t 1- f 5OZ7 i., c pi 6 A,'L 4e g-y, 06 (�� 1� �O`� Post Initial Injection MIT Req'd? Yes ❑ No Ej DOS u Spacing Exception Required? Yes IA No d Subsequent Form Required: J 0"1 04i yea / APPROVED BY Approved by: f 1,..,4, COMMISSIONER THE COMMISSION Date: 1i — 1 7 -7� -?q 1/I2//5- RIJNAL ' 'Form 10-403 Revised 11/2015 pa liaiIr 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU E-15 flilcorp Alaska,f f' Date: 11/06/2015 Well Name: MPU E-15 API Number: 50-029-22528-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: December 7th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-153 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,502 psi @ 4,000' TVD (Last BHP measured 2/11/2014) - 7.1-rt-6 Maximum Expected BHP: 1,502 psi @ 4,000' TVD (No new perfs being added) Current Shut-In Tbg Pressure: 300 psi - (Based on current SITP w/existing fluid column) Max. Predicted Surf Pressure: 1,102 psi ' (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU E-15 was drilled in 1994 using Nabors 22E and completed with a Frak-Pack in the Schrader Bluff N and OA sands. The well has had multiple ESP changeouts since 1994, (Nabors 4ES in 2002 and the most recent was an ESP changeout in 2011 using Doyon 16 to run a new ESP). Notes Regarding Wellbore Condition • Casing last tested to 1,500 psi for 30 min down to 4,880' MD on 4/29/2011. 41.c3 Cr, • Well has a history of scale. Objective: The purpose of this work is to pull the failed ESP, and run a new ESP. t✓- /0 _ C rho,c/s ,mol Brief Procedure: Pre-Rig Procedure: 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 Pump.Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. _1 •' '>* 5. Reverse circulate at least one wellbore volume with 8.5 ppg sea water down casing,taking returns up tubing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house. Spot mud boat. WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. II • • Well Prognosis Well: MPU E-15 Hilcorp Alaska,LI) Date: 11/06/2015 12. Kill well w/8.5 ppg seawater as needed. Set TWC. 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs 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. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor �" the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking ),/ yrs anywhere at surface.) 1142)c-, d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the vwell. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint(EUE) and BOLDS. 17. Pull over string weight (approx.40k PU)on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) iSr i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in 1-104 tubing head. Test BOPE per standard procedure. 18. POOH. Lay 2-7/8"tubing on the pipe rack(plan to re-run tubing). Lay down ESP. `- a. Replace bad joints of tubing as necessary. 'f$5.7 b. Look for over-torqued connections from previous Doyon#16 tubing runs. 14 ,,s- . 19. MU 6-1/8" mill/bit and casing scraper and RIH w/2-7/8"tubing. 20. Scrape 7" 26#casing down to+/-4,918' MD(VTL Packer). 21. POOH. Lay 2-7/8"tubing on the pipe rack. LD bit and casing scraper. 22. PU new 475 series ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing. a. Run 2-7/8"XN profile, 2 ea GLMS,and heat trace to+/-3,000'. (1-111/4 b. RU to use clamps to secure heat trace to tubing (ensure adequate clamps). 23. Set base of ESP at+/-4,800' (Pump intake around +/-4,775'). 24. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 25. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 26. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. . 2. RU crane. Pull BPV. Set TWC. ND BOPE. • • Well Prognosis Well: MPU E-15 Hilcorp Alaska,LL Date: 11/06/2015 3. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 4. Move 500 bbl returns tank and rig mats to next well location. 5. Replace IA pressure gauge if removed (7"). 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form H . . Milne Point Unit Well: MP E-15 C N bill-49`W:--) SCHEMATIC Last Completed: 5/01/2011 Hilcorp Alaska,LLC PTD: 194-153 CASING DETAIL Orig.RKB Elev.:53.9'/GL:24.3'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm _ 20" Conductor 91.4/H-40/PE 19.124 Surface 112' J 7" Production 26/L-80/BTC TUBING DETAIL 6.276 Surface 5,391' za' il 1 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 4,807' JEWELRY DETAIL No Depth Item 1 196' GLM t ,(- 2 4,608' GLM G-ray 3 4,752' XN-Nipple(2.250"ID) 4 4,763' Discharge Head:FPHVDIS 5 4,764' Pump:SXD 124-P4 6 4,777' Gas Separator 7 4,782' Upper Tandem Seal 8 4,788' Lower Tandem Seal 9 4,795' Motor:KMH/76hp/1,360V/34A Heat Tiacz@ 10 4,803' PumpMate XTO w/6-fin Centralizer-Bottom @ 4,807' 3,450' 11 4,918' HES VTL Packer 12 4,984' 20 ga screen w/2.99"ID-54.57'in length-Gravel Pack N-Sands,16/20 Carbolite 13 5,041' HES XN-Nipple(2.750"ID) 14 5,041' HES VTL Packer 2 15 5,128' 20 ga screen w/2.99"ID-43.49'in length-Gravel Pack OA-Sands,16/20 Carbolite 16 5,171' HES BWD Sump Packerw/4"ID *Note:All tubing/ESP jewelry depths based on Doyon#16 RKB 23.35'to Tbg Hanger M, 1 t All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL 1...,, 3 PERFORATION DETAIL T;, 4 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 4,5 N Sands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Frac Pack,12 spf i'' OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack,12 spf 7&8 %, 4 OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL 9 + 20" 250sks Arcticset I in a 24"hole KOP @ 1,000' 7„ 800sks of Permafrost"E",300 sx Trinity Lite Max Hole Angle=47 deg.@ 2,818' ,, 10 'a in a 8.5"Hole Hole Angle Thru Perfs=26 Deg. `! rt RA Tag TREE&WELLHEAD STIMULATION DETAIL 1.• A @835 Tree Cameron 2-9/16"SM Interval:4,990'to 5,028'Frac w/44,200lbs of FMC 11"Unibore x 2-7/8"EUE 8rd(Top Carbo Lite :a Wellhead &Bottom)TC-3-EC Hanger w/2.5"'H' -, 11 Interval:5,136'to 5,166'Frac w/108,0001bs porfile of Carbo Lite 12 NSaids{= i. y; 13GENERAL WELL INFO ► =' « 14 API:50-029-22528-00-00 :`s. '15Drill Nabors 22E/Nabors 4ES Frak Pack-9/13/1995 0A Sands { :- ESP Change-out w/Nabors 4ES-12/27/2002 "I' . ESP Change-out w/Doyon 16-4/29/2011 'r�.4 ,7,-.4 , 16 i. Top of Fill 5,283' TD=5,410(MD)/TD=4,673'(TVD) PBTD=5,302'(MD)/PBTD=4,577'(TVD) Created By:STP 8/18/2015 • Milne Point Unit Well: MP E-15 PROPOSED Last Completed: Proposed llilcarp Alaska,LLC PTD: 194-153 CASING DETAIL Orig.RKB Elev.:53.9'/GL:24.3'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.4/H-40/PE 19.124 Surface 112' JI, 7" Production 26/L-80/BTC 6.276 Surface 5,391' 20' TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±4,807' JEWELRY DETAIL No Depth Item 1 ±196' GLM 2 ±4,608' GLM 3 ±4,752' XN-Nipple(2.250"ID) 4 ±4,763' Discharge Head:FPHVDIS / 5 ±4,764' Pump:SXD 124-P4 6 ±4,777' Gas Separator t'R"SS C.sstrng 4/ 7 ±4,782' Upper Tandem Seal 8 ±4,788' Lower Tandem Seal 9 ±4,795' Motor:KMH/76hp/1,360V/34A 10 ±4,803' 3/8"External Capillary String 11 ±4,803' PumpMate XTO w/6-fin Centralizer-Bottom @ 4,807' 12 4,918' HES VTL Packer 13 4,984' 20 ga screen w/2.99"ID-54.57'in length-Gravel Pack N-Sands,16/20 Carbolite 14 5,041' HES XN-Nipple(2.750"ID) 2 15 5,041' HES VTL Packer 16 5,128' 20 ga screen w/2.99"ID-43.49'in length-Gravel Pack OA-Sands,16/20 Carbolite 17 5,171' HES BWD Sump Packer w/4"ID *Note:All tubing/ESP jewelry depths based on Doyon#16 RKB 23.35'to Tbg Hanger iI� All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL rPERFORATION DETAIL 4 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5 N Sands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Frac Pack,12 spf OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack,12 spf ‘' lll, ;6 v+' 7&8 l ,, OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL 4= 9 >- '' 20" 250sks Arcticset I in a 24"hole KOP @ 1,000' 107„ 800sks of Permafrost"E",300 sx Trinity Lite Max Hole Angle=47 deg.@ 2,818' it a in a 8.5"Hole Hole Angle Thru Perfs=26 Deg. 01• 11 I R4 Tag TREE&WELLHEAD STIMULATION DETAIL @4' Tree Cameron 2-9/16"5M / vALM Interval:4,990'to 5,028'Frac w/44,2001bs of • r FMC 11"Unibore x 2-7/8"EUE 8rd(Top Carbo Lite 12 Wellhead &Bottom)TC-3-EC Hanger w/2.5"'H' Interval:5,136'to 5,166'Frac w/108,000lbs porfile of Carbo Lite 13 N Sands{ a 14 GENERAL WELL INFO `' _� _� 15 API:50-029-22528-00-00 Drill Nabors 22E/Nabors 4ES Frak Pack-9/13/1995 OA Sai,ds { "v' 4' ESP Change-out w/Nabors 4ES-12/27/2002 * ESP Change-out w/Doyon 16-4/29/2011 1.-.::4111-4 ' 17 Top of Fill 5,283' 7" a .6 TD=5,410(MD)/TD=4,673'(TVD) PBTD=5,302'(MD)/PBTD=4,577'(TVD) Created By:STP 11/03/2015 • • Milne Point 2015 ASR Rig 1 Knight Oil Tools BOP Mewl a14t.k.. AMENEEMBEEMIII Stripping Head PI ShafWTz 11" - 5000 ELUELli 4,1: • CI -U I4 bpi 2 7/8" —5" VBR � I • I � 20 H I j 11" ®® 000 " I Blind 2" Kill Line 2" Choke Line len >!II •V �fl cs 111 Manual Manual Manual HCR Updated 11/03/15 • • • Choke Manifold ASR#1 11/01/2015 11.t.1...1 I I �� Digital Reverse line back to Kill Manifold Pressure Readout III C2 O. 1 * C3 Digital a Pressure Transmitter I From Choke Line Manual Choke : ; oo B .., Remote A Choke C4 C5 troll , C6 C7 II II r . i, Eabt, ,,,,G. „,,„ st 1 . € 0 ii 0 0 ii c 0 _ - I 00 1.1 lin III III a ism 2 at ill SII 5 -, PSI lel C9 I ii All Valves 2" Piper Series PB Ball Valves 6,170 psi Working 10,000 psi Tested C8 111M���' C11 0r C10 I ill C13 I C15 ,11,,:' ,, ,,,,,,:: ,.,,i 4141:.* o `, 1.I III C12 MI 1 1 *� C14 MIMIC) _ C16 % s le ItIil To Panic Line 1502 Union Outside End Capped To Gas Buster III I 0 MPU E-15 EXISTING TREE/WELLHEAD Wellhead/Tree Milne Point Unit Ilileorp Alaska,1.1A: Tree Cap 1.1 is Tree Valve 2-9/16" 5M r $00 fes., ( F. Tree Cross 2-9/16" 5M 1111°_,C,o)(111 Tree Valve 2-9/16" 5M SSV 2-9/16" 5M O ilmm r T0 Heat Trace Tree Valve 2-9/16" 5M /o -`000 ESP Cable vibi Tubing Adaptera _ .,. ....... .,,,, i ,....... Tubing Head I„ #1111 11" 5MTop x11" 5MBt Er all [0I ;� ���u At 10M- (Alt):,111'11115024 fit III t III .. :..11 . Casing Head — fd �' ° c 11" 5M Top x 11" 5M Btm IOlt �Iui ;■IC`► ]I M41 III i Witt __. I_ 7, 0 • °' -6 ''• ..,°A a a h z L, 1 IlXz°-e0 B MI •• -c, OD 91D © . O a• ,...,.• a) > > .,., (. 9 Ir• .. g (5` -A '-' rl u 2 ill• t-I• t.1 • -..1 zr, › E u: a 2 ••• ca 1— 0 Z31 viv 63 TT3 VD .7, 0 co: ,-, • 0 2 0 x 3: k., • co co _. co 0 8 co ... 8 •:z SD IN• .-I• U- C z go • i t, ri! go 0 .c u 1 -4 Cil 1 cc A i >wI , us ; 7, a I k-, > 0 ., , a :•: s41u1u,ni › 1 1 s , _. .. .,„, 0 •'ti , =u 0 Z '0 .... r 0. kJ a3 -J CO • 0 V I a cr• < Y 1 4:iit • ..*.t'",. IFC — cgfj_ I I —I I— v• w 2 co < c.7 E —DM— < 2 Y Y 1.1 'IF 2 1-- E H F -NI-- -1*— —flikl- --Pkl— _.4 F_ a g 01 a (- a.II IF Z 23 • • `-c 3 > Q U i w F.3 > s a xa` w > Ca1 co 1 . I X ® 9T7 U Y o T a > a 1 1 Z V V « 'V :� > N 'S.) Z 7 W u z_ w Z7 u+ 67 in tT7 m a w > C7 d 1 3L0:141 rn E u m m 0 u m $ Q 87 N V N C TT _. V_ c C 2 N d Y O A 0 3 ag v _ 0 A 12 to-1011-La �ITInl c m ? a m a. a F _• Y g. Z _FF 6 ~ u OC4,1 m a 101 a -I I H I— VI 7 Y Q m O Y Y Q < !- 0 z v 2 yO 9)1 Y Y Y W I F 1-- . } .- E s HI- {N— HI- -N— —I I-- a. a C IV O � I7 u N 1 • • IL 4 E $ c Qsa x c co 1 ' , g Zcl-3110 0 MI esu > gt 013 9T) a d o �/ (LQ^� ^� U m �/ vw N• J i 4 ; T N V W W ��""'' �.. le Z Z Q t; W a 4 is p a 6 z Y Z7 •; 6) TTD 4TD a w > C7 W m m a v S: u . m 0 $ m u 8 a 83 N • .• V• N C J N C . .'t.' A d C Y O t V cu cc 2 W V o1 3x S = _ D m w V c co a a m - 1 :r .i. z 0. V 2 a v a a c m D = m g s... c T 401 it H I cc H F- r � 03 0 m L,11 PY$ a i F- o _W Z 2 YA9�aY _ F- 211 m Y Y w i F- r r r F. "1 I- -1 'I I— illE --I I- a c Cu FV • • f / k .) § c/ >■ p�E 2. > E o Ii� k � « a a...- � 2 ® > � o03 / 2 a E� (X§ . . . ■ ■ ■ 0 \ 030 RI / z �� : E� 0. k � @ 0 B d2 CD _a k U 2 g lii k & k � a.t "0 = » -a0 ® J 2c <0 = Q t 22m 0 � k ƒa a 2 § C§ 4 o. _ � 0- L. S \ 8 c a) - kc f kp ta a 2 2 / � .2 / « �/ a. ■ Q 2 % o vs E 0 Q § 5 0 » ® Ts— a) m cid � . a Q II § o a$ k v ) 2 it .. t .. -6 ... q C o � & k r k 2 >o a a ƒ 0 2 co k 9 < a 23 0 k • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 06, 2015 4:41 PM To: Stan Porhola Cc: Carlisle, Samantha J (DOA) Subject: RE: Disregard Sundry 315-525 (MPU E-15 .. PTD 194-153) Sundry 315-525 will be retracted as per your request below. (PTD 194-153) Guy Schwartz J X015 Sr. Petroleum Engineertu'4 AOGCC RBOM5 Q'''...... 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, November 06, 2015 3:19 PM To: Schwartz, Guy L (DOA) Subject: Disregard Sundry 315-525 Guy, Please disregard Sundry 315-525 for well MPU E-15 (PTD 194-153). A new sundry is being submitted. Regards, Stan Porhola Operations Engineer North Mope Asset Team Hilcorp Alaska, LLC SEWED JUN Q 3 2016 sporhola@hilcorp.com ,,..®®����11 Office: (907) 777-8412 Mobile: (907) 331-8228 1 iAcrOF Ty s THE STATE Alaska Oil and Gas .s� 7A, o T j\ SJ(j\ Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 �FALASY'' Fax• 907.276.7542 www.aogcc.alaska.gov Stan Porhola453 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB E-15 Sundry Number: 315-525 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 5� DATED this31 day of August, 2015 RBDMSBSEP fl 2 t Encl. RECEIVED STATE OF ALASKA AUG 262015 OALASKA OIL AND GAS CONSERVATION COMMISSION 5 '/ iS !A1 APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request' Abandon❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing D Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate []S •I' Alter Casing ❑ Fill Clean-out0 Plug for Redrill❑ Perforate New Pool ❑ Repair Well '4' Re-enter Susp Well ❑ Chage-out ESP Q 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development Q• 194-153 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22528-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 477.05 " / Will planned perforations require a spacing exception? Yes ❑ No El 1 MILNE PT UNIT SB E-15 • 9 Property Designation(Lease Number). 10.Field/Pool(s): ADL0025518 ' MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft): Effective Depth TVD(ft)• Plugs(measured): Junk(measured). 5,410 4,673 5,283 4,560 5,302' 5,283'(Fill) Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Production 5,391' 7" 5,391' 4,656' 7,240psi 5,410psi Intermediate Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic' See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,807' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): . HES VTL Packer x 2&HES BWD Sump Packer and N/A 14,918(MD)/4,232(TVD),5,041(MD)/4,343'(TVD)&5,171'(MD)/4,459'(TVD and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development Q' Service ❑ 14 Estimated Date for 15.Well Status after proposed work: 9/28/2015 Commencing Operations: OIL ❑✓ • WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG Cl Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola@hilcorp.com Printed Name S n Porho}� Title Operations Engineer Signature V Z Phone 777-8412 Date 8/26/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. _ 25 Plug Integrity El111 /�BOP Test/ Mechanical Integrity Test ❑ Location Clearance Other: -k- 3 c^ua aP s- �v! 7- 1-- ( NMASV- WC)2_es:) Spacing Exception Required? Yes ❑ No Subsequent Form Required: `U"y C 1 APPROVED BY Approved by:ae, COMMISSIONER THE COMMISSION Date. g . 