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HomeMy WebLinkAbout203-143Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250903203157 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:9/19/2021 #321-343 Tubing:100 IA:60 OA:200 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT S-35 Permit Number:2031430 Wellhead Condition Wellhead was in good condition. There is a wellhouse in place protecting the well from the elements. Well still connected to flowline and only isolated by the wing valve. Surrounding Surface Condition Good clean gravel pad with no signs of hydrocarbons. Condition of Cellar Water in the cellar. No signs of hydrocarbons. Comments Well location verified by well-site pad map Supervisor Comments Photos (10) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025            2025-0902_Suspend_MPU_S-35_photos_gc Page 1 of 5 Suspended Well Inspection – MPU S-35 PTD 2031430 AOGCC Inspection Rpt # susGDC250903203157 Photos by AOGCC Inspector G. Cook 9/2/2025 2025-0902_Suspend_MPU_S-35_photos_gc Page 2 of 5 Wellhouse Backside 2025-0902_Suspend_MPU_S-35_photos_gc Page 3 of 5 Surface Safety Valve Tree Cap Pressure Gauge (Tbg Pressure) 2025-0902_Suspend_MPU_S-35_photos_gc Page 4 of 5 IA Pressure Gauge OA Pressure Gauge 2025-0902_Suspend_MPU_S-35_photos_gc Page 5 of 5 Well Cellar Hilcorp Alaska, LLC David Haakinson, Milne Point Operations Manager 3800 Centerpoint Dr, Suite 400 Anchorage, Alaska 99503 08/19/2022 Chairman Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Docket Number: OTH-22-025, Notice of Violation. Suspended Well Inspection Requirements. Milne Point Unit S-24 (PTD 203-038), S-32 (PTD 203-092), S-35 (PTD 203-143), Hilcorp Alaska, LLC. Dear Chairman Price, Please see below for information requested per Docket Number: OTH-22-025 on 08/17/2022 regarding suspended well inspection requirements for Milne Point Wells S-24 (PTD 203-038), S-32 (PTD 203-092), S-35 (PTD 203-143). Event Summary: Milne Point wells S-24 (suspended on 7/3/2021), S-32 (suspended on 6/24/2021), and S-35 (suspended on 9/19/2021) required inspections within 12 months after initial suspension. Upon review of our records on 07/25/2022, S-24 and S-32 were identified as being overdue for the initial inspection. On 07/26/2022, Hilcorp self-reported the issue and the AOGCC was notified of the delinquency and informed that the inspections would be submitted as soon as possible. The well inspections were completed and witnessed on 07/29/2022. Inspections were submitted for S-35 and S-24 on 08/05/2022 for record. S-32 inspection was submitted for record on 8/8/2022. Photos were taken during the inspection but lacked clarity needed to clearly identify well information. Investigation Details: Recent timeline of events leading to the late inspections: o 06/24/2022: S-32 (PTD 203-092) Initial suspended well inspection due. o 07/03/2022: S-24 (PTD 203-038) Initial suspended well inspection due. o 07/25/2022: Identified late inspections and communicated with the field to schedule inspection. o 07/26/2022: Communication to AOGCC that inspections would be late and the nature of the delay. o 07/29/2022: Field inspections of the suspended wells were completed. o 08/05/2022: S-24 (PTD 203-038) and S-35 (PTD 203-143) inspections submitted for record. o 08/08/2022: S-32 (PTD 203-092) inspection submitted for record. The suspended well inspection and renewal requirements are currently tracked within a manual entry spreadsheet monitored by the Well Integrity Engineer. As well statuses change and inspections are completed, the Well Integrity Engineer is responsible for updating the data accordingly. Periodic review of the data is completed to ensure compliance per 20 AAC 25.110(e). A review was conducted and identified two inspections not completed by their due date. Notification was sent to the field to conduct the inspections as soon as possible and a call was placed to AOGCC to self-report the late inspections. The inspections were completed and subsequently submitted for record. Photos were taken during the inspection and submitted as part of the record. During the process of taking and sending