3/ /3--- ft., 144/i c9/ 44/i 5 v 8'17 L s". A- 7 Submit Form and Form 10-403 Revised 5/2015 0 RnivGiNi�1 s slid for 12 months from the date of approval. Attachments in Duplicate II Well Prognosis Well: MPU E-15 Hilcorp Alaska,LL Date:8/26/2015 Well Name: MPU E-15 API Number: 50-029-22528-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: September 28th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-153 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: )`) • Current Bottom Hole Pressure: 1,502 psi @ 4,000'TVD (Last BHP measured 2/11/2014) \ 1 w.��� Maximum Expected BHP: 1,502 psi @ 4,000'ND (No new perfs being added) / 6y Max.:ith3W8b1 Surf Pressure: 0 psi (Based on SBHP taken 2/11/2014 and water cut .411..+-:`I of 50% (0.385psi/ft)with an added safety factor I502-o- - y`'2'eSV of 1,000' ND of oil cap) Zg,,Pt '. Brief Well Summary: _ !w Z 0: MPU E-15 was drilled in 1994 using Nabors 22E and completed with a Frak-Pack in the Schrader Bluff N„-&.c-- and Sx-and OA sands. The well has had multiple ESP changeouts since 1994, (Nabors 4ES in 2002 and the most recent was an ESP changeout in 2011 using Doyon 16 to run a new ESP). Notes Regarding Wellbore Condition • Casing last tested to 1,500 psi for 30 min down to 4,880' MD on 4/29/2011. Obiective: The purpose of this work/sundry is to pull the existing failed ESP and run a new ESP. Brief Procedure: WO Rig Procedure: 1. Circulate well with 8.4 ppg lease water down tubing and fill casing. 2. RU crane. Set BPV. ND Tree. NU 11" BOPE. 3. MIRU Hilcorp ASR#1 WO Rig. 4. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 2-7/8"test joint. '5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Well Prognosis Well: MPU E-15 Hilcorp Alaska,LL Date:8/26/2015 d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 6. Bleed any pressure off tubing and casing. Pull BPV. 7. MU landing joint(2-7/8" EUE 8RD hanger thread)and pull over string weight(previous rig string weight 80k UWT with Doyon 16 includes top drive weight) on tubing hanger to confirm free. 8. POOH. Lay 2-7/8"tubing on the pipe rack(utilize as workstring). a. Drift ID of 2-7/8"tubing is 2.347". 9. MU 6-1/8" bit and junk baskets and RIH to packer+/-4,918' MD. 10. POOH. Lay down bit and junk baskets. Lay down 2-7/8"tubing. 11. MU 2-5/8" mill and junk baskets and RIH to packer+/-4,918' MD. 12. Cleanout fill inside screens down to PBTD+/-5,302' MD. a. Min ID is 2.750" at X-profile+/-5,041' MD. 13. Circulate bottoms up x 2 with 8.4 ppg lease water. 14. POOH. Lay down mill and junk baskets. Lay down 2-7/8"tubing. 15. PU new 475 series ESP and RIH with new 2-7/8" 8RD EUE L-80 tubing. 16. Set base of ESP at+/-4,850' MD(Pump intake around+/-4,810' MD). Land tubing hanger. a. Run 3/8"control line w/clamps down to pump gauge centralizer. 17. Lay down landing joint. Set BPV. ND BOPE. NU existing 2-7/8" 5,000#tree. Pull BPV. 18. Set TWC.Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 19. RD Hilcorp ASR#1 WO Rig. 20. Replace IA x OA pressure gauge if removed (7"x 20"). 21. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic Milne Point Unit Well: MP E-15 . 14 SCHEMATIC Last Completed: 5/01/2011 Hileorp Alaska,LLC PTD: 194-153 CASING DETAIL Orig.RKB Elev.:53.9'/GL:24.3'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 41 L 7" Production 26/L-80/BTC 6.276 Surface 5,391' TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 4,807' JEWELRY DETAIL No Depth Item 1 196' GLM 2 4,608' GLM 3 4,752' XN-Nipple(2.250"ID) 4 4,763' Discharge Head:FPHVDIS 5 4,764' Pump:SXD 124-P4 6 4,777' Gas Separator 7 4,782' Upper Tandem Seal 8 4,788' Lower Tandem Seal 9 4,795' Motor:KMH/76hp/1,360V/34A Heat Trace 10 4,803' PumpMate XTO w/6-fin Centralizer-Bottom @ 4,807' 3,450' 11 4,918' HES VTL Packer 12 4,984' 20 ga screen w/2.99"ID-54.57'in length-Gravel Pack N-Sands,16/20 Carbolite 13 5,041' HES XN-Nipple(2.750"ID) 14 5,041' HES VTL Packer 15 5,128' 20 ga screen w/2.99"ID-43.49'in length-Gravel Pack OA-Sands,16/20 Carbolite p 2 16 5,171' I HES BWDSump Packerw/4"ID *Note:All tubing/ESP jewelry depths based on Doyon#16 RKB 23.35'to Tbg Hanger ,.jUMAll sand control jewelry depths based on Nabors 22E RKB 29.6'to GL Y3 41 iii > t'„ PERFORATION DETAIL *.j 1, �a 4 Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status i 5 N Sands 4,990' 5,028' 4,297' 4,331' 38' 9/09/95 Frac Pack,12 spf OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack,12 spf Ili, r,6 3' ' „7&8 i " OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL i+ ;t;9 20" 250sks Arcticset I in a 24"hole KOP @ 1,000' ,C 800sks of Permafrost"E",300 sx Trinity Lite Max Hole Angle=47 deg.@ 2,818' )' " 10 3 7 in a 8.5"Hole Hole Angle Thru Perfs=26 Deg. g @ 4Tag TREE&WELLHEAD STIMULATION DETAIL Tree Cameron 2-9/165M ,835 VbLM " Interval:4,990'to 5,028'Frac w/44,200Ibs of FMC 11"Unibore x 2-7/8"EUE 8rd(Top Carbo Lite e^ N Wellhead &Bottom)TC-3-EC Hanger w/2.5"'H' `t' _-4 1 11 Interval:5,136'to 5,166'Frac w/108,000Ibs porfile of Carbo Lite '12 4" NSands{* 1 13 �€ GENERAL WELL INFO i ,1 I►: 14 API:50-029-22528-00-00 .,� L _x..15 �"' Drill Nabors 22E/Nabors 4ES Frak Pack-9/13/1995 OAS{ p ESP Change-out w/Nabors 4ES-12/27/2002 r r ESP Change-out w/Doyon 16-4/29/2011 I a„ ., rZe I._- 16 9Top of Fill, .... �,�,5,283' 1D=5,410(MD)/TD=4,673'(TVD) PBTD=5,302'(MD)/PBTD=4,577'(TVD) Created By:STP 8/18/2015 Milne Point Unit Well: MP E-15 . 14 PROPOSED Last Completed: 5/01/2011 Ilileorp Alaska,LLC PTD: 194-153 CASING DETAIL Orig.RKB Elev.:53.9'/GL:24.3'Nabors 22E Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.4/H-40/PE 19.124 Surface 112' 41 I 1 7" Production 26/L-80/BTC 6.276 Surface 5,391' 20„ TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface ±4,807' JEWELRY DETAIL No Depth Item 1 ±196' GLM 2 ±4,608' GLM 3 ±4,752' XN-Nipple(2.250"ID) 4 ±4,763' Discharge Head:FPHVDIS 5 ±4,764' Pump:SXD 124-P4 6 ±4,777' Gas Separator 7 ±4,782' Upper Tandem Seal 8 ±4,788' Lower Tandem Seal _ 9 ±4,795' Motor:KMH/76hp/1,360V/34A TraceHeat @ 10 ±4,803' PumpMate XTO w/6-fin Centralizer-Bottom @ 4,807' 3,450x E 11 4,918' HES VTL Packer 12 4,984' 20 ga screen w/2.99"ID-54.57'in length-Gravel Pack N-Sands,16/20 Carbolite I 13 5,041' HES XN-Nipple(2.750"ID) 14 5,041' HES VTL Packer 2 4 15 5,128' 20 ga screen w/2.99"ID-43.49'in length-Gravel Pack OA-Sands,16/20 Carbolite t 16 5,171' HES BWD Sump Packer w/4"ID :; *Note:All tubing/ESP jewelry depths based on Doyon#16 RKB 23.35'to Tbg Hanger ti Ii + All sand control jewelry depths based on Nabors 22E RKB 29.6'to GL rk In3 V ' 4! ¢' PERFORATION DETAIL 1' Y+ 4 n Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status -*5 N Sands 4,990' 5,028' 4,297 4,331' 38' 9/09/95 Frac Pack,12 spf OA Sands 5,136' 5,166' 4,428' 4,455' 30' 9/06/95 Frac Pack,12 spf N IIII 6 ,; IIs,78,8 i : OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL I,,9 > , 20" 250sks Arcticset I in a 24"hole KOP @ 1,000' 8.5"in a Hole 7„ 800sks of Permafrost"E",300 sx Trinity Lite Max Hole Angle=47 deg.@ 2,818' � ,a K 10 0Hole Angle Thru Perfs=26 Deg. RA Tag TREE&WELLHEAD STIMULATION DETAIL li:AV WJ1 Tree Cameron 2-9/16"5M Interval:4,990'to 5,028'Frac w/44,200lbs of FMC 11"Unibore x 2-7/8"EUE 8rd(Top Carbo Lite `" Z Wellhead &Bottom)TC-3-EC Hanger w/2.5"'H' ' ►_a v s 11 Interval:5,136'to 5,166'Frac w/108,0001bs i., e porfile of Carbo Lite v: ..12 •y. NSands{a r' 14 13 6 GENERAL WELL INFO ..-4, i r- 14 API:50-029-22528-00-00 t1 15 M Drill Nabors 22E/Nabors 4ES Frak Pack-9/13/1995 OA Saids{ ESP Change-out w/Nabors 4ES-12/27/2002 r, 7' ESP Change-out w/Doyon 16-4/29/2011 I"' •_ 4 „r 16 Top d Fill v: �4.' 5,283' TD=5,410(MD)/TD=4,673'(TVD) PBTD=5,302'(MD)/PBTD=4,577'(ND) Created By:TDF 8/26/2015 Milne Point 2015 ASR Rig 1 `�'�.►N, Knight Oil Tools BOP ficin 11" BOPE Stripping Head 3.98' ' Shaffer I 4 11"- 5000 111111 IllI11lit I AIM A 111.1111!1 lllrule CI6U . 11 4.54' IsW - 2 7/8-5 variables ar: Pr ;Arial 11"-50001111=1 Blind 1111 lit 111( ! it 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves i Il1Ill1l1111=!: 1. 2.00' o�u . : 1 € – 111 111 thin 111��� - — Manual Manual Manual HCR Updated 8/19/15 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the Original file and viewable by direct inspection. I~ C/ -. I,~-.~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: . Scanned by: Beved~Vincent Nathan Lowell Date: f~ '--3 [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 w Post Office Box 196612 Anchorage, Alaska 99519 - 6612 ED FEB 2 2 ZQIZ December 30, 201 of 1+-15 f` 1 5 3 tmpf-- pr's %' " ID Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue _ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, • Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE -09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 ----fir' MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 STATE OF ALASKA ALASKA./ AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATI 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 194 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 1 50 - 029 - 22528 - 00 - 00 7. Property Designation: 8. Well Name and Number: ` ADL 025518 v MPE -15 9. Field / Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured 5410' feet Plugs (measured) None feet true vertical 4673' feet Junk (measured) None feet Effective depth: measured 5302' feet Packer: (measured) 4918', 5041' & 5171' feet true vertical 4577' feet Packer. (true vertical) 4232', 4343' & 4459' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface Intermediate Production 5391' 7" 5391' 4656' 7240 5410 Liner Perforation Depth: Measured Depth: 4990' - 5166' 4 0 JUN b 1 2 .° 11 True Vertical Depth: 4297' - 4455' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 4807' 4133' Packers and SSSV (type, measured and true vertical depth): 4918' 4232' Screen Assembly: 7" VTL Packers (2) and 5041' 4343' 7" x 4-1/2" HES 'BWD' Sump Packer 5171' 4459' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ��` s' / ttt S;3 Gil & 68$ ;Aft&. CiiiiwIlISSian 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 28 100 Not Available Not Available Subsequent to operation: 120 21 125 20 172 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ - IN OiI ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Charles Reynolds, 564-5480 N/A Printed Name 4Terr1/111/ Hubble iie p�}�QJ�Qp Title Drilling Technologist f�c . 4 a O e, 56 4 r: Signature Phone 564 - 4628 Date Ii( Prepared By Terrie Hubble, 564 Name/Number Form 10-404 Revised 10/2010 � � � ��� 71_ S_3/_/ Submit Original Only MOMS r'tl4f • • North America - ALASKA BP Page 1 of 5 Operation Summary Report - - Common Well Name: MPE -15 AFE No Event Type: WORKOVER (WO) I Start Date: 4/25/2011 I End Date: 5/1/2011 X4- OORFH -E (700,000.00 ) Project: Milne Point ' Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/16/1995 12:00:OOAM Rig Release: 5/1/2011 Rig Contractor: DOYON DRILLING INC. [UWI: 500292252800 Active Datum: 27 15 7/14/1998 06:00 ©83.20ft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (ft) I 4/25/2011 15:00 - 15:30 1 0.50 RIGD P PRE !BLOW DOWN SURFACE LINES 15:30 - 18:00 2.50 RIGD P PRE LRHOS FREEZE PROTECTS WELL WHILE DOYON 16 CONTINUES TO RD -HANG STABBING BOARD 18:00 - 22:00 4.00 RIGD P PRE !PREP RIG FOR RIG MOVE ' -LD DERRICK AND SECURE WIND WALLS, 1 1 — ETC. ' 22:00 - 23:00 1.00 RIGD P PRE REMOVE BOP FROM CELLAR AND SECURE ONTO TRANSPORT SKID 23:00 - 00:00 t 1.00 RIGD P PRE I INSTALL REAR BOOSTERS 4/26/2011 , 00:00 - 04:30 4.50 MOB P PRE � MOVE RIG FROM MPU J PAD TO MPU E PAD. 04:30 - 06:30 2.00 MOB P PRE STAGE RIG TO PULL OVER MPE -15. II REMOVE BOOSTERS AND INSTALL BOP. 06:30 - 09:00 2.50 MOB P PRE STAGE HERCULITE AND RIG MATS. 09:00 - 13:00 4.00 RIGU P PRE ' SPOT AND SHIM RIG. I -BUILD UP ENTRY WAYS DUE TO SPOTTING 3 I MAT BOARDS HIGH. -LOWER CELLAR DOORS. -SPOT AND BERM SLOP TANK. I -SPOT TIGER TANK. 1 -1200 PSI IA. ' 13:00 - 15:30 2.50 RIGU P PRE CRAISE AND SECURE DERRICK, CATTLE CHUTE, TUGGER, & MAN RIDER. i -POST RIG MOVE CLEAN UP. I -TAKE ON SEAWATER. ACCEPT RIG @ 15:00 HRS 15:30 - 18:00 2.50 WHSUR P WHDTRE BRIDAL DOWN AND SECURE TOP DRIVE. I - PREPARE RIG FLOOR. 18:00 - 20:00 2.00 WHSUR P WHDTRE R/U CIRCULATING LINES. R/U SQUEEZE MANIFOLD. _ _ -R/U CHOKE & KILL LINE. 20:00 - 21:00 1.00 WHSUR P I 11 WHDTRE ! CONDUCT RIG EVACUATION DRILL. -AAR. ' 21:00 23:30 2.50 WHSUR P WHDTRE ' FILL & TEST LINES 250 / 2000 PSI 5 MINUTES EACH. -0K. 1 23:30 - 00:00 0.50 r DHB P DECOMP r R/U & TEST LUBRICATOR 250 / 2000 PSI. -PULL BPV. 600 PSI ON TBG. 4/27/2011 00:00 - 00:30 0.50 DHB P DECOMP I R/D DSM LUBRICATOR. 00:30 - 06:00 5.50 KILLW P DECOMP STEAM CIRCULTING LINES. BLOW AIR THROUGH LINES. -IA 1200 PSI. TBG 600 PSI. -OPEN WELL AND BLEED IA TO 600 PSI. -BLEED IA & TBG TO ZERO. - MONITOR WELL 20 MINUTES, PRESSURE BUILT UP TO 20 PSI. ! -BLEED WELL TO ZERO W/ 8 GALLONS OF IRETURNS. -SHUT IN MONITOR WELL - ZERO PRESSURE. -OPEN UP WELL, ZERO PSI AND NO FLOW OUT. Printed 5/11/2011 10:21:59AM •rth America - ALASKA - BP Page 2 of 5 w Operation Summary -Report Common Well Name: MPE -15 AFE No Event Type: WORKOVER (WO) Start Date: 4/25/2011 End Date: 5/1/2011 X4- 00RFH -E (700,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/16/1995 12:00:OOAM Rig Release: 5/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292252800 I Active Datum: 27:15 7/14/1998 06:00 @83.20ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT I NPT Depth 1 Phase Description of Operations (hr) ! i (ft) 06:00 - 07:30 1.50 1 KILLW P I DECOMP WITH WELL DEAD AND NO FLOW. -BULL HEAD 30 BBLS HEATED SEAWATER DOWN TBG @ 5 BPM & 800 PSI. 1- TBG =O PSI AND IA =10 PSI. I- PUMPED 400 BBL HEATED SEAWATER I DOWN TUBING. ! - THROUGH CHOKE TO TIGER TANK AT 5 1 BPM/960 PSI. -PUMP UNTIL RETURNS WERE CLEAN. ! I ' -LOST A TOTAL OF 20 BBLS TO FORMATION. 1I ! -SHUT DOWN PUMPS. TBG & IA ARE ON A VACUUM. - RECOVERED 140 BBLS CRUDE AND 85 BBLS SEAWATER TO TIGER TANK. - ESTABLISHED CONTINUOUS HOLE FILL - 20 BPH. 07:30 - 08:30 1.00 WHSUR 1 P ! DECOMP I BLOW DOWN LINES TO TIGER TANK. -PURGE LINES WITH STEAM. -BLOW DOWN AGAIN. I - MAINTAIN CONTINUOUS HOLE FILL AT 20 ' BPH. 108:30 - 11:00 2.50 WHSUR , P 1 T DECOMP R/U LUBRICATOR AND PT 250 LOW PSI / 1500 HIGH PSI. ' 1 -SET TWC. ! - ROLLING PRESSURE TEST BELOW AT 500 , PSI PUMPING 4 BPM @ 600 PSI. PUMPED AWAY 50 BBLS. -P/T FROM ABOVE AT 250 PSI LOW PSI AND 3500 PSI HIGH PRESSURE. r-R/D DSM LUBRICATOR. 11:00 - 13:00 2.00 WHSUR P DECOMP SUCK OUT TREE. N/D TREE. 13:00 - 17:00 4..00 BOPSUR 1 P ' — DECOMP N/U BOPS & RU TO TEST. 0 17:00 - 21:30 4.50 BOPSUR P DECOMP TEST BOPE PER WELL PLAN,,PERMIT TO _$ I DRILL, AND AOGCC REGS. v ld -t TEST WITNESS WAIVED BY JEFF JONES OF AOGCC. ALL COMPONENTS TESTED TO 250 PSI LOW 1 AND 3500 PSI LOW. -TEST USING 2 -7/8" AND 4" TEST JOINTS. - PRESSURE TEST 13 -5/8" HYDRIL. '- PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL & DDI TP. 1 , -ALL TEST FOLLOW TESTING CRITERIA 1 DOCUMENTED IN CRT - AK -10 -45 1-MAINTAINING 20 BPH CONTINUOUS HOLE FILL IN THE IA DURING TESTING. KOOMEY DRAW DOWN TEST: -2900 PSI DRAWN DOWN TO 1750 PSI. -200 PSI INCREASE IN 18 SECONDS. ! I -FULL PRESSURE IN 82 SECONDS. -5 N2 BOTTLES @ 2000 PSI. 21:30 - 22:30 1.00 , BOPSUR P DECOMP BLOW DOWN. R/D ALL TEST EQUIPMENT. -DRAIN STACK. WASH & VACUUM ON TOP OF TWC. -TIME CLOSING OF BOP COMPONENTS: - ANNULAR= 18 SEC, UPPER VBR'S 2 -7/8" x 5 "= I 7 SECONDS. - BLIND /SHEAR= 12 SECONDS, LOWER 2 -70= 8 SECONDS. 1 22:30 23:00 ' 0.50 BOPSUR P 1 DECOMP I PERFORM DERRICK INSPECTION, KNOCK ICE ! — !, OUT OF DERRICK. Printed 5/11/2011 10:21:59AM Page 3 of 5 •rth America - ALASKA BP Operation Summary Report — Common Well Name: MPE -15 AFE No Event Type: WORKOVER (WO) 1 Start Date: 4/25/2011 I End Date: 5/1/2011 X4- 00RFH -E (700,000.00 ) I Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 ; Spud Date/Time: 5/16/1995 12:00:OOAM Rig Release: 5/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292252800 Active Datum: 27:15 7/14/1998 06:00 @83.20ft (above Mean Sea Level) Date 1 From - To I Firs 1 Task 1 Code 1 NPT NPT Depth Phase , Description of Operations L_ (hr) _ (ft) 23:00 - 00:00 1.00 I BOPSUR 1 P DECOMP R/U & TEST LUBRICATOR 250 PSI LOW / 2000 , HIGH PRESSURE. - 5 CHARTED MINUTES EACH. 4/28/2011 00:00 02:00 2.00 PULL P 1 DECOMP ; PULL TWC. R/D DSM. i I 1 -DSM HAD TROUBLE OPERATING LUBRICATOR. 1 -LUBRICATOR WAS FLUID LOCKED AND I WOULD NOT GO DOWN. 102:00 - 03:00 1.00 PULL 1 P DECOMP M/U LANDING JT W/ CMT HOSE. I -RIH ENGAGE HANGER. BOLDS. 1 -PULL HANGER TO RIG FLOOR. 1 -OFF SEAT= 80K, PUW= 77K. 03:00 - 04:30 j 1.50 I PULL P DECOMP PUMP 20 BBLS SAFE - SURF -O PILL. -PUMP 5 BPM / 820 PSL DYNAMIC LOSSES= 60 BPH. _ , ± _ - MONITOR WELL- STATIC LOSSES 60 BPH. 04:30 - 05:30 1.00 PULL P DECOMP TERMINATE ESP & HEAT TRACE LINES. 1 -B /O & UD LANDING JT & CMT HOSE. 1-E3/0 & UD TBG HANGER. -R/U TO PULL ESP COMPLETION. 05:30 - 15:30 10.00 PULL P DECOMP j PULL 2 -7/8" ESP COMPLETION. 1 ' RECOVERED ALL FLAT GUARDS & BANDS. -RECOVERED 25 LASALLE CLAMPS. 1 I -PIPE CONDITION STARTED TO DEGRADE W/ DEPTH. I -@ JT 80, BAD INTERNAL PITTING NOTED. 15:30 - 18:00 1 2.50 PULL P DECOMP j BREAK & UD ESP MOTOR ASSEMBLY. 1 -MOTOR ELECTRIC TEST - TESTED GOOD. +- -MOTOR WAS PLUGED UP. 18:00 - 19:00 1.00 PULL P DECOMP R/D SHEAVE & ESP TRUNK. INSTALL WEAR RING. 9 -1/8" I.D. - CONTINOUS HOLE FILL @ 20 BPH. 1 19:00 - 21:00 2.00 CLEAN P j CLEAN , CLEAR & CLEAN RIG FLOOR. GENERAL 'HOUSEKEEPING. 21:00 - 00:00 3.00 CLEAN P CLEAN I P/U HES 7" CHAMP PKR ON 4" DP AND SINGLE IN THE HOLE. -RIH TO 1733' MD. -1 4/29/2011 00:00 - 04:30 4.50 EVAL P OTHCMP I CONTINUE TO SINGLE IN THE HOLE FROM 1733' TO 4854' MD. -PUW= 100K, SOW= 100K. -SET 7" CHAMP PKR COE @ 4880' MD. -FILL BACKSIDE, 8 BBLS TO FILL. 1 1-TEST TO 1500 PSI / 30 CHARTED MINUTES 1-PASS. -BLOW DOWN, R/D SURFACE LINES. i MONITOR WELL, OBTAIN LOSS RATE 60 1- OTHCMP ! BPH. EVAL P 04:30 - 11:00 6.50 1 POH W/ 7" CHAMP PKR. UD 4" DP. - CONTINOUS HOLE FILL OF 20 BPH. 11:00 - 12:00 1 1.00 EVAL P OTHCMP UD CHAMP PACKER. -RID FROM RUNNING DRILL PIPE. - i -PULL WEAR RING. 1 12:00 - 13:00 ' 1.00 EVAL 1 P 1 1 OTHCMP 1CLEAN AND CLEAR RIG FLOOR. -VISIT BY BP AND DDI SAFETY ! 1 REPRESENTITIVES. Printed 5/11/2011 10:21:59AM - •rth America - ALASKA - BP Page 4 of 5 Operation Summary Report Common Well Name: MPE -15 AFE No Event Type: WORKOVER (WO) Start Date: 4/25/2011 ' End Date: 5/1/2011 IX4- OORFH•E (700,000.00 ) Project: Milne Point Site: M Pt E Pad . Rig Name /No.: DOYON 16 � Spud Date/Time: 5/16/1995 12:00:OOAM Rig Release: 5/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292252800 Active Datum: 27 : 15 7/14/1998 06:00 @83.20ft (above Mean Sea Level) Date From - To Hrs Task I Code I NPT 11 NPT Depth I Phase I Description of Operations (hr) (ft) 13:00 - 16:00 ; 3.00 RUNCOM ' P I RUNCMP R/U TO RUN 2 -7/8 ESP COMPLETION. -HANG ESP CABLE SHEAVE. -R/U POWER TONGS. -P /U CLAMPS, FLAT GUARDS. -LOAD ESP ASSEMBLY AND INSPECT. i -LOAD SPOOLING UNIT W/ ESP CABLE ! SPOOL & HEAT TRACE. 16:00 19:00 3.00 RUNCOM ! P RUNCMP 1P/U & Mill ESP ASSEMBLY. -FILL & CHECK CONTINUITY. 19:00 - 00:00 5.00 RUNCOM P RUNCMP f RIH W/ ESP COMPLETION ON 6.5 #, 2 -7/8" EUE, L -80 TBG. ' - UTLIZE BEST -O -LIFE 2000 THREAD I COMPOUND. j -TQ T02300 FT /LBS OPTIMUM. -RUN +/- 3500' OF HEAT TRACE W/ ESP I CABLE. -CHECK CONTINUITY EVERY 2000'. , I -USE FLAT GUARDS ON EVERY COLLAR FOR • THE LENGTH OF THE HEAT TRACE. -USE CANNON CLAMPS PER PROGRAM. -USE CANNON CLAMPS ON ALL GLM PUPS ' i- CONTINUE TO FILL HOLE © 20 BPH. 4/30/2011 00:00 - 12:00 12.00 RUNCOM P RUNCMP CONTINUE TO RUN 2 -7/8" ESP COMPLETION I PER PROGRAM I -CHECK CONTINUITY EVERY 2000'. I - CIRCULATE 5 BBLS EVERY 2000', 0.5 BPM / 1440 PSI. I -USE CANNON CLAMPS PER PROGRAM. I -AT 3,500 FT / TOP OF JOINT # 39 START TO RUN HEAT TRACE TAPE WITH ESP CABLE. -FEED WELL AT 20+ BPH WITH 8.5 PPG _ _ I I I SEAWATER. 12:00 - 16:30 4.50 RUNCOM fi P RUNCMP CONTINUE TO RUN 2 -7/8" ESP COMPLETION PER PROGRAM FROM JOINT # 110. i -CHECK CONTINUITY EVERY 2000'. - CIRCULATE 5 BBLS EVERY 2000', 0.5 BPM / I 1480 PSI. -USE CANNON CLAMPS PER PROGRAM. I 1 -FEED WELL AT 14 - 16 BPH WITH 8.5 PPG I II SEAWATER . 16:30 - 17:00 0.50 RUNCOM P RUNCMP KICK WHILE TRIPING DRILL WITH ASSOCIATED AAR 17:00 - 21:00 'I 4.00 RUNCOM P RUNCMP I CONTINUE TO RUN 2 -7/8" ESP COMPLETION PER PROGRAM FROM JOINT # 133. -FEED WELL AT 14 -16 BPH WITH 8.5 PPG I SEAWATER. I i -CHECK CONTINUITY EVERY 2000'. - CIRCULATE 5 BBLS EVERY 2000', 0.5 BPM / 1460 PSI. 1 -RUN TBG TO 4807' MD. PUW= 80K, SOW= I 76K. 21:00 - 21:30 I 0.50 RUNCOM P RUNCMP , P/U & M!U TBG HANGER & LANDING JT. -INSTALL PENETRATORS. CHECK _L CONTINUITY. -OK. Printed 5/11/2011 10:21:59AM •rthl America - ALASKA - BP Page 5 of 5 . Operation Summary Report • Common Well Name: MPE -15 AFE No Event Type: WORKOVER (WO) , Start Date: 4/25/2011 End Date: 5/1/2011 X4- 00RFH -E (700,000.00 ) Project: Milne Point i Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/16/1995 12:00:OOAM Rig Release: 5/1/2011 ' Rig Contractor: DOYON DRILLING INC. UWI: 500292252800 Active Datum: 27:15 7/14/1998 06:00 @83.20ft (above Mean Sea Level) Date I From - To Hrs I Task I Code NPT ' NPT Depth Phase I Description of Operations 1 21:30 - 00:00 2.50 I RUNCOM P (ft) RUNCMP I TERMINATE ESP CABLE & HEAT TRACE CABLE. -R/D ESP CABLE SHEAVE. -PUMP 10 BBLS DOWN TBG 0.5 BPM / 1480 I 1 i PSI. TOTAL CLAMPS RUN: ; -(529) - 5 HEAT TRACE CANNON CLAMPS -(112) - 2' CROSS COLLAR HEAT TRACE CLAMPS. I -(25) - 2- CROSS COLLAR CANNON CLAMPS. ' -(6) - 2' HEAT TRACE CANNON CLAMPS. I -(5) -400 PUMP BODY CLAMPS. ! 5/1/2011 , 00:00 01:30 1.50 RUNCOM P RUNCMP � CO NTINUE TO SPLICE HEAT TRACE TO TBG HANGER HEAD PIN. I - -TEST CONDUCTIVITY OF ESP & HEAT TRACE I CABLES. -0K. 01:30 - 02:00 0.50 RUNCOM P RUNCMP LAND TBG HANGER. RILDS. B/O LANDING JT. 02:00 - 03:00 1.00 RUNCOM P RUNCMP , SET & TEST TWC. 250 LOW/ 5000 PSI HIGH 'PRESSURE. FROM ABOVE. ;- ROLLING TEST FROM BELOW F/ 39 BBLS. 3 BPM / 700 PSI. 1 -BOTH TESTS F/ 10 CHARTED MINUTE S . - 03:00 - 04:30 1.50 WHSUR P RUNCMP – , I PJSM. N/D BOPE. 04:30 - 07:30 3.00 WHSUR P RUNCMP N/U ADAPTOR FLANGE & TREE. -TEST ADAPTOR TO 250 PSI LOW / 5000 PSI I HIGH PRESSURE. I -CHART TEST F/ 30 MINUTES. GOOD. -CENTRILIFT REP, TAKE FINAL READING, GOOD. 1 I -Pi: 1723 PSI, Pd: 0 PSI, Tm: 66.8 deg F, Ti: 65.5 I deg F, Cz: 10.230 ma, Cf: 18.398 ma, Cla: 0.053 L I ma, Clp: 0.000 ma, Vib: 0.0 G. 07:30 - 08:30 1.00 WHSUR I P RUNCMP FILL AND TEST PRODUCTION TREE WITH ! DIESEL -250 PSI LOW / 5,000 PSI HIGH FOR 30 I _ _ CHARTED MINUTES, GOOD. 1 108:30 - 10:00 1.50 WHSUR P RUNCMP I R/U DSM LUBRICATOR ! i -TEST 250 PSI LOW / 1,500 PSI HIGH FOR 5 CHARTED MINUTES, GOOD. I -PULL TWC 1-SET BPV. ' -R/D DSM. 10:00 10:30 0.50 WHSUR P RUNCMP I TEST BPV - PERFORM A ROLLING TEST FROM BELOW 1 I AT 2.8 BPM / 600 PSI -FOR 10 CHARTED MINUTES, 42 BBLS 10:30 - 12:00 1.50 WHSUR P RUNCMP PUMPED. fi R/D TEST EQUIPMENT AND CIRCULATING LINES. I ! -CLEAN PITS I I -CLEAN AND SECURE WELL HEAD AND I CELLAR. I I ** *RIG RELEASED AT 12:00 HRS 5/1/2011 * ** RIG OFF WELL AT 15:00 HRS Printed 5/11/2011 10:21:59AM • • Tree: 2-9/16",5M Cameron M P U E15 5 • Wellhead: 11" 5M Gen 6 D F = 5 3.9' (N22E) Unibore w/ 11' x 2/78" EUE GL = 24.15' 8rd tbg. hgr., 2.5" "H" BPV RKB (N22E) to 7" Hgr. = 29.7' profile. 20" 91.1 ppf, H -40, Csg. 113' I a A Camco 2 7/8" x 1" KBMG GLM 196' MD KOP @ 400' Max Hole Angle: 47° 2600' to 3300' MD Centrilift heat trace 3450' MD 2 -7/8 ", 6.4 ppf, EUE 8rd. Tubing (cap. = 0.0058 bpf) 7 ", 26 ppf, L -80, BTC. Casing P° Camco 2 7/8" x 1" KBMG GLM 4608' and (cap. = 0.0383 bpf) (cap. w/ tbg inside = 0.02758 bpf) v7 HES 2 7/8" XN nipple 4752 'md (2.205 no -go ID) Pump - 124 -P4, model PMSXD 4763' MD Gas Separator - FPHVDIS 4777' MD IiiraW Intake TVD 4094' Tandem Seal Section 4782' MD GSB3DB UT/LT PFSA/FLAS HSN ME Casing tested to 1500 psi above r Centrilift KME -1 Motor (Re- rated) 4795' MD 4880' MD during 4/29/11 RWO. 55 HP, 1259 Volt, 26 Amp Stimulation Summary: ill PumpMate XTOw /6-lnCentralizer 4803' MD 'N' Sand 44,200 lbs. 16/20 xTOTVD 4129' 'OA" Sand 122,000 lbs. 16/20 x RA Collar at 4835' WLM RKB Perforation Summary: 4: . �_� ,,,, 7" Halliburton "VTL" Pkr 4918' and Ref. Log: DIL � .����;i��� i 05/19/95 $ ' ; +: 20 Gauge Halliburton Welded 304 SS 48.4.01 l∎'••:;:; Wire Wrapped Screen Size JSPF Interval (TVD) �. tI II ::;y 5041' and 4.5" 12 4990' -5028' (4301' - 4335') .4 � -. - 7" Halliburton "VTL" Pkr ••■•■4 . XV `i`i`i' V.! 4.5" 12 5136' -5166' (4432' - 4459') p�;NI ll�;�;�� 20 Gauge Halliburton Welded 304 SS Jumbo Jet ( "big hole ") 26 gr. charges, = ' Wire Wrapped Screen 5171' wlm � 7" x 4" bore HES "BWD" Sump Pkr. w/ 135 / 45 deg phasing, EHD - 0.74 ", 3.813" XN npl. and WLEG TTP = 5.8" 5302' and Tagged fill 9/5/95 @ 5283' wlm ■11011117■� PBT T - " 5391' and 7 Csg. Shoe DATE REV. BY MILNE POINT UNIT 09/10/95 JBF ESP Completion by N 4ES (Rev. 1) Well E - 12/26/02 MAS ESP RWO by N 4ES API NO: 50 - 029 - 22528 4/29/11 Hulme ESP RWO by Doyon 16 BP EXPLORATION (AK) ..~~~ • STATE OF ALASKA ~ ~ ~QQ~ .~/a-D~ ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL ~~~A-~ ~~°~'~''~~~'r`''n~~'~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate '~"'~"'~ Other ~ ACID TREATMENT_ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ ` v~ ~ jy > Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ • 2. Operator BP Exploration (Alaska), Inc. 4, Current Well Class: 5. Permit to Drill Number: Name: Development r' Exploratory ~~ 194-1530 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-22528-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 54 KB - MPE-15 - 8. Property Designation: 10. Field/Pool(s): ADLO-025518 - MILNE POINT Field/ SCHRADER BLFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 5410 feet Plugs (measured) 5283' TAGGED FILL true vertical 4673.49 - feet Junk (measured) None Effective Depth measured 5302 feet true vertical 4577 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 32 - 112 32 - 112 1490 470 Production 6938 7" 26# L-80 30 - 5391 30 - 4656 7240 5410 lYl~4~ ~ ~, r ht' 4tlrt t a; ~~iv`v Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.4# L-80 28' - 4742' 0 0 - Packers and SSSV (type and measured depth) NO PACKERS IN WELL 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 101 21 62 181 Subsequent to operation: 157 15 120 191 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory h Development r,- Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gash WAG GINJ h WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 3/10/2009 Form 10-404 R ised 04/2006 _ ~ 1 ~ ~ ~ ~-~ ~~i~ ~ `~ ~~~~~ n22ii 3 ~ t ~ Submit Original Only MPE-15 194-153 PFRF OTTOCHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE-15 9/10/95 PER 4,990. 5,028. 4,296.91 4,330.97 MPE-15 9/10/95 PER 5,136. 5,166. 4,427.84 4,454.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i C~ J MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE { SUMMARY 3/5/2009 T/I/0=300/220/N/A Pump acid per sequence/ Pump at .4 bpm 15 bbls 130 degree diesel/5 bbls cold diesel/13 bbls 7.5% DAD acid/3 bbls 60/40 meth to flush acid hose/ 13 bbls of diesel to displace acid to the ESP. Swab, wing closed. Ssv, Mst,l open. FWHP=390/400/N/A. FLUIDS PUMPED BBLS 3 60/40 13 7.5% DAD ACID 33 DIESEL 1 Total STATE OF ALASKA ~AY Q 9 ~~~~ S'/.~ O~ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL 0~~$ar~s. ~crnmi~siar~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q - Cck~~ther ~ ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ EXploratory 194-1530 ` 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22528-00-00 7. KB Elevation (ft): 9. Wel{ Name and Number: 54 KB ' MPE-15 8. Property Designation: 10. FieldlPool(s): ADLO-025518 ' MILNE POINT Fieldl SCHRADER SLUFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 5410 - feet Plugs (measured)1283' TAGGED FILL true vertical 4673.49 , feet Junk (measured) None Effective Depth measured 5302 feet true vertical 4577 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 50" 91.5# H-40 32' - 112' 32' - 112' 1490 470 PRODUCTION 6938' 7" 26# L-80 30' - 5391' 30' - 4656' 7240 5410 *~~~E~ MAY ~. ~ 200$ Perforation depth: Measured depth: O 4990 - 5028 O 5136 - 5166 _ _ _ True Vertical depth: 4296.91 - 4330.97 4427.84 - 4454.74 = _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.4# L-80 28' - 4742' 0 0 - Packers and SSSV (type and measured depth) NO PACKERS IN WELL 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 63 25 69 199 Subsequent to operation: 62 24 68 221 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~' Development '' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~'' GINJ ~ WINJ Via' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: N{A Contact Gary Preble Printed Name Gary Pre Y Title Data Management Engineer Signature ~ Pon 564-4944 Date 5{6{2008 Form 10-404 Revised 04(2006 E ~ ('~`° ~ a~ ~ ~~ ~ Submit Original Only t,~ '~ ~`~ (~ a- • • 4/28/2008 4/29/2008 MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY '** WELL FLOWING ON ARRIVAL'** (FLOWING SCRAPE ) RIH WI 2.11 CENT FULL SIZE SCRATCHER DOWN TO 4000 FT VERY SLOW GOING DOWN 500' TO 1780' = 20 TO 40 FPM (VERY TIGHT) 12 FPM TO 4000' SLM *'`*CONT ON 4129/08 ""' _,.. _ ~ ..._ . r. __ __ _~ . __ .... __ ~~'`*CONTINUE FROM 4128108 '~'"` TUBING SCRAPE RIH W/ FULL SCRATCHER FALLING VERY SLOW TO 4000' (20 -40 FPM) DIDN'T HAVE ANY PARAFFIN ON TOOLS RID EQUIPMENT "`*JOB COMPLETED *"* 5!1 /2008 Tl1=2501250. (ESP acid treatment). Spear into tbg w/ 5 bbls diesel for infectivity. Pump 11.3 bbls 7.5°l° DAD acid down tbg. Spot acid at ESP w/ 3 bbls 60/40 meth & 18 bbls diesel. Let Acid soak on ESP for 20 minutes. Turn well over to DSO. DSO to run ESP forward for 10 minutes against closed choke, then 5 minutes in reverse, then forward again for 5 minutes before flowing to tank. FWHP= 250/310. FLUIDS PUMPED BBLS 23 Diesel 3 60/40 METH 12 ACID 38 Total '' STATE OF ALASKA ~%~~~~ ALASKA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS ~.