photos clarity of signage was not sufficient for all the well details. Hilcorp regrets this error. In MPU S-35’s case, the wellhouse was removed and placed nearby for gravel work at the time of photographs. Root cause of the incident: x Well Integrity Engineer failed to extract the correct information from the current data management system. By Samantha Carlisle at 3:48 pm, Aug 19, 2022 Contributing factors of the incident: x Manual entry and tracking of data with no automated alert in place to notify of upcoming and past-due obligations. Actions to prevent recurrence: x Migrate Milne Point Unit and Alaska Islands (Northstar, Endicott, and Point Thomson) teams to the Alaska Integrity Management System adopted by the Prudhoe Bay Unit which includes automated alerts for approaching and past-due obligations with notifications provided to personnel responsible for regulatory reporting. (Project began in May 2022 and targeted initial rollover by 1 September 2022. Full functionality planned to be in place by end of year 2022.) x Communicate to the company representatives photo requirements with regards to quality and content. x Communication to company representatives that well signage must be moved from wellhouse to wellhead in event of wellhouse removal. If you have any questions, please call me at 907-777-8343 or Jerimiah Galloway at 907-564-5005. Sincerely, David Haakinson Milne Point Operations Manager Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.08.19 11:29:28 -08'00' David Haakinson (3533)  Žƒ•ƒ‹Žƒ† ƒ• ‘•‡”˜ƒ–‹‘‘‹••‹‘   333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov  August 17, 2022 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 9723 Mr. David Haakinson MPU Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-22-025 Notice of Violation Suspended Well Inspection Requirements Milne Point Unit S-24 (PTD 203-038) Milne Point Unit S-32 (PTD 203-092) Milne Point Unit S-35 (PTD 203-143) Dear Mr. Haakinson: Hilcorp Alaska, LLC (Hilcorp) conducted several Alaska Oil and Gas Conservation Commission (AOGCC) witnessed initial suspended well inspections on the Milne Point Unit (MPU) Spad wells listed above. Inspections occurred on July 29, 2022. All wells had at least one issue with the inspection or the inspection report: - MPU S-24: 20 AAC 25.110(e) requires the initial inspection of a suspended well to occur within 12 months of the date of suspension. The well was initially suspended on July 3, 2021, so the July 29th inspection was conducted 26 days late. The quality of photos submitted with the inspection report were too poor to assess whether the well sign meets the requirements of 20 AAC 25.040. - MPU S-32: 20 AAC 25.110(e) requires the initial inspection of a suspended well to occur within 12 months of the date of suspension. The well was initially suspended on June 24, 2021, so the July 29th inspection was more than a month overdue. The quality of photos submitted with the inspection report were too poor to assess whether the well sign meets the requirements of 20 AAC 25.040. - MPU S-35: Inspection report does not demonstrate that the well has the sign required by 20 AAC 25.040. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with: Docket Number: OTH-22-025 Notice of Violation August 17, 2022 Page 2 of 2 1) a written description of why wells MPU S-24 and MPU S-32 were not inspected within 12 months of the date of initial suspension as required by 20 AAC 25.110(e) and what steps Hilcorp will take to ensure that initial suspended well inspections will occur within the time frame prescribed by the regulations. And, 2) legible photographs demonstrating that the three wells have signs that meet the requirements of 20 AAC 25.040. The AOGCC reserves the right to pursue addition enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Dave Roby at dave.roby@alaska.gov or (907)793-1232. Sincerely, Jeremy M. Price Chair, Commissioner cc: AOGCC Inspectors Jim Regg, AOGCC Phoebe Brooks, AOGCC Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.17 13:52:12 -08'00' Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 InspectNo:susAGE220802142723 Well Pressures (psi): Date Inspected:7/29/2022 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:9/19/2021 #321-343 Tubing:25 IA:0 OA:150 Operator:Hilcorp Alaska, LLC Operator Rep:Derek Weglin Date AOGCC Notified:7/27/2022 Type of Inspection:Initial Well Name:MILNE PT UNIT S-35 Permit Number:2031430 Wellhead Condition Good working condition Surrounding Surface Condition good. No sheens or trash Condition of Cellar water in cellar do to recent heavy rain ,water level is below valves, to be sucked out soon. Comments location verified by pad map Supervisor Comments Photo (1) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 30, 2022 9 9 9 9 9 9 9 9 9 9 2022-0729_Suspend_MPU_S-35_photo_ae Page 1 of 1 Suspended Well Inspection – MPU S-35 PTD 2031430 AOGCC Inspect # susAGE220802142723 Photo by AOGCC Inspector A. Earl 7/29/2022 By Anne Prysunka at 2:44 pm, Aug 05, 2022 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,804 feet N/A feet true vertical 4,110 feet N/A feet Effective Depth measured 10,412 feet 9,546' & 10,657'feet true vertical 4,047 feet 3,882' & 4,077'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2"12.6# / L-80 10,655' 4,077' HES TNT Pkr & Packers and SSSV (type, measured and true vertical depth)ZXP Liner Top Pkr N/A See Above N/A 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: 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: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: Collapse N/A 2,090psi 4,790psi Casing 2,904' 4,089' 20" 4,111'14,804' Surface Intermediate Production 10-3/4" 7-5/8" 4"4,154' measuredPlugs Junk measured Length 110' 5,816' 10,751' Size 6,590psi 3,580psi 6,890psi 7,910psi Burst N/A N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380109 / ADL0025906 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: MILNE PT UNIT S-35 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-143 50-029-23175-00-00 0 120 218 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 3,578 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 110' 5,816' 10,751' Conductor TVD 110' WINJ WAG 14 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 267 N/A David Gorm dgorm@hilcorp.com 777-8333 00 321-343 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 12:48 pm, Oct 12, 2021 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.10.12 11:06:38 -08'00' David Haakinson (3533) MGR15OCT2021 DSR-10/12/21SFD 10/13/2021 RBDMS HEW 10/13/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 8/5/2021 9/19/2021 8/6/2021 MU and RIH w/2.25" BDJSN. Coil locking up from 12,900' to 13,053' Discuss forward plan with Operations Engineer. Decision made to lay in cement from 13,000' to 11,700' 1:1. Lay in 16 bbls 15.8ppg class G cement. Displace with PowerVis and diesel. POOH. Secure well and crews leave for the night. Hilcorp Alaska, LLC Weekly Operations Summary 8/5/2021 MIRU CTU #9. MU and RIH with 2.25" JSN. RIH to 11951' and tag. PUH and begin pumping 1 bpm. Able to RIH to 11971'. PUH and begin pumping 1.5 bpm. Able to RIH to 12420' Call and discuss forward plan and options with Operations Engineer. POOH. 8/18/2021 MIT-TBG PASSED (Post Cement) (Pressure test surface lines 250/2500 psi) Pressured up TBG to 1515 psi with 1.7 bbls diesel. 1st 15 min TBG lost 50 psi. 2nd 15 min TBG lost xx psi for a total loss of xx psi in 30 min. Bled TBG back to 55 psi and recovered 1.7 bbls. Tags hung. WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/2,500H (tag cement). RAN 5'x2.5" DRIVE DOWN BAILER W/ MULE SHOE BALL & S/D @ 4,332' SLM (4,337' MD), UNABLE TO WORK PAST, VERY POOR ACTION, RECOVERED 1lb OF COIL SHAVINGS. RAN 10'x2.5" PUMP BAILER W/ MULE SHOE BALL & S/D @ 4,332' SLM (4,337' MD), UNABLE TO WORK PAST, RECOVERED 1gal OF CEMENT. WELL S/I ON DEPARTURE, DSO NOTIFIED. Crews arrive on location. RIH with Baker 2.5" inflatable cement retainer BHA: 2" CTC, 2.13" Disco, 2.1" XO, 2.13" spotting valve, 2.5" inflatable retainer OAL = 16.6. Tag early @ 10,832'. Discuss with OE. Decide to set @ 10,800'. Pump 1/2" aluminum ball and unable to see ball land. Surge coil and see slight circulating pressure response. POOH to inspect. Overpull @ 10,596'. Discuss with OE and decide to set retainer at this depth. Set down and moving in hole. POOH to inspect BHA. OOH and retainer is sheared off and downhole. Setting tool fully stroked. Plan to run 3" nozzle drift run to ensure tubing tubing clear of retainer. Secure well and SDFN. Continued on 8-12-21 WSR. 8/11/2021 Continue POOH with 1:1 returns. OOH jet tree and BOPs. FP tubing w/66 bbls of diesel from 4300' ctm to surface (2500' TVD) Shut in well with 50psi. Well appears to be holding a column of fluid. RDMO CTU9. Job complete. 