~_ f~G~~1U NOV ~ ~ 2007 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 . _8S ~ ~i'h~r .~ ~ ~~ ` ~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extensioh,gGi~treatment Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well ~V""OO~~~~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' EXplOratOry 194-1530 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: , Anchorage, AK 99519-6612 50-029-22528-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54 KB ~ MPE-15 ' 8. Property Designation: 10. Field/Pool(s): - ADLO-025518 MILNE POINT Field/ SCHRADER BLUFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 5410 ~ feet Plugs (measured) 5283' tagged fill true vertical 4673.49 - feet Junk (measured) None Effective Depth measured 5302 feet true vertical 4577 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 32' - 112' 32' - 112' 1490 470 Production 6938' 7" 26# L-80 30' - 5391' 30' - 4656' 7240 5410 ~~~~~~ NOV ~ ~ 2007 Perforation depth: Measured depth: 4990 - 5028 5136 - 5166 True Vertical depth: 4296.91 - 4330.97 4427.84 - 4454.74 = _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.4# L-80 28' - 4742' 0 0 - Packers and SSSV (type and measured depth) NO PACKER IN WELL 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 119 19 109 189 Subsequent to operation: 120 19 89 182 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ~`~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas i WAG ~' GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 11/9/2007 Form 10-404 Revised 04/2006 ~ ~~' y Submit Original Only 1 • • MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDAT SUMMARY E 11 /1 /2007 T/1=250/250. (Acid treatment). Spear into tbg w/ 10 bbls crude followed by 12.3 bbls 12% DAD acid. Spot acid ~ ESP w/ 6 bbls 60/40 meth & 22 bbls crude. Let soak for 20 minutes. Saw acid hit ESP @ 13 bbls away. Run ESP forward & in reverse. Pump 90 bbls crude down tbg for overdisplacement. FWHP=600/600 FLUIDS PUMPED BBLS 12.3 12% dad 6 60/40 METH 112 DEAD CRUDE 130.3 TOTAL ~ . STATE OF ALASKA I ;7~..¿)? ALASKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERA TION91aska Oil & Gas Cons. Commission o Stimulate 0 Other n I)a1)QEATMENT o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 194-1530 - o~ 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 54 KB... 8. Property Designation: ADLO-025518 - 11. Present Well Condition Summary: Total Depth measured 5410 ' feet true vertical 4673.49 feet Effective Depth measured 5302 feet true vertical 4577 feet Casing Length Size MD Conductor 80' 20" 91.5# H-40 32' - 112' Production 6938' 7" 26# L-80 30' - 5391' ! "\L..VL..I V L..LJ JUL 2 3 2007 Exploratory Service 6. API Number: 50-029-22528-00-00 / 9. Well Name and Number: MPE-15 ,,- 10. Field/Pool(s): MILNE POINT Field/ SCHRADER BLFF OIL Pool Plugs (measured) Tagged fill @ 5283' Junk (measured) None TVD 32' - 112' 30' - 4656' Burst 1490 7240 Collapse 470 5410 Perforation depth: Measured depth: 4990 - 5028 True Vertical depth: 4296.91 - 4330.97 5136 - 5166 SCAN~ED JUL 3 1 2007 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 13 49 0 13 41 0 15. Well Class after proposed work: Exploratory Development M 16. Well Status after proposed work: Oil M Gas WAG 4427.84 - 4454.74 Tubing: (size, grade, and measured depth) 2-7/8" 6.4# Packers and SSSV (type and measured depth) NO PACKERS IN WELL o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 89 98 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble L-80 28' - 4742' o o o o RBDMS 8Fl JUL 3 0 2007 Tubing pressure 178 181 Service WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Management Engineer Date 7/19/2007 Signature .1.... .... Phone 564-4944 d 04/2006 0 RIG I N A L ~/..,'-f #¥~ Submit Original Only . \ . , .. MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/14/2007 MIRU CTU#9 w 15805' 1.75" CT. RIH with 2" JSN and tag ESP at 4730'. Pumped 12 BBLs of Acid in (2 BBLs interval) and waited 15 minutes in between. PUH to 3500 and establish injectivity test. Establish injectivity at 0.7 bpm and 520 psi. Pad Operator kicked the ESP in Forward, Reverse, Forward. Taking returns to the tanks and looks good. POOH. RDMO. *** Job Completed*** FLUIDS PUMPED BBLS 12 10% HCL ACID 46 DIESEL 52 METH 100 TOTAL 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull TubingD Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Kt:l.,t:1 V ,-U . STATE OF ALASKA . -rftIJ ALA Oil AND GAS CONSERVATION COM I~Y 2 ~ -7007 REPORT OF SUNDRY WELL OPERAkliIOtJI&s Cons. Commission o Stimulate 0 .l\nchoriþJr 0 ACID TREATMENT o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 194-1530 / ~ S,.".;2~~~ ~ P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 6. API Number: 50-029-22528-00-00 - 3. Address: 9. Well Name and Number: 54 KB' MPE-15' ADLO-025518 . 11. Present Well Condition Summary: 10. Field/Pool(s): MILNE POINT Field/ SCHRADER BLFF OIL Pool - 8. Property Designation: Total Depth measured true vertical 5410 / 4673 I feet feet Plugs (measured) Tagged Fill @ 5283' (9/5/95) Junk (measured) NONE Effective Depth measured 5302 feet true vertical 4577 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 32' - 112' 32' - 112' 1490 470 Production 6938' 7" 26# L-80 30' - 5391' 30' - 4656' 7240 5410 S;G~~NED JUN 1 4 2007 Perforation depth: Measured depth: 4990 - 5028 True Vertical depth: 4296.91 - 4330.97 5136 - 5166 4427.84 - 4454.74 - - Packers and SSSV (type and measured depth) 2-7/8" 6.4# BOTTOM OF JET PUMP NO PACKERS IN WELL o o o L-80 28' - 4742' 4791' o o o o Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 89 SHUT-IN Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 13 49 0 o 0 0 15. Well Class after oroposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 178 o 13. Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ WDSPl Contact Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/22/2007 d 04/2006 U R \ G \ N A L ,¡UN 11 2007 Submit Original Only . . MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/16/2007 T /1=500/500. (Acid treatment). pump 10 bbls crude down tbg for injectivity test. Pump 13 bbls 15% DAD acid followed by 3 bbls 60/40 meth & 14 bbls crude to spot acid at ESP. Load 90 bbls produced water. Pump 90 bbls produced water down tbg to displace acid into perfs. Freeze protect tbg w/ 19 bbls crude. FWHP=200/550. 5/17/2007 ***WELL ON (POST ACID) SET DPSOV IN TOP STATION @167'MD 144' SLM, SET DUMMY IN BOTTOM STATION @4584'MD 4572' SLM ***WELL LEFT S/I*** 5/18/2007 T/I=250/250. (Injectivity test). Pump 8.5 bbls down tbg for injectivity test. Tbg pressured up after 7 bbls. Continue pumping to pump acid out of ESP. FWHP=1000/250 5/18/2007 00/150 Pump 4 bbls meth down tbg. FWHP's=300/150 FLUIDS PUMPED BBLS I 9 60/40 METH 9 TOTAL . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COM~SION nCT () 4 Z006 REPORT OF SUNDRY WELL OPERA TIQA4~í¡ & Gas Cons. Commissíon RECEIVED 1. Operations Performed: Anchoraf:5 AbandonD Repair WellO PluQ PerforationsD Stimulate 00 Other Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 194-1530 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-22528-00-00 7. KB Elevation (ft): 9. Well Name and Number: 53.90 MPE-15 8. Property Designation: 10. Field/Pool(s): ADL-025518 Milne Point Unit 1 Schrader Bluff Sand 11. Present Well Condition Summary: Total Depth measured 5410 feet true vertical 4673.0 feet Plugs (measured) Tagged Fill @ 5283 (09/05/1995) Effective Depth measured 5302 feet Junk (measured) None true vertical 4577.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5 H-40 32 . 112 32.0 - 112.0 1490 470 PRODUCTION 6938 7" 26# L-80 30 - 5391 30.0 - 4656.0 7240 5410 Perforation depth: '-' (-, f%, ~;~\ f,j ';':: if ' \J·~,rtj ',,'; '.J~'.~) Measured depth: 4990-5028,5136-5166 True vertical depth: 4301-4335, 4432-4459 Tubing ( size, grade, and measured depth): 2-7/8" 6.4# L-80 @ 28 - 4742 Bottom of Jet Pump " ,@ 4791 Packers & SSSV (type & measured depth): No Packer in well. No SSSV in well. 12. Stimulation or cement squeeze summary: RBDMS 8Ft OC1 () 4 20D8 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv AveraQe Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 26 0 --- 181 Subsequent to operation: 133 40 0 --- 185 14. Attachments: 15. Well Class after proposed work: ExploratoryO DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ 2S; OilŒ] GasO WAG 0 G1NJO W1NJO WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. J hereby certify that the foregoing is true and correct to the best of my knowledge. ¡SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature .AJ;£, ~ .. ¿;f? ,JI. f/ Phone 564-5174 Date 9/29/06 Form 10-404 Revised 4/2004 0 R \ G \ N A L . . MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/04/2006 CTU#6,Spot Acid; Spot Equipment. MIRU. Order Diesel and Acid Transport. PT surface lines and lubricator. RIH wI 2.1" JSN. Tag Pump Top at 4741' ctmd. PJSM for pumping Acid. Flood lines and pump 5 bbls diesel, 12 bbls 7.5% HCL Acid, and 34.8 bbls diesel. Displace acid through pump in 2 bbls increments. Let acid soak at for 10 mins and repeat. PUH above all acid and displace the remainder of the acid through the pump. Final inj 0.7 bpm at 2300 psig. Let soak. Operator attempt to start pump without success. RIH and thump on pump 3x's and start up pump. Decision made by MP Operations to overdisplace acid into formation wI 100 bbls 1 % KCL. POOH to surface. Finish over-displacing acid wI 100 bbls. Start pump and produce down flowline. *** Job Complete *** 07/10/2006 T/l/O=1 00/1 00 Acid Treatment Attempt. Pumped 8.5 bbls crude down tbg by pressuring up tbg and letting pressure bleed off. Tbg was taking @ 1 bbl=20 min. ESP acid job cancelled. Final WHP=1 00/1 00 07109/2006 Load fluids for upcoming job. BBLS 56 Diesel 109 1 % KCL Water 12 7.5% Acid 177 TOTAL FLUIDS PUMPED Page 1 Tree: 2-9/16",5M Cameron Wellhead: 11" 5M Gen 6 Unibore wI 11' x 2/78" EUE 8rd tbg. hng., 2.5" "H" BPV profile. Actuator: 20" 91.1 ppf H-40 ~ csg. KOP @ 400' Max Hole Angle: 41' 2600' to 3300' MO 2-7/8", 6.4 ppf, EUE 8rd. tbg. (cap. = 0.0058 bpf) No. 1 ESP Cable 7", 26ppf, L·80 BTRC. Stimulation Summary: 'N' Sand 44,200 Ibs. 16/20 'OA" Sand 122,000 Ibs. 16/20 Perforation Summary: Ref. Log: OIL 05/19/9 Size SPF Interval (TVO) 4.5" 12 4990'-5028' (4301' - 4335') 4.5" 12 5136'·5166' (4432' - 4459') Jumbo Jet ("big hole") 26 gr. charges, 135/45 deg phasing, EHO = 0.74", TTP = 5.8" Tagged fill 9/595 @ 5283' wlm DATE 09/10/95 12/26/02 EV.BY JBF MAS ESP Completion by N 4ES (Rev. 1) ESP RWO by N 4ES MILNE POINT UNIT Well E-15 API NO: 50-029-22528 MPU E-15 OF = 53.9' (N22E) GL = 24.15' RKB (N22E) to 7" Hng. = 29.7' Cameo 27/8" x 1" KBMG GLM 1167' MD I Centrilift heat trace I 3450' MD I Cameo 27/8" x 1" I 4584' md I KBMG GLM . . 2-7/8" XN-Nipple I 4726 'md I (2.205" No-go 10) . . FC925 ESP 4" 00 14742' MD I 214 stages, FPMTARM 1:2 8 FCNPSH stages, FPMTAR 1:1 ~ Intake TVD ~ Tandem Gas Separator 4" 00 14764' MO I FPINTAR .. Tandem Seal Section 5.13" 00 14765' MO I GSB3DBUT/L TILH6PFSAFLAS/HSN Centrilíft KME-1 Motor 5.62" OD 14779' MO I 82 HP, 1230 Volt, 35 Amp (Re-rated) . . Centrilift PHD'M6t1 Cer1råza' 14791' MD I RA Collar at 4835' WLM RKB 7" Halliburton "VTL" Pkr I 4918' md I 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen I 5041' md I 7" Halliburton "VTL" Pkr 20 Gauge Halliburton Welded 304 SS Wire Wrapped Screen 15171' wlm I 7" x 4" bore HES "BWO" Sump Pkr. wi 3.813" XN npl. and WLEG I 5302' md I 15391' md I BP EXPLORATION AK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 54' 3. Address ri Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3567' NSL, 1900' WEL, SEC. 25, T13N, R10E, UM X= 569246, Y=6016105 MPE-15 At top of productive interval 9. Permit Number / Approval No. -~ 194-153 3028' NSL, 3925' WEL, SEC. 25, T13N, R10E, UM x = 567226, Y = 6015547 10. APl Number At effective depth ~.x. J 50-029-22528-00 2989' NSL, 4057' WEL, SEC. 25, T13N, R10E, UM x=567o94, Y=6O155o7 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 2975' NSL, 4103' WEL, SEC. 25, T13N, R10E, UM x--567049, Y =6015493 12. Present well condition summary Total depth: measured 5410 feet Plugs (measured) true vertical 4673 feet Effective depth: measured 5302 feet Junk (measured) true vertical 4577 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5361' 7" 800 sx PF 'E', 300 sx Trinity Lite 5391' 4656' Intermediate Production Liner R CEIVED Perforation depth: measured 4990' - 5028', 5136' - 5166' 8 2003 true vertical 4297' - 4331', 4428' - 4455' Alaska 0ii & Gas Co~s. C0~mtJssi0r~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 4793'. Anchorage Packers and SSSV (type and measured depth) Screen Assembly - 7" VTL Packers at 4918' and 5041' and a 7" x 4" HES 'BWD' Sump packer with leg at 5171' 13. Stimulation or cement squeeze summary Intervals treated (measured) ,SCANNED FEB 0 4 2003 Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17.1 hereby ce~i~f.~~~rrect to the best of my kh-owledge Si.(:lned S~dra Stewm_~.l~..~tle~ ~-~" ~ ~-~'~--~ Technical Assistant Date O I' Z "7 - 0 3 Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 R !] I~N$ II F I. ~ JA[~ 2 8 "' ?~_} Submit In Duplicate BP EXPLORATION Page,1 of 2 Operations Summary Report Legal Well Name: MPE-15 Common Well Name: MPE-15 Spud Date: 5/16/1995 Event Name: WORKOVER Start: 12/23/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2002 Rig Name: NABORS 4ES Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 12/22/2002 06:00 - 07:30 1.50 MOB P PRE RDMO MPG-04.- SCOPE / LOWER DERRICK 07:30 - 10:00 2.50 MOB P PRE MOVE CAMP, SHOP, SUB, PITS, PIPE SHED. 10:00 - 12:30 2 50 RIGU P PRE LAY HERCULITE AND MATS, SPOT SUB, PITS, PIPE SHED, CAMP. 12:30 - 14:00 1.50 RIGU P PRE RAISE / SCOPE DERRICK - ACCEPT RIG 14:00-15'00 1.00 RIGU P DECOMP SET AND RU LINES TO TIGER TANK,TEST TO 2500 PSI. RECEIVE SEAWATER IN PITS 15:00 - 16.00 1.00 RIGU P DECOMP PU LUB, PULL BPV 16:00 - 20'00 4.00 RIGU P DECOMP RU LINES TO TREE TO KILL WELL, TEST TO 2500 PSI. INITIAL PRES - TBG 1350 / IA 1350 BLEED TBG / IA TO ~50 PSI TO TT. 20:00 - 21:30 1.50 KILL P DECOMP PUMP SEAWATER TO KILL WELL PUMP 245 BBL 140 DEG. SW DOWN TBG WITH 50 BBLS CRUDE RETURNS TO TT. SD PUMPS. 21:30 - 22:00 0.50i KILL P DECOMP MONITOR WELL - TBG 0 / IA 100 22:00 - 23'00 1.00' KILL P DECOMP BULLHEAD 150 BBL SW DOWN IA TO KILL WELL AND CLEAN TBG.MONITOR WELL - TBG O / IA 0 23:00 - 23:30 0.50 KILL P DECOMP MONITOR WELL - TBG 0 / IA O 23'30-00:00 0.50 KILL P DECOMP SET AND TEST TWC -1000 PSI 12/23/2002 00'00 - 00:30 0.50 BOPSUF P DECOMP SET AND TEST TWC - 1000 PSI 00.30 - 02:00 1.50 BOPSUF P DECOMP ND TREE 02:00- 04:30 2.50 BOPSUF P DECOMP NU BOPE 04:30 - 09:00 4.50 BOPSUF P DECOMP TEST BOPE TO BP / AOGCC PROCEDURES 250 / 3500PSI. GOOD TEST.- WITNESS OF TEST WAIVED BY AOGCC INSP. J. SPAULDING. 09:00 - 10.00 1.00 BOPSUF P DECOMP DRAIN STACK. PU LUB PULL TWC 10:00 - 10:30 0 50 PULL P !DECOMP MU LANDING JT, BACK OUT LDS, PULL HGR TO FLOOR. UPWT 43 K. 10:30 - 11:00 0.50 PULL P DECOMP RU DRAIN HOSE FOR CABLES. TIE HEAT TRACE AND CABLE TO SPOOLING UNIT 11:00-14'00 3.00 PULL P DECOMP TOH-LDTBGANDSPOOLCABLE/HEATTRACE 14:00 - 16:30 2.50 PULL P DECOMP CONT TOH WITH TBG AND CABLE. 16:30 - 18'00 1.50 PULL P DECOMP DISCONNECT CABLE, INSPECT PUMP-OK - LOST 42 BANDS IN HOLE. 18.00 - 19:30 1.50 PULL P DECOMP CLEAR / CLEAN FLOOR OF ESP PULLING EQUIP. RU TO PU 2 7/8 TBG 19:30 - 20:00 0.50 RUNCOI~ 33 COMP MU 6" BIT ON TBG FOR DRIFT RUN. 20:00 - 00:00 4.00 RUNCOI~ 33 COMP PU TBG AND TIH FOR DRIFT RUN TO 4860' NO OBSTRUCTIONS ON TIH. 12/24/2002 00:00 - 04:00 4.00 CLEAN P DECOMP Stop drift run wi6" bit at 4,860-ft (end of ESP completion to be at 4,793-ft). TOOH with 2/78" tbg standing back in derrick. 04:00 - 04:30 0.50 CLEAN P DECOMP LD bit. CC floor. 04'30 - 06'00 1.50 RUNCOI~ 33 COMP RU to run ESP completion. Start to pu and service ESP assy. 06:00 - 07:30 1 50 RUNCOr~33 COMP Crew change PJSM. Complete service of ESP assy, plug in MLE and secure. 07:30 - 08:00 0.50 RUNCOr~ 33 COMP TIH with new 2 7/8 tbg and ESP assy to 1340' 08:00 - 09:00 1.00 RUNCOI~ 33 COMP RU to run Heat Trace 09:00 - 18:30 9.50 RUNCOI~ ~ COMP Cont. TIH with ESP / Heat Trace assy. - Used 587 Flat Guards -25 LaSalle Clamps - 1786 Bands. 18:30 - 19:30 1.00 RUNCOr~ 33 COMP PJSM-MU landing jr, PU FMC hgr, install penitrators 19:30 - 22'30 3.00 RUNCOI~33 COMP Splice cable and land hgr. 22.30 - 23:00 0.50 RUNCOI~ 33 COMP PU Lub,Set/test 'rwc 2500 psi, run in LDS, Pnnted 12/26/2002 10.1~,23AM SCANNED FEB 0 4 20D3 BP EXPLORATION Page 2 of 2 Operations Summary Repo Legal Well Name: MPE-15 Common Well Name: MPE-15 Spud Date: 5/16/1995 Event Name: WORKOVER Start: 12/23/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2002 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/24/2002 23'00 - 00.00 1 00 BOPSUF:P COMP PJSM-ND BOPE 12/25/2002 00:00 - 01:30 1.50 BOPSUF:P COMP iComplete ND BOPE. 01'30 - 03:30 2.00 WHSUR P COMP PJSM. NU Production Tree. Test to 5,000 psi. Good. 03:30 - 05:00 1.50 WHSUR P COMP PU lubricator. Pull TVVC. Install BPV. LD lubricator. 05:00 - 06:00 1.00 RIGD P COMP Clean Rig pits. Blowdown lines. Secure well and cellar. Rig released 06:00 hrs. Begin to RD. Fesco to FP well after Derrick ~s layed over. SCANNED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ SCALE INHIBITION Pu~l tubing _ Alter casing _ Repair well_ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 1712' FNL, 1900' FEL, Sec. 25, T13N, R10E, UM At top of productive interval 3029' FSL, 3925' FEL, Sec. 25, T13N, R10E, UM At effective depth 2289' FNL, 1222' FWL, Sec. 25, T13N, R10E, UM At total depth 2303' FNL, 1176' FWL, Sec. 25, T13N, R10E, UM 5. Type of Well: Development __X Exploratory_ Stratigraphic._ Service._ (asp's 569246, 6016105) (asp's ri~a) (asp's 567094, 6015508) (asp's 567049, 6015493) 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Miline Point Unit MPE-15 9. Permit number / approval number 194-153 10. APl number 50-029-22528 11. Field / Pool Miline Point Unit / Schrader Bluff Sands 12. Present well condition summary Total depth: measured true vertical 5410 feet Plugs (measured) 4673 feet Effective depth: measured 5302 feet Junk (measured) true vertical 4577 feet Tagged Fill @ 5283' (09/05/1995) Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arcticset I (approx) 144' 144' Production 5361' 7" 800 SX pf 'E'/ 300 SX 5391' 4656' Trinity Lite Perforation depth: measured Open Perfs 4990'- 5028', 5136'- 5166'--- Gravel Pack Completion. true vertical Open Perfs 4301' - 4335', 4432' - 4459' Tubing (size, grade, and measured depth) 2-7/8", 6.4 ppf, L-80 tubing to 4748'. Packers & SSSV (type & measured depth) 7" Halliburton 'VTL' PKR's @ 4918' & 5041'; 7" x4" Bore HES 'BWD' Sump PKR @ 5171'. 2-7/8" x 1" Camco side pocket KBMM GLM @ 127'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 09/05/2001 126 Subsequent to operation 09/14/2001 148 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 58.5 77 38.4 61 Casing Pressure Tubing Pressure 174 175 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~~ ~'~,_~~ Title: Technical Assistant DeWayne R. Schn'~rr ~,. ORIGINAL Form 10-404 Rev 06/15/88 · Date September 19, 2001 Prepared by DeWa)me R. Schnorr 564-5174 SUBMIT IN DUPLIC~, MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/06/2001 ACIDIZE ESP EVENT SUMMARY 07/06/01 ACIDIZE ESP THROUGH THE INNER ANNULUS. HB&R AND DOWELL RIGGED UP TO THE IA AND PRESSURETESTED TO 3500 PSI. HELD PJSM. ADJUSTED CHOKE TO HOLD 500 PSI ON TUBING THROUGHOUT PUMPING OPERATION. PUMPED I BBL DIESEL TO VERIFY WE COULD PUMP DOWN IA. PUMPED 18 BBLS OF 5% DAD ACID, PUMPED AT 1.5 BPM AT 2500 PSI. PUMPED 5 BBLS DIESEL, PUMPED AT 1.8 BPM AT 2500 PSI. JOB WAS COMPLETED WITH NO PROBLEMS. FLUIDS PUMPED 6 DIESEL 18 5% DAD ACID 24 TOTAL Page 1 01'4 OR BEFORE c ..LOi~ixMI: ILM -I:~0 C P E R N I T 94 .... 153 9a. ~-- 153 AOG(;C Ind'iv"¥duai b/e11 6.---;ol og'~'cal Piai:er"'i'ai s ..[r~ven'~or'.y ' ~" )""'":-'.'-,-.¢ i"¢i) "L6 ?:, '7-i/ & DATA T DATA ...... ............................................................... BHP -'IL L~565 .... ~* ....... :.~ '79 DIFL./F'ROX/GR/SP ,:,E: a. 565~'-5379 94 .... 153 SSTVD ~¢.L/4565-~5379 9~.~i53 ZDL/CNL/GR/CAL. ~¢J:.: 4565--5325 9h.--'i53 GR/CCL~ PERF REC ..-L. .. 4820-~5°48 GR/CCL F'ERF 1 0 -~-'4 [.)7 DAZ[..Y WELL ODS REC ~.J.~:4796 .... 5012 R U N E, A'F F:. ..... R E ,::: V D · ~ o 6 / o i / 9 s 'i 06 / 0 'i/"' 95 .J I 06/01/"9!5 1 09/1/~,./95 i 09 / 28 / 95 !., /',/r 7 / "! b/' 0 / // /; :/';, ..,, t" '/ i'10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI=COMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number BP Exploration (Alaska) Inc. 94-153 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22528 4. Location of well at surface 9. Unit or Lease Name 3567'NSL'1900'WEL'SEC'25'T13N'R10E~CO;"'~'":~-~j..: .,,P,~,TE)" ~ "~: i' ~~M/InePointUnit' '- ~ 10. Well Number At Top Producing Interval i ~'~// ~ ! t;~ ~ ~ MPE- 15 3029'At TotalNSL'Depth3925' WEL, SEC. 25, T13N, RIOE ~ '~--'~-?J VJ~RJ¢JED~!~.~~_~~~ ~j , 11. Field and Pool ~ ~'.~ ' ~ Mi/ne Point Unit/Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 53.9' ADL 025518 12. Date Spudded 13. DateT. D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 05/16/95 05/21/95 09/12/95I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 5410' MD/4673' TVD 5302' MD/4577' TVD YES [] NO []I N/A feet MDI 1800' (Approx.) 22. Type Electric or Other Legs Run GR/RES/NEU/DEN, SBL .. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.4# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 5391' 8-1/2" 8oo sx PF "E"/300 sx T#nity Lite 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 12 spf 2-7/8" 4790' N/A MD 7-VD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4990'-5028' 4297'-4331' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5136'-5166' 4428'-4455' Freeze protected wi90 bbls diesel Frac-pac 4990'-5028' 'N' Sand w/44200# 16/20 Carbolite Frac-pac 5136'-5166' 'CA' Sand w/108000# 16/20 Carbofite 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 05/17/96 ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD ~ .. I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE z9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Schrader Bluff 4963' 4219' N Sands 4991' 4244' OA Sands 5137' 4374' .. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __ ' Title Senior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production .from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU E-15 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/16/95 02:00 SPUD: RELEASE: 05/23/95 01:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: NABORS 4ES 05/16/95 ( 1) TD: 112'( 0) 05/17/95 ( 2) TD: 1298' (1186) 05/18/95 ( 3) TD: 3762' (2464) 05/19/95 ( 4) TD: 5150' (1388) 05/20/95 (5) TD: 5375' ( 225) LOADING BHA IN PIPE SHED MW: 0.0 VIS: 0 MOVE RIG FROM MP E-13 TO MP E-15. HOOK UP WATER, ELECTRICAL AND STEAM LINES. TAKE ON WATER IN MUD PITS. NU AND MODIFY RISER. LOAD AND STRAP BHA. DRILLING MW: 0.0 VIS: 0 FINISH NU RISER AND FLOWLINE. FINISH BUILDING BERMS AROUND CUTTINGS TANK, MUD ROOM, CENTRIFUGAL ROOM, AND LAY INJECTION LINE TO MP E-Il. PU 81 JTS "E" DP AND 27 JTS HWDP AND STAND BACK DERRICK. FUNCTION TEST 20" DIVERTER. MU 9 7/8" BIT AND BHA %1. ORIENT AND TEST MWD. SPUD @ 112' AND DRILL/SLIDE TO 1298' SHORT TRIP MW: 0.0 VIS: 0 DRLG AND MWD SURVEY F/ 1298 - 2057'. SHORT TRIP 10 STDS, NO PROBLEMS. DRLG AND MWD SURVEY F/ 2057 - 3762'. CBU. PUMP PILL. POH TO HWDP. PUMP OUT OF HOLE F/ 2615 - 2000' DUE TO SWABBING. RIH. HOLE TIGHT AT 2100' WASH AND REAM F/ 2100 - 2300' RIH TO 2720' DRILLING MW: 0.0 VIS: 0 WORK THROUGH TIGHT HOLE F/ 2720 - 2785'. RIH TO 3762'_ NO PROBLEMS. CBU. PUMP SWEEPS. DRLG AND MWD SURVEY F/ 3762 - 4703'. ERATIC TORQUE LAST 50'_ PUMP SWEEPS. CBU. POH TO 1950' PUMP OUT FROM 2500 - 2400' DUE TO SWABBING. NO TIGHT HOLE. PUMP PILL. POH. NO PROBLEMS. CHANGE BIT. CLEAR FLOOR. ORIENT TOOLS. RIH SLOW. WORK THROUGH TIGHT HOLE F/ 2300 - 2700' RIH TO TD. NO FILL. HOLE CONDITIONS ARE IMPOROVING. DRLG AND MWD SURVEY F/ 4703 - 5150' RU SCHLUMBERGER MW: 0.0 VIS: 0 DRLG AND MWD SURVEY F/ 5150 - 5375' PUMP SWEEP. CBU. DROP EMS TOOL. PUMP PILL. POH TO HWDP. FISH EMS. RIH TO TD. NO PROBLEMS. CIRC AND CONDITION MUD. MONITOR WELL AND PUMP PILL. POH. LD MWD AND MOTOR. NO PROBLEMS. CLEAR FLOOR. RU ATLAS. RUN DIF/MLL/GR/CHD/TESMP LOG. RD ATLAS. RU SCHLUMBERGER. WELL : MPU E-15 OPERATION: RIG : NABORS 22E PAGE: 2 05/21/95 ( 6) TD: 5375'( 0) 05/22/95 ( 7) TD: 5410' ( 35) 05/23/95 (8) TD: 5410' ( 0) 05/24/95 ( 9) TD: 5410' ( 0) 09/04/95 (10) TD: 5392 PB: 5302 RUN SCHLUMBERGER MW: 0.0 VIS: 0 MU SCHLUMBERGER MDT TOOL STRING. RIH TO 2000'. CIRC AND CONDITION MUD. RIH TO 4700'. CIRC AND CONDITION MUD. INSTALL SIDE DOOR ENTRY SUB. LOG F/ 4700 - 5305'. TEST 5225', 5230', 5264', 5152', 5179', 5172', 5060', AND 5003'. NO HOLE PROBLEMS. LD BHA MW: 0.0 VIS: 0 FINISH MDT. NO PROBLEMS. POH TO SIDE DOOR ENTRY SUB @ 4700'. POH W. WL. RD SAME. CIRC AND COND MUD. MONITOR WELL AND PUMP PILL. POH. NO PROBLEMS. LD SCHLUMBERGER MDT TOOLS. RETRIEVE SAMPLES F/ TOOLS. CLEAR FLOOR. PU BHA ~3. RIH TO 5375' NO PROBLEMS. FILL DP EVEY 25 STDS. DRILL F. 5375 - 5410' PREP TO INSTALL CSG HEAD MW: 0.0 VIS: 0 CLEAR FLOOR. RU TO TUN 7" CSG. RIH W/ 128 JTS 7" 26# L-80 BTC CSG. WASH THROUGH LEDGE AT 880'. INSTALL DOUGHNUT HANGER. LAND CSG W/ SHOE AT 5391' MU CEMENT HEAD. CIRC AND COND MUD. INCREASE PUMP RATE SLOWLY UNTIL 14 BPM OBTAINED. NO MUD LOSS. CIRC WHILE INJECTING EXCESS MUD. FLUSH OUT PUMPS AND LINE W/ SOURCE WATER. RU HALLIBURTON. PUMP 10 BBLS H20. TEST LINES. PUMP 65 BBLS H20, 800 SX LEAD CEMENT, 300 SX TAIL CEMENT AND 75 BBLS DIESEL. DISPLACED W/ SOURCE WATER. BUMP PLUG. CHECK FLOATS, OK. TEST CSG. ND AND PU DIVERTER. BREAK LANDING JT. SET DIVERTER DOWN. BACK OUT AND LD LANDING JT. SET BACK DIVERTER. PERFORM 150 SK TOP JOB. RD CSG EQUIP. PULL MOUSE HOLE. PREP TO INSTALL HEAD. RELEASE RIG MW: 0.0 VIS: 0 CLEAN AND INSPECT 7" BTC WELL HEAD CONNECTION. BAKER-LOK THREADS TORQUE HEAD. NU ADAPTER FLANGE, 6 3/8" VALVE AND TREE CAP. TEST TREE AND 7" CSG, OK. FINISH CLEANING PITS. INJECT ALL FLUIDS. FREEZE PROTECT E-11 ANNULUS W/ 90 BBLS DIESEL. RELEASE RIG @ 1300 HRS ON 05/23/95. NU BOPE MW: 0.0 MOVE RIG. ND DRY HOLE TREE. NU BOPE AND INSTALL SHEAR RAM BODY. WELL : MPU E-15 OPERATION: RIG : NABORS 4ES PAGE: 3 09/05/95 (11) TD: 5392 PB: 5287 09/06/95 (12) TD: 5392 PB: 5287 09/07/95 (13) TD: 5392 PB: 5287 09/08/95 (14) TD: 5392 PB: 5287 REV CIRC MW: 0.0 NU BOP & ACCEPT RIG @ 0900 HRS.,09/04/95. NU BOPE. INSTALL 3.5 PIPE RAMS & SHEAR RAMS. INSTALL TEST PLUG & TEST BOPE. RIG DN & ATTEMPT PULL TEST PLUG, PLUG STOCK, PULLED FREE W/153K. INSTALL WEAR RING. PU BHA 91 & RIH WITH 3.5,9.3# NSCT WORKSTRING T/2000' (DRIFT WORKSTRING). DISPL & CIRC OUT 75 BBLS OF DSL W/8.6 PPG BRINE. RIH WITH WORK STRING TO PBTD @ 5287'. CIRCULATE. TEST 7" 26# CASING T/4500 PSI. REV CIRC @ 6 BPM. RD ATLAS MW: 0.0 REV CIRC. DIRT MAGNET SWEEPS & COND HOLE FLUID TO 50 NTU, 81 DEG F. SLIP & CUT 42' DRILLING LINE. POOH & LD BHA. ND FLOWLINE & RISER. NU PERF FLG. RU ATLAS & TEST LUB T/1000 PSI. RUN 91. RIH WITH GR/CCL-30' GUN 12 SPF. MISFIRE. POOH. REPAIR GUN & RUN 92-PERF F/5136' T/5166'. POOH. RUN 93. RIH WITH 6" GR & JB 70 5220. POOH. RECOVER RUBBER & METAL PIECES. RUN #4. RERUN JB T/5220'. POOH. RECOVER METAL CUTTINGS. RUN #5. RERUN JB T/5220'. POOH. CLEAN RUN. RUN #6. MU & RIH WITH BWD SUMP PKR. GR/CCL & SET SUMP PKR @ 5171'. RD ATLAS. POOH W/ FRAC TOOLS MW: 0.0 CONT TO RD ATLAS. ND FLG & NU FLOW NIPPLE. HOWCO & RIG TO RU FRAC PAC ASSY. TIH WITH FRAC PAC ASSY. TAG @ 5174' 4ES KB. SPACE OUT PUP JTS & DROP 2-1/8" BALLS & SET PKR @ 5040' & TEST PKR T/2000 PSI. ATTEMPT TO REV OUT BALL. SHEAR BALL @ 2800 PSI. RU BJ. TEST LINES T/60009 & PICKLE STRING WITH ACID & REVERSE TO SLOP TANK. PERFORM DATA FRAC. FRAC PAC AS DATA DESIGN. PUMPED TOTAL OF 1280009 16/20. NOT SUCCESSFUL IN GETTING SCREEN TO PAC. SCREEN WAS STRESSED SEVERAL TIMES, BUT BROKE BACK EACH TIME. REV CIRC & 4 BPM REV APP 20000% SAMD PUMPED OUT. MONITOR WELL & RIG DOWN BJ EQUIP. HOLE LOADED WITH 10.2 PPG. POOH & WELL STARTED TAKING APP 20 BPH. WELL EVALUATE THE FRAC PAC TOOL WHEN ON SURFACE TO DETERMINE POSSIBLE PROBLEM. SET HOWCO PLUG MW: 0.0 CIRC & CUT BRINE WT TO 9.6 TO PREVENT LOSS. TOH WITH HOWCO FRAC PAC TOOL. FOUND TOOL WAS FLUID & SOLIDS CUT VERY SEVERLY. TIH WITH 2-1/16" STINGER. STING INTO PACKER & SCREEN ASSY & REVERSE XANVIS PILL AROUND TO CLEAN SAND. TOH. MU FRAC PACK TOOL & RIH. STING INTO PACKER & SCREEN ASSY & PRESSURE UP T/1500 PSI WITH APP 3/4 BBL OF FLUID PUMPED. STRESS SCREEN SEVERAL TIMES. POOH & LD TOOL. MU JP PLUG & RIH WITH SAME. WELL : MPU E-15 OPERATION: RIG : NABORS 4ES PAGE: 4 09/09/95 (15) TD: 5392 PB: 5392 09/10/95 (16) TD: 5392 PB: 5392 09/11/95 (17) TD: 5392 PB: 5392 09/12/95 (18) TD: 5392 PB: 5392 09/13/95 (19) TD: 5392 PB: 5392 RIH W/HOWCO FRAC-PAC TOOL MW: 0.0 SET JP PLUG IN PACKER @ 5043'. TEST PLUG T/3000 PSI & DUMP 100# SAND ON SAME. POOH WITH SETTING TOOL. ND FLOW NIPPLE & NU FLANGE. CHANGE VALVE ON WELLHEAD. RIG ATLAS & TEST LUB T/1000 PSI. TEST ANNULUS VALVE T/3000 PSI. RUN #1 PERF 12 SPF 4990'-5010'. POOH & RD ATLAS. RD FLANGE & NU FLOW NIPPLE. RIH WITH JP RETRIEVING TOOL. WASH SAND FROM PLUG & PULL SAME. POOH. MAKE UP FRAC-PAC TOOLS & REPLACE SEALS ON SAME. RIH WITH FRAC-PACK TOOL. POH W/BALL, ROD & RD CAMCO MW: 0.0 CONT TIH WITH FRAC-PAC ASSY & STING INTO VTL PACKER @ 5040.56'. RIG CAMCO WIRELINE & TEST TO LUBRICATOR T/3500 PSI & RIH WITH SETTIN BALL & ROD & SET VTL PACKER @ 4922.62' W/3500 PSI. TEST ANNULUS T/3000 PSI. OK. POOH & RD CAMCO. RIG UP BJ & TEST LINE T/6000 PSI. ATTEMPT TO PUT FRAC TOOL INTO REVERSE POSITION. DID NOT SEE CORRECT OVERPULL REQUIRED TO SHEAR TOOL. DETERMINED THAT HAD PROABLED TOOL. POOH. CUT DRILLING LINE. CONT POOH. PACKER STILL ATTACHED TO FRAC-PAC TOOL PACKER. HAD BEEN SET. DETERMINE FAILURE. WAIT ON PACKER. (HOWCO REDRESSED PACKER FROM PREVIOUS JOB). MU FRAC-PAC ASSY & RIH WITH SAME ENGAGE SEALS INTO PACKER @ 5040.56'. RIG CAMCO. SET BALL & PACKER T/3000 PSI. OK PACKER @ 4922.62' RU TO RUN ESP ASSY MW: 0.0 TEST ANNULUS T/3000 PSI. EXPELL ANNULUS BALL W/2600 PSI. RELEASE RUNNING TOOL FROM PACKER W/45K OVER. RIG BJ & TEST LINES T/6000 PSI. PERFORM DATA FRAC WAIT FOR FINAL FRAC PROC. FRAC WELL W/57000% OF PROPPANT OF WHICH 44200# ENDED UP BEHING PIPE. SCREENED OUT STRESSED & RESTRESSED SEVERAL TIMES T/1800 PSI & REVERSE OUT EXCESS SAND. RD BJ & RESTRESSED SCREEN TO 1800 PSI. CIRC WELL BORE & MONITOR FOR LOSS OR GAIN. STABLE. POOH. LD 14 JTS TUBING. WELL BORE BEGIN TAKING FLUID. ADJUST BRINE WT TO PREVENT MAJOR LOSS. POOH LAYING DOWN TUBING. MU HANGER & PENETRATORS & MAKE DUMMY RUN. OK. SET TEST PLUG & CHANGE RAMS & TEST T/5000 PSI. MU ESP. SPLICE ESP CABLE @ HANGER MW: 0.0 MU & SERVICE ESP. RIH W/ ESP COMP. RU TO BEGIN INSTALLING RAYCHEM HEAT TRACE TAPE. CONT RIH W/ ESP COMP (149 JTS, 2-7/8" 6.5% L80 8RD EUE TBG). MU HANGER & PENETRATORS & SPACE OUT HEAT TRACE TAPE & SPLICE ESP CABLE. RIG MOVE TO MPL-12 MW: 0.0 SPLICE ESP & LAND TBG. RILDS & SET TWC. ND BOP'S. NU TREE & TEST SAME T/5000 PSI. MAKE FINAL CHECK ON HEAT TAPE & ESP. PULL TWC & SET BPV. FREEZE PROTECT TUBING & ANNULUS. SECURE TREE & CELLAR & CLEAN PITS. *********** sU~,JEY ANALYSIS *~***** COMPANY BP WELL H~E ~PE-15 ~OCATION 1 MIL~ POINT LOCATION 2 ALASKA DATE: 19-MAY-gS APl# -5002994040-00 NA~NETIC DECLI~qTION 28.73 ,lOB ~ 36175 GRID CONVERGENCE ANGLE WELL NUMBER 15 RECEIVED AU~ ~ g F'A~E .2', MF'E-15 SURL.~'Y AI~L¥SIS fi: ft INC CHG CUMINC CHG I RATE AZM C~ CUMAZM CHG ~eq. deq./lOOft ~eg deg. TURN RATE -- deq_/100fi: CLOSLIR£ TOOL FACE BLS I)LSRT ft d. eq. de.q/lOOft deg/lOOft**2 112,0 112,00 0.00 0,00 0,00 0.00 0.00 0.00 174,4 174.37 0.82 0,82 1.32 203,32 203.~ 326.00 259,2 257,19 0,24 1,06 0.28 13,97 217,29 16,46 350.2 ~0,21 0,15 1,21 0.16 -2,32 214,97 -2,55 440,6 440,51 0,22 1.43 0,24 2,53 217,50 2,80 0.00 0.00 0.00 0o00 0.36 0,00 1.32 2,12 1,34 51.30 .0.~? 1,10 2.51 21.51 0.17 0,24 0,00 0,00 0,26 0,09 529.2 529.~ 0,03 1,46 0,03 3.44 220.94 3,89 623,4 623,26 0,39 1,84 0,41 -9,82 211,12 -10.42 712,3 712.16 0.16 2.00 0,18 -2,32 20B,80 -2,61 801,7 B01,42 0,19 2,19 0,21 -5,85 202,94 -6,55 8~,0 8~,67 -0,15 2,04 -0,16 25,77 228.71 28.22 5,19 74.~ 0.11 0,17 6,96 41.18 0.51 0,43 9,13 26.29 0.20 0,35 11,66 51.~ 0.32 0,13 3,84 18,16 1..~ O,BO 982.3 1017,6 1112.5 1207.6 1301.5 981.F2 1017.23 1111 1206.48 0,60 0,54 1,53 2,08 2,00 2,64 3.19 4,72 6,80 B,BO 0,67 4,65 233,37 2~6.1a 1,54 2.76 ~ ~ 1,61 10,46 246,59 2,19 2,97 249,56 2.13 1,_~ 250.67 5,21 7.81 11,02 3.12 1,19 15.37 20.01 0,70 0,38 16.03 15.45 1.59 2,50 17,61 30.48 1,78 0,20 18,95 9,61 2.21 0,46 13.62 111.61 2,13 13%,1 1491.3 1585.4 1681,0 1776,6 1~FZ,57 2,84 11,63 3,00 '1,98 ~2,66 1485,18 3,63 15.26 3,82 2,16 254.81 1574,94 4,09 19~35 4,35 0.11 254,92 1664,25 3,33 22,69 3.48 2.75 '257.66 1752,78 -0,58 22,10 -0,61 -0,77 2~.90 2,10 2.26 0.11 2,87 -0.80 21,70 8,05 3.02 0.94 22,69 8,90 3,85 0.87 23,45 0.29 4,0'-5 0.53 23.48 17.74 3,63 0,75 20,34 4.85 0.68 1670,6 1963.5 2062,6 2157.6 2251,2 18~.12 1¢~2.34 2006,12 2087,6?. 21./,3,22 1,96 4,48 3,08. 3,02 · 3,07 24.06 28.54 31,62 34.64 37,71 2.08 -0,~. 256,03 4,83 3,83 259.66 3,1! -0.54 259.32 3,18 0,06 2.59.38 3,27 -1.68 257,70 -O,F2 4,12 -0.54 0.07 -1,80 22,94 10.23 2.11 1.53 21.75 22.45 5,16 3,28 19.02 5,24 3.12 2,06 16.39 0,72 3,18 0.07 22.94 153.76 3.44 0,28 2346,3 2534,7 2630.3 2725.8 2236.61 2306.68 2374.47 2440.59 2505.96 3.02 2.08 2.-99 0.91 0.20 40,73 42,81 45,80 46,70 46,90 3,18 1,80 259,50 2,22 -1,28 2.58.22 3.16 -2.25 255,98 0,95 '-0,31 255,67 0,21 0,20 25'5.87 1,89 -1,36 -2.37 -0.32 0.20 12,10 21,32 3,40 0,05 ?.4~ 22.75_ 2.40 1,07' 8,/-'5 28.48 3.56 1,23 9.50 13.75 0,98 2,71 14.37 18,65 0,25 0.76 2818,4 2914,1 3008,4 3104.6 31~,0 2567,06 0,35 47,25 0.38 1.52 257.39 2634,09 -O,1B 47.07 -0.19 -2,15 255,24 2696,29 0.08 47.15 0.08 0.72 255,96 2763.77 O.OB 47.23 0.08 0.48 256.44 2827,82 -0.06 47.17 -0.07 -0.89 255.55 1.64 -2.25 0.77 0.49 -0.94 10,0~ 72,90 1,26 1,09 10.24 97.26 1,66 0,42 11.25 B1.90 0.57 1.16 11,55 77.16 0,37 0,20 10.31 35,72 0,70 0,34 3294,3 28~2,72 -0,16 47.01 -0,17 1,03 256.56 3366,8 29~5,80 -1,78 45,23 -1.'~ -0.63 255.i5 3461.0 3024.71 -2.70 42.52 -2.87 -1...g) 254.35 3574.9 3094,98 -1,87 40.65 -1,~'Y 1,91 256,26 3671.2 3168.F2 -t.64 39.01 -1.70 -1.90 254.36 -0,.~ -1,70 2.04 -1,97 12,55 102,31 0,81 0,12 12,75 165,96 1,~? 1,28 14,20 1~,30 3.10 1,16 15,46 146,49 2,40 0,74 0.~7 12.09 f5.94 2.12 o,, 3 MP£-15 **~********** AHAD~IL~ ************** SURVk'Y ANALISIS ************* CIRCULAR ARC M~D******** MI) TVD INC_CHG O]MINC_CHG I_RATE AZIt_OtG CUMAZM_CHG ft ft deg deg de.oflOOft deg deg ~_~TE' CLOSI~E TOOL_FACE DIS I)LSRT deg/1CX)ft ft de9 deg/lOOft deg/lOOft**2 3762.7 323~,99 -0.03 38,98 -0.03 0.70 255.07 0.77 3859.5 3315.B8 -1.23 37.75 -1,27 -1,04 254.03 -1.07 3954.8 33?2,20 -1,89 ~,~5 -1.~8 0.54 ~4,~ 0.~ 4~7,0 3~7.78 -1,7~ 34,~ -1,~ 1,07 ~5,64 1,16 4141,3 35~,76 -1,~ ~,15 -2,04 -2,69 ~2,~ -2,~ 18,38 94,39 0,4? 1,79 20,36 152,73 1,43 0,98 22,50 170,44 .2,01 0,61 23,74 161,44 2,04 0,03 16,65 144,20 2,57 0,56 4236,2 3627,51 -0,94 31,21 -1,00 0,35 253.30 0,37 4329,5 3707,91 -1,55 Z?,&5 -1,67 -0,47 252,82 -0,51 4423,1 3790,04 -1,83 27,82 -1.95 0,53 253,36 0,57 4517,6 3873,93 -0.97 26,86 -1,02 -0,16 253,20 -0,17 4609.6 3956,0? -0,22 26,64 -0,24 -0,23 252,97 -0.25 26,52 169,10 1,01 1,64 31,30 171,48 1,69 0,72 33,94 172,30 1,97 0,31 36,33 175,75 1.03 1,00 25,63 143,70 0,27 0,83 4705.3 4041,75 -0,32 26.31 -0.34 -0,41 252,55 -0.43 4601,7 4128.15 0,03 26,34 0,03 0,65 253,20 0,68 4896.2 4212,89 0.03 26,37 0.03 -0.28 252.'FZ -0.30 4~0.3 425'7.15 -0.01 26.35 -0,02 1,88 254.80 2.00 5086.4 4383,31 -0.14 26.21 -0,15 -0,70 254.11 -0,72 41,49 150,38' 0,39 0,13 44,15 85,02 0,30 0.09 46,62 76,59 0,14 0,17 48.50 91,84 0.89 0.80 38,75 154,65 0.35 0.56 5182.1 4469,16 O.OB 26,2? 0,09 ~0,58 253+53 -0,61 51,91 72,31 0,28 0,08 5284.6 4561,07 0,01 26,30 0,01 -0,~5 253.17 -0,35 54,36 87,71 0,15 0,12 5375,0 4642,10 O,O0 26,30 0,00 0,00 '253,17 0,00 56,65 0,00 0,00 0,17 RE'CEIVED PAGE ********* SCHLUMB~G~ ********** ********* ********** ********************************************************* COMPAWY BF' WELL NAME MPE-15 L~ATION 1 MILNE POINT LOCATION 2 ALASI(A MAGNETIC DECLINATION GRID CONVERGENCE ANGLE [~TE: 19-~t'-~ WELL NUMBER 15 AF'I~ 500~B7404000 WELL HEAD LO.TIOga: LAT(N/-S) 0.00 JOB ~ 36175 AZ!MLrrH FROM K~3TAR¥ TABLE TO TARGET IS TIE IN F~}INT(TIP) MEASLMED DEP~ 112.00 TRUE VERT DI~qlM 112.00 INCLINATION AZIMU~ 0.~ ~TI~E(N/-S) D~'AR~E(~-W) 0,00 DEP(E/-W) 0.00 256,44 2 ~ASU[d~D It~T~I~,hkLU~T~TICAL D~'TH DEPTH ft' ft ft 112,00 0,0 112.00 174,37 62.4 174,37 259.20 84,8 259.19 350,24 91.0 350,21 4~,56 90.3 440,51 529,17 8~.6 529.06 623,38 94.2 623.26 712,33 ~,9 712,16 801.65 89,3 B01,42 892.97 91.3 692,67 982,29 1017,65 1112.53 1207,61 1301.49 1396,08 1491.31 1585.35 1681.04 1776,79 1870,65 1963.49 2062.63 2157.58 2251,24 2346.25 24~k,'~ 2534 2630.27 2725.77 2818,45 29.14.06 3008.40 3104.76 3199.02 3294,34 3481,00 3574.~ 3671.23 89.3 981.92 35,4 1017.23 94,9 1111,89 95,1 1206,48 93,9 1299,50 94,6 1392,57 95,2 1465,18 94,0 1574,94 95,7 1664,25 95,8 1752,78 93,9 1639,12 92,8 1922,34 99.1 2006,12 94,9 2087,62 93;7 2163,22 95,0 2236,81 93.7 2306,68 94,7 2374,47 95.6 2440,5? 95,5 2505,96 92,7 ~69.08 95.6 2634,09 94.3 2698,29 96.4 2763,~ 94.3 2827,82 95.3 2892,72 92,4 295.5.80 94,2 .3024,71 93,9 3094.96 96.3 3168.~ TARG~"I S?ATION AZIMUTH LATITUDE SECTION I)~LN. W-S ft Oeg deg ft 0,00 0,00 0,27 0.82 203,32 -0,41 1.24 1.06 217,29 -1,60 2,61 1,21 214,97 -3,05 4,20 1,43 217,50 -4,72 5,98 1,46 220,94 -6,45 8,02 1,84 211,12 -8,65 10.07 2,00 20~,60 -11,24 12.14 2.19 202.94 -14.18 14,62 2,04 228,71 -16.86 17,92 2,64 233,37 -19,14 19,59 3,19 Z'~5,13 -20,17 25.91 4.72 246,59 -23,19 35,35 6,60 249.56 -26,71 48,01 8,BO 250,67 -31.03 64,72 11,63 252,66 -36,27 86,63 15,26 254,81 -42,41 114,79 19.35 254,92 -49,71 149,10 22.69 257~66 -57,78 185,56 22,10 256,90 -65,81 222,37 24,06 256,03 -74,43 263,46 .28,54 259,86 -82,91 313,06 31,62 259,32 -91,90 364,90 34,64 259,3~ -101,48 420,14 37,71 257,70 -112,49 480,15 40,73 259.50 -124,34 542,50 42,81 258,22 -136.41 606.64 45,B0 2.55,98 -151,21 677,70 46,70 255,67 -168,13 747,31 46.~) 255,87 -185,24 815,17 47,25 257,39 -200,93 885,28 47,07 255,24 -217,52 954,39 47,15 255,96 -234,71 1025,09 47,23 :~_6,44 -~1,b-7 1094,24 47,17 255,55 -268,31 1164,05 47.01 256,58 -265.13 1230~68 45.23 255.95 -300,94 1~5,95 42.52 254,35 -317,66 1358,29 40,65 256.26 -333,49 1419.94 39,01 254,36 -349,11 D~'ARTURE DI~'LACBt£NT at ~-W ft ft 0.00 0.00 -0.18 0,45 -0.89 1,83 -1,95 3.62 -3,18 5,70 AZI~JTH DLS dee/ o deg 10Oft 0.00 0,00 203,3~ 1.32 209.26 0.~ 212,63 0,17 213,98 0,26 -4,59 7.92 215.46 0,11 -6,16 10,62 215,46. 0,51 -7.65 13,59 214,24 0,20 -9.07 16.~ 212,60 0,32 -10,97 20,11 213,05 1,05 -13.82 23.61 215,~3 0,70 -15,29 25,31 217.16 1,59 -21.06 31.33 222.24 1,78 -29.92 40,11. 228.24 2,21 -41.9Q 52.14 233.48 2,13 -57,83 68.26 237,91 3,02 -79,09 89.75 241,80 3,85 -106,10 117,17 244,89 4,35 -139,44 150.94 247,49 3,63 -175,03 186,99 249,39 0.68 -210,60 223,55 -251.02 264.36 -299,89 313.66 -350,89 365.27 -405,05 420.36 250.55 2,11 251,72 5,16 252.96 3,12 253.87 3.18 254,48 3.44 -463,93 480,31 255,00 3,40 -525.15 542.58 255.44 2;40 -589,62 608,70 255,62 3,56 %56,56 677.76 255,64 0,98 -724,06 747.38 255,65 0,25 -790.06 815.24 255.73 1,26 -858,20 885.34 255.78 1,66 -925,15 954,46 255,76 0,57 -f5r3.80 1025.15 255,79 0,37 -10~.91 1094,31 255.81 0.70 -1128.66 1164,12 -1193.30 1230.74 -1256,50 1296.03 -1316,80 1358.36 -1376,46 1420.04 R 255.82 O.B1 255.85 1,99 255.81 3.10 255.79 2,40 AUG 2 9 190t; P~B NB, ***.w.,.~***** ANAl)RILL ~**~**~*~ 9URqJEY CALOJLATIONS **~w**~,~,~ CIRt'IJLAR ARC P1ETHOD~***~w.* ~PE-15 MEASURED INTERVAL VERTICAL DEPTH DEPTH i't ft 'ft 3762.68 9'1.4 3239.99 3859,46 96.8 3315,88 3954,79 95,3 4047,02 92,2 3467.78 4141,32 94.3 3~6.76 T~:GET STATIDN AZIMUTH LATITUDE SECTION INCLN, N/-S ft deg deo it 1477,46 38,98 255.07 -3~.~,26 1537.49 37,75 254,03 -380,28 1594,56 35.66 254.~ -3?5.74 1647,40 34,08 255,64 -409.33 1698,87 32,15 252.95 -423,24 DEP~TLME DISPLAC~E~T at E/-W ft ft -1431.96 1477.57 -1489,86 1537.63 -1544.64 1594.72 -1595.91 1647,57 -1645,50 1699.06 d~ 255,73 255,4.8 255,63 · 255.61 255,58 DLS deq/ lOOit 0.49 1,43 2,01 2.04 2.57 4236,21 4329.46 4423,13 4517,57 46~.5S 94.9 3627.51 ~.2 3707,91 ~,7 37'70.04 94.4 3873,73 92,0 3956.~ 1748,62 31,21 253,30 -437.71 1795,77 29,66 252,82 -451,47 1840,73 27.82 253.36 -~4.57 1884,04 26,66 253,20 -477.05 1925,38 26,64 252.97 -489.10 -1673,19 1748,85 255,51 -1738.37 1796,04 255,44 -1781,46. 1841.04 255,38 -1823,00 1884.39 255,34 -1862.62 19~25.77 255,29 1,01 1,69 1.97 1,03 0,27 4705.27 4801,67 4</90.28 5086.37 '~J.7 4041,75 96,4 4128,15 94.6 4212,87 94,0 4297,15 96.1 4363.31 1967,95 26.31 252,55 -501.75 2010,42 26,34 253,20 -514,~ 2052,52 26,37 252,?Z -526,57 2094,23 26,35 254,80 -538,17 2136,76 26.21 254,11 -549.57 -1903,36 1968,39 -1944,22 2011,10 -1984,38 2053,05 -2024,48 20?4,79 -2065.48 2137.34 255,23 255.18 255,14 25'5,11 255.10 0.39 0.30 0.14 0,35 5182,11 95,7 5284.62 102.5 PROJECTED TO TD 5375.00 90.4 4469,18 4~51,07 4642,1o 2179,~5 26,29 253.53 -561.37 2224,41 26.30 253,17 -574,39 2264,39 26.30 253~17 -585,98 -~10..,15 2179,68 25'5.08 -2149.65 ~.07 255,04 -2187,98 2265.09 255,01 0.28 0,15 0,00 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501° Dear Sir/Madam, Reference: Date RE: 13 September 1995 Transmittal of Data ECC #: 6434.03 sent by: HAND CARRY Data: PFC/PERF MPE-15 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # I Please sign and return to: Attn. Rodney D. Paulson Atlas wireline Services 5600 B street suite 201 Anchorage, AK 99518 Please st~usnd return tO= Petrotechnical Data Cente~ BP Exploration (Alaska) InS 900 East Benson Boulevard Anchorage~ Alaska 99508 Received by Date LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Sent by: HAND CARRY 11 September 1995 Transmittal of Data Dear .~ /~ ~__r,..a_am, . . ..... : ._~ . . _...T~.. . . _ .... , . r. Enclosed, find the data described below: paease .as . . :i ~'~ .1 ~ L~ FIN~ BL+~ Run ' , - = . . _ . . ~_3' '. -' - ' '.: .' ...... ~ - ~-.:_.:~.._. -_ ~=~'-~:~%'-':':-:~ ~-" . _ Please sign and return to: Attn. Rodney D..Paulson --'.: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 ~C ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 September 1995 RE: Transmittal of Data Sent by: HAND CARRY - _ Dear Sir/Madam, Enclosed, please find the data as d~scribed below: Please sign and return to Attn.'Rodney D. Paulson _ Atlas Wireline Services Received by: Anchorage, AK 99518 ' _'-t' ::- '-' :"- ".i" "SEP ; 4'1~9~'":C'-:., ~-_'-._t--I-;~ '_-.:.:i~i.i_. _Or FA~ to (907) 563-7803 A~ask - ' .... ' ........ . ._ a OH & Gas C~s. Co~misslon . -Date: ~ehoran~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: Date: RE: 26 May 1995 Transmittal of Data ECC #: 6434.00 Sent by: PRIORITY MAIL Data: OH-LDWG BP MPE-15 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: D ate: ~lease sign and r. eturn Petrotechnical Data Cente~ BP Exploration (Alaska) 900 ~kst Benson Boulevard - ~~alaska 99508 Date RECEIVED JUN 09 1995 A/aska Oil & Gas Cons. ~chora.g.e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 24 May 1995 Transmittal of Data ECC #: 6434.00 Sent by: PRIORITY MAIL Data: OH-LDWG Dear Sir/Madam, Reference: MILNE POINT NORTH SLOPE, A Enclosed, please find the data as described below: Prints/Films: 1 DIFL/GR FINAL BL+RF Run # 1 1 ZDL/CN/GR FNL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 1 BH PROFILE FNL BL+RF Run # 1 Please sign and return ~~ · CONSERVATION COMMISSION ALASKA OIL AND GAS TONY KNOWLE$, OOVEF~NOF~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 12, 1995 : · Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point MPE-15 Revised BP Exploration (Alaska), Inc. Permit No. 94-153 Sur Loc 35672qSL, 1900'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc 29252qSL, 4412'WEL, Sec. 25, TI3N, R10E, UM Dear Mr. Clark: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December 14, 1994 are in effect for this revision. : Chairman '~~ BY ORDER OF TIlE COMMISSION dlf/Enclosures CC: Department offish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o enci BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: May 9, 1995 Attention: David Johnston, Chairman Subject: Well MPE-15 Revised Well Permit (94-153) Well MPE-15 permit # 94-153 will be drilled in May, 1995 with rig Nabors 22E. Anticipated spud is May 11, 95, therefore, your early approval of the attached revised permit is requested. The surface location has been changed but all other details remain the same. Yours Sincerely, Drilling Engineer Supervisor MS cc. Well file Petrotechnical Data Center RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-I lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen© Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54' feet Milne Point - Schrader Bluff 3. Address 6. Property Designation P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 25518 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3567' NSL, 1900' WEL, SEC. 25, T13N, RIOE Milne Point At top of productive interval 8. Well number Number 3078' NSL, 3923' WEL, SEC. 23, T13N, RIOE MPE-15 2S100302630-277 At total depth 9. Approximate spud date Amount 2925' NSL, 4412' WEL, SEC. 25, T13N, RIOE 5/10/95 $200,000.00 i12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28231-4412' feet No close approach feet 2560 5518' MD/4784' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 51 o Maximum surface 1629 psig At total depth (TVD) 4784'/2105 psig 18. Casing program Setting Depth raze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.4# H-40 Weld 80' 32' 32' 112' 112' 250 sx Articset I (Approx.) 8-1/2" 7" 26# L-80 NSCC 5487' 31' 31' 5518' 4784' 440 sx PF 'E'/280 sx "G'/250 sx PF 'E' 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production Liner MAY 10 199§ Perforation depth: measured true vertical AJ~}f~ 0il & Gas Cons. Commission 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling pr~.rn [] Drilling fluid program/E] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] certify ~t , f, r~going i~ true and correct to the best of my knowledge 21. I hereby ~~~ Signed T itl e Drilling En~lineer Supervisor Date · ' - Commission Use Only Permit Number JAPI number Approval date See cover letter ,~-//,.~ ~ J5 0- c~ ;7._-~ - ~-- ~- ~'-~ ~" / ~ -//7/ _ ~'¢ for other requirements Conditi°n~ of apprm/al Samples required [] Yes [] No Mud Icg requir(Jd []Yes ,J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required 1~ Yes [] No Required working pressure for BOPE []2M; r-13M; 1-15M; r-I10M; []15M; / / Other: Oi'igii'i~! b:~lUa i:3y by order of Approved by David W. Johnston Commissioner ~ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate ] Well Name: ] MPU E- 15 Well Plan Summary ]Type of Well (producer or injector): ]Schrader Bluff I I Producer Surface Location: 3567' FSL 1900' FEL Sec 25 T13N R10E UM., Ak. Target Location: 3078' FSL 3923' FEL Sec 25 T13N R10E UM., Ak. Bottom Hole Location: 2925' FSL 4412' FEL Sec 25 T13N R10E UM., Ak. I AFE Number: I I ]Estimated Start Date: ]Jan 25, 1995I ]5518' I IfyI): 14784' bkbl I Rig: ]Nabors 22E I Operating days to complete: [ 6 ]KBE: 154' I Well Design (conventional, sHmhole, etc.): I Schrader Bluff ESP Producer Formation Markers: Formation Tops MD TVD (BKB) Formation Pressure Data KOP 1000' 1000' _ Base Permafrost 1821' 1804 - Top NA Sand 4954' 4254' EMW 8.6 ppg Target 4954' 4254' EMW 8.6 ppg Top NB Sand 4975' 4274' EMW 8.6 ppg Top NC Sand 4997' 4294' EMW 8.6 ppg Top ND Sand 5015' 4311' EMW 8.6 ppg Top NE Sand 5024' 4320' EMW 8.6 ppg Top OA Sand 5103' 4394' EMW 8.6 ppg Top OB Sand 5167' 4454' EMW 8.6 ppg Base OB Sand 5199' 4484' EMW 8.6 ppg TD 5518' 4784' _ Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.4# H-40 Weld 80' 32/32" 112'/112' ,, 8-1/2" 7" 26# L-80 NSC 5487' 31'/31' 5518'/4784' RECElV£D Well Plan Summary MAY 1 0 1995 Oil & Gms Cons. ~ommission Page 1 AJlOhOrr: ~ Internal yield pressure of the 7" 26# L-80 casing is 7240 psi. Worst case surface pressure would occur with a full column of gas on top of plugged perfs (no packer) at the reservoir at 4254' TVD. Maximum anticipated surface casing pressure assuming virgin pressure of 1800 psi at 4000'TVD is 1350 psi, which is well below the burst pressure rating of the 7" casing. Logging Program: I Open Hole Logs: Production 8-1/2" to TD w/MWD Directional and LWD (GR/CDR/CDN). Cased Hole Logs: GR/CCL/gyro (w/out rig on well) Mud Program: ]Special design considerations ]None Surface Mud Properties: N/A [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss to to to to to to to Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 8 10 8 8 8.5 15 to to to to to to to 9.5 15 30 15 30 9.5 7 Well Control: Well control equipment consisting of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Lines. Completion Rig (Nabors 4ES) 5000 psi W.P. pipe ram, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKoP: I 1000', S-Shaped Maximum Hole Angle: I 51 ° Close Approach Well: [ NONE Well Plan Summary RECEIVED MAY lo 199,5 & Gas Cons. Commission Anchor;': ~, Page 2 Disposal: Cuttings Handling: CC2 Fluid Handling: All drilling and completion fluids will be hauled to CC2 for injection. Annular Injection: The MPU E-15 well will not have an annulus available for injection as permitted. Consequently, no drilling or completion fluid will be injected in this well. Operations Summary: . 2. 3. 4. 7. 8. 9. 10. 11. 12. 13. 14. Drill and set 20" conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 20" Diverter system. Directionally drill 8-1/2" hole to 5518' MD/4784' TVD. Run and cement 7", 26#, L-80, NSCC casing to surface (perform top job if req'd) N/D Diverter and N/U wellhead. RDMO Nabors 22E. MIRU Nabors 4ES. N/U 13-5/8", 5M WP BOP Stack and test. Perforate, hydraulic sand frac and gravel pack "N" and "O" sands. Complete well with 2-7/8", 6.5#, L-80 EUEtbg with Electric Submersible Pump (ESP). Set BPV. N/D BOP Stack and N/U x-mas tree. RDMO with Nabors 4ES o , Drilling Hazzards and Risks: There was evidence of shallow gas/hydrates in the E-pad area (E-7 and E-8 wells). Consequently the MW schedule requires 9.3 ppg by 2000' TVD. This practice was adhered to on MPU well E-09 and there was no evidence of a hydrate problem while drilling surface hole. No other drilling hazards or risks have been identified for this well. Well Plan Summary RECEIVED MAY lO 1995 Alaska Oil & Gas Cons. Commission ~chor~'~ ~: Page 3 CASING SIZE: 7" SPACER: 75 bbl fresh water. LEAD CEMENT TYPE: Temp E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX # SACKS: 440 TAIL CEMENT TYPE: MPU E-15 7" PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP: 75° F at 4500' TVDss YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F Premium G ADDITIVES: 2.0% CACL2, 0.3% CFR-3, 0.5% HALAD-344 WEIGHT: 15.8 PPG YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX # SACKS: 280 THICKENING TIME: Greater than 4 hrs at 50°F FLUID LOSS: 100cc FREE WATER: 0 TOP JOB CEMENT TYPE: (If Needed) Permafrost E ADDITIVES: Retarder WEIGHT: 15.6 PPG YIELD: 0.96 ft3/sk MIX WATER: 3.7 gal/sk APPROX NO. SACKS: 250 CENTRALIZER PLACEMENT: 1.7-1/8" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 20 jts of 7" Casing (40 Total). This will cover 250' above the top of the "N" sands. 2. Run one 7-1/8" x 16" Straight Blade Turbulators in side of the 20" casing. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirements. Displace at 10 BPM. Batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry Volume is calculated to cover 500' md above the top of the upper "N" sands with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3.80' 7", 26# capacity for float joints. 4. Top Job Cement Volume will be 250 sx, if necessary. ~ ~ ~ ~ I~ ~ D Well Plan Summary 0il & Gas Cons. 00mmi~[t~e 4 'Alldlor~: :' I SHARED SERVICES DBi'~LING: .ii'~., I i il ii i i i i Al K8 0 0 0 O. O0 B~ ~o~/~u~/,oo ~ ~ooo ~ooo -o ~.oo VERTICAL SEC~ION'VIEW 81 E~B ~/~00 8UlL~ ' ~579 ~05 616 47.~6 , ~, ;, - D) DROP 2/100 3449 ~995 t257 47.36 : . , E~ END 2/100 D~OP ~ 4567 3891 1912 25.00 Section at 256.44 Fl ....... T~RG[T ' 4967 4254 208~ 25,00 TVD Scale.' J inch = 600 '~eet. '<KB> ~ TO ,~ 55~2 4757 2~6 25.00 Oep Scale'. ~ inch = 600 ,feet ' , j · Drawn · 04/14/95 i . .. I ........... u~~ ' ' ~oo ..... ~ ...... ' ~ ~na~i.] ] Sc~] e¢ · [ · . I' I ~ . i 4 . : ,. ...... . . i. : j ........... , ........... I ,, . , , 1200 ~ ' ' . .,..~ ~ , ~~ ~ F~ASIBILI':~ P~N . ~100 ...... ' -- . ~oo- ' I I ' .: ~-~ ~" , ~ · _. . . ~ ' 2700 ............. ~ ~ --- ..... , ., ...... ~ ..... . .... ' ~ : ~ : ~ I~[IVED '~ . , MAY t0 199~ -- q ........ , ................... ; J ~ ~...J ..... · ....... , ....... .... 3~o~ ....... i- :~ ..... · ~~'____ ' "' ~*~ "~ ~ .... I'-- z ...... 4200 - ' I; : ; ....... : ............ .__~~!!!i~ ~!~~ ~~~~::'~'::'::~ ' 0 300~ 600 900 2700 300~ 330u 3600 3900 ~ Section Dep~rtuee , ~ : ~ ' 'SHARED S'ERV:[I ES DR':[LL]:NG j J JSCALE ....... : 1 ~nch = 300 feet ...........................................Ai~'~II~L"'-' .... ............................................ ':'~ '~""'? '~'': ~-"'-:""'~ KA.DP 2 Jb'Fl'A'i~r~':"i'.'..'~' :: ~;~'?',~J~ ................... i ii i i iiii. FEASIEILITY PLAN .~.~.~ Ideo[),j¢~[jor~ HD H/S EJ'H · ..' I.'.N. Qii_~.__.A_PP...ROV_ED.!FOR.'.' ......... "... i · -~..~, .......................... o ......... o ........ ' EXECU"[IUN.4~'~'"' '--.,~, ,! KOP/BUILO 3/100 1000 O 0 '" C) END 3/'100 BUILD ~§79 '144 599 ' , -, ': ...... O) DI:tOP 2/100 3449 ~~-~ ~---' i Fi ....... TAR6E1 ....... 4§67 408 2023 ~ ~ ~ G) lO §522 543 2251 - - · .... i. · I ................ ! .......... · "~J '- ] : . ; , ~ ~ ............ t ~ ~ ,, ,, . _ -' '- . ' " -~.. -- I ...... I ...i .... · .I-.~. . i / ,' .......................... ~ ....... ...... i ~ .......... I ....... I---- . ...... ! -~ -' ' ' ! } . ..... : "1 ..... ....-- - .... ,~ '" .... "1 ..................... "" ..... I:'- .... , 'i i i · il i llll _ i l~nadr~ 1 ] $chlur~bergen ii _ J! i1[ ! ii _ MPE- 15 (P09) ,~ PLAN V I CLOSUIqE · 2316 leet at Azimuth 256.44 2550 J· 2400 2250 2100 1950 1800 1650 ]500 t350 t200 1050 900 750 600 450 300 t50 0 150 <- NESf "E~S! -> (~n~dr~]] (cj93 ~P~I.~9 I]1.5;~ 1:53 Pi~ !) ALASKA OIL AND GAS CONSERVATION COMMISSION December 14, 1994 TONY KNOWLES, GOVERNOR 3001 POR('Ui'INE DRIVE ANCIIORA(;E, ALASKA 99501-3192 PIIONE: (907)279-1433 TELECOPY: (907)276-7542 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point MPE-15 BP Exploration (Alaska), Inc. Permit No: 94-153 Sur. Loc. 3684'NSL, 1992'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 2925'NSL, 4412'WEL, Sec. 25, T13N, R10E, UM Dear Mr. Clark: Enclosed is the approved application' for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 ila. Type of work Drill [] RedrilllDIlb. Type of well. Exploratoryl-1 Stratigraphic Testi-i Development Oill~ Re-Entry [] DeepenCII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54' feet Milne Point - Schrader Bluff 3. Address 6. Property Designation P. O. Box 196612. Anchorac~e. Alask~ 99519-6612 ADL 25518 4. Location of well at sur]aCe 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3684' NSL, 1992' WE/_, SEC. 25, T13N, RIOE Mi/ne Point At top of productive interval 8. Well number Number 3078' NSL, 3923' WE/_, SEC. 25, T13N, RIOE MPE- 15 2S 100302630-277 At total depth 9. Approximate spud date Amount 2925' NSL, 4412' WEL, SEC. 25, T13N, RIOE 1/25/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(aOandWO) property line ADL 28231-4412' feet No close approach feet 2560 5518' MD/4784' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ^^c 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 5~ o Maximum surface 1629 psig At total depth (TVD) 4784'/2105 psig 18. Casing program Setting Depth raze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 24" 20" 91.4~ H-40 Weld 80' 32' 32' 112' 112' 250 sx Articset I (Approx.) 8-1/2" 7" 26# L-80 NSCC 5487' 31' 31' 5518' 4784' 440sxPF"E"/280sx"G"/250sxPF"E" 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural R~g6~lV~D Conductor Surface Intermediate DEC -'2 1994 Production Liner h'i~sk~ 0il & Gas Cons. Commission Perforation depth' measured Anchors true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program I~ Time vs depth plot ~ Refraction analysis l-I Seabed report[-I 20 AAC 25.050 requirements[] 21. I hereby certify t~.cb~/t1~e ~/e~ing is tr¢~ and correct to the best of my knowledge . Signed y~/ ('"'~' L~'-'~~'~ TitleDri//ingEn~/ineerSupervisor [~ Commission Use Only Permit Number IAPI number IApprov/a~date lSee cover letter ? ~,/-./,/~",,..~ 150-~_.~.-..~-~Z ,5'"' ~ <~I /~",~ other requirements Conditions Of approval · Samples required [] Yes 1~ No Mud Icg required []Ye~'~ No Hydrogen sulfide measures [] Yes .~ No Directional survey requ~rea [] Yes [] No Required working pressure for B~)PE []2M; ~[.3~M; 1-15M; [-I10M; I-I15M; Other: DavidUriglnaFSigneaw. JohnstonUY by order of Approved by Commissioner ~ne commission Date Form 10-401 Rev. 12-1-85 Submit in I Well Name: I MPU E-15 Well Plan Summary IType of Well (producer or injector): ISchrader Bluff Producer ISurface Location: Target Location: Bottom Hole Location: 3684' FSL 1992' FEL Sec 25 T13N R10E UM., Ak. 3078' FSL 3923' FEL Sec 25 T13N R10E UM., Ak. 2925' FSL 4412' FEL Sec 25 T13N R10E UM., Ak. I AFE Number: I Estimated Start Date: Well Design (conventional, slimhole, etc.): I IRis: I Nabors 22E I Jan 25, I Operating days to complete: 16 I TVD: 14784' bkbI I KBE: 154' I Schrader Bluff ESP Producer Formation Markers: Formation Tops MD TVD (BKB) Formation Pressure Data KOP 1000' 1000' _ Base Permafrost 1821' 1804 - Top NA Sand 4954' 4254' 8.6 ppg EMW Tarl~et 4954' 4254' 8.6 ppg EMW Top NB Sand 4975' 4274' 8.6 ppg EMW Top NC Sand 4997' 4294' 8.6 ppg EMW Top ND Sand 5015' 4311' 8.6 ppg EMW Top NE Sand 5024' 4320' 8.6 ppg EMW Top OA Sand 5103' 4394' 8.6 ppg EMW Top OB Sand 5167' 4454' 8.6 ppg EMW Base OB Sand 5199' 4484' 8.6 ppg EMW TD 5518' 4784' _ Casing/Tubinl ram: Hole Size i2sg/ ' Wt/Ft Grade Conn Length Top Btm Tbs O.D. MD/TVD MD/TVD 24" 20" 91.4# H-40 Weld 80' 32/32" 112'/112' 8-1/2" 7" 268 L-80 NSC 5487' 31'/31' 5518'/4784' - ~nchora ~-" Well Plan Summary Page 1 Internal yield pressure of the 7" 20g L-80 casing is 7240 psi. Worst case surface pressure would occur with a full column of gas on top of plugged perfs (no packer) at the reservoir at 4254' TVD. Maximum anticipated surface casing pressure assuming virgin pressure of 1800 psi at 4000'TVD is 1350 psi, which is well below the burst pressure rating of the 7" casing. Logging Program: [ Open Hole Logs: Production ! Cased Hole Logs: 8-1/2" to TD w/MWD Directional and LWD (GR/CDR/CDN). GR/CCL/gyro (w/out rig on well) Mud Program: [ Special design considerations [None Surface Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Intermediate Mud Properties: N/A ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss to to to to to to to Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 8 10 8 8 8.5 15 to to to to to to to 9.5 15 30 15 30 9.5 7 Well Control: Well control equipment consisting of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Lines. Completion Rig (Nabors 4ES) 5000 psi W.P. pipe ram, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional' [ KOP: [ 1000', S-Shaped [ Maximum Hole Angle: [ 51° Close Approach Well: NONE (~ons. commias'ton Well Plan Summary Page 2 Disposal: Cuttings Handling: CC2 Fluid Handling: All drilling and completion fluids will be hauled to CC2 for injection. Annular Injection: The MPU E-15 well will not have an annulus available for injection as permitted. Consequently, no drilling or completion fluid will be injected in this well. Operations Summary: . 2. 3. 4. 7. 8. 9. 10. 11. 12. 13. 14. Drill and set 20" conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 20" Diverter system. Directionally drill 8-1/2" hole to 5518' MD/4784' TVD. Run and cement 7", 20g, L-80, NSCC casing to surface (perform top job if req'd) N/D Diverter and N/U wellhead. RDMO Nabors 22E. MIRU Nabors 4ES. N/U 13-5/8", 5M WP BOP Stack and test. Perforate, hydraulic sand frac and gravel pack "N" and "O" sands. Complete well with 2-7/8", 6.5#, L-80 EUEtbg with Electric Submersible Pump (ESP). Set BPV. N/D BOP Stack and N/U x-mas tree. RDMO with Nabors 4ES . . Drilling Hazzards and Risks: There was evidence of shallow gas/hydrates in the E-pad area (E-7 and E-8 wells). Consequently the MW schedule requires 9.3 ppg by 2000' TVD. This practice was adhered to on MPU well E-09 and there was no evidence of a hydrate problem while drilling surface hole. No other drilling hazards or risks have been identified for this well. Well Plan Summary Oil & Gas Cons. Commisff~on ~chor[" Page 3 CASING SIZE: 7" SPACER: 75 bbl fresh water. LEAD CEMENT TYPE: Temp E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX # SACKS: 440 TAIL {~EMENT TYPE; MPU E-15 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 75° F at 4500' TVDss YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50°F Premium G ADDITIVES: 2.0% CACL2, 0.3% CFR-3, 0.5% HALAD-344 WEIGHT: 15.8 PPG YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX # SACKS: 280 THICKENING TIME: Greater than 4 hrs at 50°F FLUID LOSS: 100cc FREE WATER: 0 TOP JOB CEMENT TYPE; (If Needed) Permafrost E ADDITIVES: Retarder WEIGHT: 15.6 PPG YIELD: 0.96 ft3/sk MIX WATER: 3.7 gal/sk APPROX NO. SACKS: 250 CENTRALIZER PLACEMENT: 1.7-1/8" x 8-1/4" Straight Blade Turbulators-- two per joint on the bottom 20 jts of 7" Casing (40 Total). This will cover 250' above the top of the "N" sands. 2. Run one 7-1/8" x 16" Straight Blade Turbulators in side of the 20" casing. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirements. Displace at 10 BPM. Batch mixing is not necessary. Well Plan Summary CEMENT VOLUME: 1. The Tail Slurry Volume is calculated to cover 500' md above the top of the upper "N" sands with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3.80' 7", 26g capacity for float joints. ~ 4. Top Job Cement Volume will be 250 sx, if necessary. ~ [ ~'_ ~D tmeh0r¢ ' Page 4 PRUOHOE 'B~y' DRI_LING GROO'P ~ I J_ ii ! · Ill II Inl I Illl Ill II I · II I · , I I[ A) KB 0 0 0 0.00 ~ ~o~/~u=o~.~/~oo ,ooo ~ooo-o o.oo VERTICAL SECTION VIEW D) DROP 2/tO0 3~72 2987 ~0 5~,64 ' E) .... TARGET .... 4954 4254 2024 20,00 Section at: 252.58 F) END 2/~00 DROP 4954 4~5~ 202~ 20.00 TVD Sca]e.' 1 ~nch = 500 feet <KB> ~' TO A 551B 478~ 22J7 20.00 Dep Scale.' ~ inch = 600 feet · Drawn · J ~/09/94 300~ ~ ................ /nadr ~ ] ] Sch]umberger · ~-- · FEAS BILI~ ,~oo-- ~ , ~ N~T APPROVEg FOR ._ . ~ E~(EC~TION,.__ ..... K I ' B ~soo I . ...... ~ I -~00 ......... ~ .......................... ~ : --' ~ I · i ..... I ~00' i , ~ . -. :.-:_-'~ :): : _ i '~. ~ -' - - -~~o'-~ ' ""I I ' ........ :'r."Ti ......... . ............... I · ::- -~ I~~ .' . :'D,~,'c:'~-~'-~: :'~ KtLClyCU .... ..... ,~o , ~ '~x, '~ .'-'" .... ============================================, =.~ _~ ...... ~~N~~~: ~ · , :::::::::::::::::::::::::::::: :,:::::: s~~:::::-~~~'~~ ~ j '~ =-~=~:--,~ ' ' , .... -~ '. -.- t, t 0 300 600 900 ~200 ~500 JR00 2100 G 2400 2700 3000 3300 3600 3900 Section Departure · : -~lll ~1~ ~[1~05-~:5~ ~:Z4 ~ ~1" :. " . - - "' ~ : . - ., .. , . .,. , . ~. . , · .... " J :; ~ ' ':" ,'~ .... t: -.'.:. ;: ' :' ~ ' ' .t ' : ' ~' ' ' ' ' : ~ -.. ~ : :.'. -~....: ~ ,'.. : , ..: t .' ._ - "P'~UDHOE BAY DRILLING'WROUP ........ IL . ,! · I M~rk,r ,d~nt,ficst~on 14B,,~ ~'~~ NPE-E (~4) (~5) (P05) ~) KB 0 0 0 D) DROP 2/~00 3372 332 1059~ ' ' ' E) .... TARGET .... 4954 606 tg3~ ~CLOSURE ' 22~7 feet at Azimuth 252.58 Fi END 2/t00 DROP ~954 606 1931 ~} TD 55~8 664 ~5 DECLINATION.' 30.000 E SCALE ' I inch = 400 feet BRAWN ' 1 ~/09/94 ANADRILL " A~-DPC ..... AnE~cJ/7 Scn/u~ergec ,,. PPRCVEE) FO ~ 1000 ............. ~, i ~ ·., 600 ~ , ~ , ' ~ " ~ 4uu ~ ~' 20 FTT~JETRADI~ : A~chor;.' ..... 1200 ..... I , 1400 2600 ~00 2200 2000 ~00 ~00 ~400 ~200 ~0~ BO0 600 ~00 200 0 200 :WELL PERMIT CHECKLIST PROGRAM: exp [] dev~ redrll [] aery [] ON/OFF SHORE ADMINISTRATION APPR DATE 1. 2. 3. 4. 5. 6. · 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Y Lease number appropriate ................ Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. · Can permit be approved before 15-day wait ....... N N N N N N N N ENGINEERING GEOLOGY APPR DATE , 14. Conductor string provided ............... /tx ~~ 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... ~Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ~y N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~--~.... ~/~ 22. Adequate wellbore separation proposed ......... //~ N 23. If diverter required, is it adequate .......... ~ I N 24. Drilling fluid program schematic & equip list adequate I ~I N 25. BOPEs adequate ..................... t ~; N 26. BOPE press rating adequate; test to 36~'~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... .~-~~ 28. Work will occur without operation shutdown ....... VY\ N 29. Is presence of H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... J~. Y N 34. Contact name/phone for weeklY[exploratoryonly]progress reports . .../4 . Y N GEOLOGY: ENGINEERING: COMMISSION: RP~ BEW UWJ C~mments/Instructions: HOW/jo - A:~FORMS~cheklist my 03/94 vvlS..LL PERMIT CHECKLIST ,.oo,. PROGRAM: exp [] dev~ redrll [] serv [] //3,2-g s-o o,tJ ADMINISTRATION 1. 2. 3. 4. 5. 6. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............... Y Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ........ ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit .............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ ~ ........ 26. BOPE press rating adequate; test to' ~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis of shallow gas zones .......... V N 33. Seabed condition survey (if off-shore) ......... : N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z HOW/jo - A:~FORMS~ch.eklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ,No special effort has been made to chronologically organize this category of information. Tape Subfile 2 i's type: LIS TAPE HEADER MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RUN 1 6434.00 R. ECK SEE REMARKS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE lST STRING 2ND STRING 3RD STRING PRODUCTION STRING MPE-15 500292252800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 25-MAY-95 RUN 2 RUN 3 25 13N 10E 3566 1900 53.90 0.00 24.15 REMARKS: CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 9.875 5375.0 DIFL/PROX/ZDL/CN/GR. LOGS WITNESSED BY: J. DILLON & D. LUTRICK. CIRCULATION STOPPED AT 17:00 HRS, 19-MAY-95. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. 4804.5 4806.5 4821.0 4844.5 4852.5 4859.0 4866.0 4870.5 4874.5 4882.5 4891.5 4903.0 4911.5 4915.5 4927.5 4940.0 4942.5 4943.0 4946.0 4968.5 4969.0 4969.5 4974.0 4977.0 4977.5 4978.0 4980.0 4989.0 4994.5 4997.5 5002.0 5006.0 5008.0 5008.5 5024.5 5025.0 5044.0 5044.5 5046.5 5047.0 5051.5 5056.0 5056.5 5065.5 5090.5 5093.0 5093.5 5098.5 5102.0 5102.5 5120.5 5123.0 5123.5 5136.5 5139.5 5140.5 5141.0 5144.0 5144.5 5158.5 4804.5 4969.0 4974.0 4976.5 4995.0 5009.0 5024.5 5044.0 5051.5 5056.5 5093.0 5103.0 5124.0 5141.0 5145.5 5158.5 4804.5 4967.5 4976.0 4993.5 5002.0 5009.0 5024.0 5043.5 5051.5 5O55.5 5092.5 5101.5 5120.5 5136.0 5139.0 5144.5 4804.5 4969.0 4974.0 4976.5 4995.0 5009.0 5024.5 5044.0 5051.5 5056.5 5093.0 5103.0 5124.0 5141.0 5145.5 5158.5 4807.0 4822.0 4844.5 4852.5 4866.5 4874.5 4915.0 4927.0 4942.0 4946.5 4969.5 4977.5 4988.5 4998.0 5007.0 5009.0 5025.0 5047.0 5065.5 5090.5 5094.0 5098.5 5102.5 5122.5 4804.0 4807.0 4820.5 4844.5 4852.5 4859.0 4865.5 4870.0 4874.5 4882.0 4891.0 4902.0 4911.0 4915.0 4927.0 4940.0 4943.0 4946.5 4969.0 4980.5 4988.5 4998.0 5005.5 5008.0 5024.5 5044.0 5046.5 5051.5 5065.5 5090.5 5094.0 5098.5 5102.5 5122.5 5140.0 5144.0 MPE- 15 MILNE POINT M ICI OFIL Run 1' 19 - May- 1995 DIFL/PL/ZDLCN/GR RECEIVED 1995 WESTERN ATLAS 5379 FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4565.0 5300.0 DIL 4644.0 5379.0 PL 4618.0 5353.0 SDN 4594.0 5325.0 2435 4652.0 5307.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH LL8 4597.0 4635.0 4649.5 4655.0 4657.5 4659.5 4660.0 4669.5 4677.0 4681.0 4680.5 4681.5 4682.0 4686.5 4687.0 4688.0 4690.0 4690.5 4692.5 4693.5 4697.5 4699.0 4701.0 4717.0 4726.5 4734.0 4736.0 4736.5 4737.5 4738.0 4743.0 4746.0 4748.5 4749.0 4756.0 4758.0 4759.5 4761.0 4772.0 4800.5 4690.5 4717.0 EQUIVALENT UNSHIFTED DEPTH PROX ILD NPHI 4659.5 4680.5 4680.5 4654.5 4686.0 4692.5 4697.0 4701.0 4717.0 4717.0 4669.5 4682.0 4687.0 4737.5 4737.5 4737.5 4743.0 4743.0 4743.0 4748.0 4748.0 4748.0 4758.0 4757.0 4726.0 4732.5 4734.5 4737.5 4755.5 4761.5 all runs merged; no case RHOB 4597.0 4635.5 4649.5 4654.5 4656.5 4659.0 4669.5 4677.0 4681.0 4688.0 4690.0 4693.0 4698.0 4735.5 4737.5 4743.0 4746.0 4748.5 4755.5 4759.0 4761.5 4772.0 4801.0 5161.5 · 5162.0 5163.5 5169.5 5170.0 5178.0 5195.5 5211.5 5212.0 5214.5 5228.0 5228.5 5241.5 5254.5 5266.0 5266.5 5279.0 5299.0 5300.0 5318.0 5323.5 5333.0 5333.5 MERGED DATA SOURCE PBU TOOL CODE GR DIL PL SDN 2435 $ REMARKS: 5161.0 5168.5 5162.0 5168.5 5212.5 5212.5 5213.5 5227.5 5227.0 5227.5 5265.0 5163.5 5177.5 5196.0 5211.5 5228.5 5254.0 5266.5 5266.5 5266.0 5279.0 5299.5 5299.5 5318.0 5332.0 5323.0 5334.0 RUN NO. PASS NO. MERGE TOP 1 3 4565.0 1 3 4644.0 1 3 4618.0 1 3 4594.0 1 3 4652.0 MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. 5163.5 5169.0 5177.5 5196.0 5211.5 5227.5 5241.5 5254.0 5266.0 5279.0 5300.0 MERGE BASE 5300.0 5379.0 5353.0 5325.0 5307.0 /??MATCH1.OUT /??MATCH2.0UT /??MATCH3.0UT /??MATCH4.0UT /??MATCH5.OUT $ CN : BP EXPLORATION WN : MPE-15 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME (ALASKA) Tape depth ID: F 18 Curve~: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 2 LL8 DIL 68 1 OHMM 3 ILM DIL 68 1 OHMM 4 ILD DIL 68 1 OHMM 5 RT DIL 68 1 OHMM 6 DI DIL 68 1 IN 7 SP DIL 68 1 MV 8 MTEM DIL 68 1 DEGF 9 TEND DIL 68 1 LB 10 TENS DIL 68 1 LB 11 PROX PL 68 1 OHMM 12 RHOB SDN 68 1 G/C3 13 DRHO SDN 68 1 G/C3 14 PEF SDN 68 1 BN/E 15 CALl SDN 68 1 IN 16 NPHI 2435 68 1 PU-S 17 FUCT 2435 68 1 CPS 18 NUCT 2435 68 1 CPS 4 4 08 310 01 1 4 4 08 995 99 4 4 08 995 99 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 22 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 130 Tape File Start Depth = 5402.000000 Tape File End Depth = 4562.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decOding summary: Rep Code: 68 31940 datums Tape Subfile: 2 357 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. other main pass tool strings per run. RUN NUMBER: 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4564.5 5311.0 DIFL 4637.5 5390.0 PROX 4617.5 5364.0 ZDL 4589.0 5335.0 2435 4652.0 5308.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 19-MAY-95 FSYS REV. J001 VER. 1.1 1700 19-MAY-95 2358 19-MAY-95 5375.0 5382.0 4565.0 5379.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT SPS MIS MODL GR CN ZDL KNJT KNJT TEMP PCM PROX DIFL $ CABLEHEAD TENSION CORRELATION SUB MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR PROXIMITY LOG DUAL INDUCTION TOOL NUMBER 3974XA 3966NA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3923NA 3923NA 2806XA 3506XA 1233XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 112.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): LSND 9.70 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-15 : MILNE POINT : NORTH SLOPE : ALASKA 65.0 9.0 48.0 88.4 1.500 .920 1.620 .000 1.810 .000 THERMAL SANDSTONE 2.65 .000 1.5 54.0 88.0 49.0 .0 44.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHM}4 RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN RPRX PROX 68 1 OHMM ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S LSN 2435 68 1 CPS 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 21 270 30 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 334 31 1 20 SSN 2435 68 1 CPS 4 4 43 334 30 1 * DATA RECORD (TYPE# 0) Total Data Records: 281 1014 BYTES * 80 Tape File Start Depth = 5402.000000 Tape File End Depth = 4562.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 70582 datums Tape Subfile: 3 366 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4624.5 DIFL 4698.0 PROX ZDL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 4678.0 4649.5 4712.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION CORRELATION SUB MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR PROXIMITY LOG DUAL INDUCTION CHT SPS MIS MODL GR CN ZDL KNJT KNJT TEMP PCM PROX DIFL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 5313.0 5392.0 5366.0 5337.0 5310.5 19-MAY-95 FSYS REV. J001 VER. 1.1 1700 19-MAY-95 45 20-MAY-95 5375.0 5382.0 4565.0 5379.0 1500.0 TOOL NUMBER 3974XA 3966NA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3923NA 3923NA 2806XA 3506XA 1233XA 1503XA 9.875 112.0 .0 LSND 9.70 65.0 9.0 FLUID. LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-15 : MILNE POINT : NORTH SLOPE : ALASKA 48.0 88.4 1. 500 .920 1.620 .000 1.810 .000 THERMAL SANDSTONE 2.65 .000 1.5 54.0 88.0 49.0 .0 44.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHM~ RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN RPRX PROX 68 1 OHMM ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 21 270 30 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 334 31 1 4 43 334 30 1 * DATA RECORD (TYPE# 0) Total Data Records: 262 1014 BYTES * 80 Tape File Start Depth = 5404.000000 Tape File End Depth = 4620.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 97818 datums Tape Subfile: 4 345 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS 95/ 5/25 O1 **** REEL TRAILER **** 95/ 5/26 O1 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 26 MAY 95 8:0la Elapsed execution time = 10.93 seconds. SYSTEM RETURN CODE = 0