8/17/2021 8/12/2021 Crews arrive on location. Check equipment and oils. MU and RIH with Baker MHA Drift BHA: 2" CTC, 2.13" Disco, 2.1" XO, 3" JSN. Tagged possible retainer at 10,751' ctm. Performed injectivity test 2 bpm @ 531 psi. MU and RIH w/cement BHA, at 10,700' ctm pumped 46 bbls of 15.8 ppg class G cement, 180 psi pressure bump. Pumped 2 bbls of KCL in .5 bbl increments every 30 minutes. No change in WHP. Load & launch 3/4" ball w/21 bbls of 2.25 ppb Powervis, contaminate and cleanout down to 10,400' ctm. Pump OOH while jetting across jewelry. Continued on 8-13-21 WSR. 8/13/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 8/5/2021 9/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary 9/19/2021 - Sunday CTU #6 with 1.75" coil. Crews arrive on location, check equipment and oils. Install UTIM to record coil condition. MU Quadco MHA. Pull test to 30k. Pressure test to 3500 psi. MU 2 7/8" motor and 3.70" 5 bladed junk mill. RIH for tag. Tag @ 4366' ctmd. Mill through @ 2.5 bpm, 3200 psi with no apparent motor work. Continue RIH to 9450' and tag. Mill through obstruction with 2.5 bpm and 3170 psi with no apparent motor work. RIH and tag @ 10412' with 5k down weight. PUH to 10401' and perform MIT T to 1500 psi. Pass. Tag and MIT were witnessed and approved by AOGCC representative Brian Bixby. Pump 10 bbl PowerVis sweep off bottom and POOH chasing with 1% XS KCL. Freeze protect coil and well. Well freeze protected to 2500' TVD (4224' MD) with 64 bbls diesel. Secure well and bring injector to back deck. RDMO. Job Complete. _____________________________________________________________________________________ Revised By: DH 10/6/2021 SCHEMATIC Milne Point Unit Well: MPU S-35 Last Completed: 8/15/2012 PTD: 203-143 TD =14,804’(MD) / TD = 4,110’(TVD) 20” Orig. DF Elev. = 71.68’ / Orig. GL Elev.= 37.9’ Doyon 14 7-5/8” 3 6 7 8 9 & 10 11 2 1 NOTE: Flush IA after pulling JP, Brush SS while flushing .IA sands up due to being last well on well row. Min ID 3.725” @ 9,647’ MD PBTD =10,412’(MD) / PBTD = 4,047’(TVD) 5 TOC @ 10,412’ 9/1/92021 4 10-3/4 ” Fill on jet pump 9,450’ SLM 7/06/19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 5,816’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 10,751’ 0.0459 4” Production Liner 9.5/ L-80/ IBT 3.548 10,650' 14,804’ 0.0122 4” Screen C27 Liner 9.5/ L-80/ IBT-M 3.548 10,761’ 14,757’ N/A TUBING DETAIL 4-1/2” Tubing 12.6/ 13Cr-80/ VAM 3.958 Surface 10,655’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,066’ SLB 4.5” x 1”KGB-2 GLM 2 9,457’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 3 9,469’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down 9A JP Set 6-25-19 4 9,479’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 5 9,546’ 7-5/8” x 4.5” HES TNT Packer – 3.856” ID 6 9,578’ 4.5” HES X-Nipple – 3.813” Packing Bore 7 9,647’ 4.5” HES XN-Nipple -3.813” x 3.725” No-Go 8 10,650’ Baker Tie Back Sleeve 9 10,657’ Baker ZXP Liner Top Packer 10 10,663’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 11 10,655’ WLEG – 4,077’ TVD OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 910sx Arctic Set Light, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 750sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 304’ MD Hole Angle Passes 70 Deg. @ 2,600’ Max Hole Angle in Tubing = 77 deg. 71 Deg. @ Sliding Sleeve WELLHEAD Tree 4-1/16” – 5M CIW Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger. 4” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23175-00-00 Drilled and Completed by Doyon 14 - 9/27/2003 Recompleted by Doyon 14 – 8/15/2012 NOTE: 1. 2’ Blast Rings Below Tubing Hanger. 2. Casing Test to 3,500psi @ 9,546’ 8/17/2012 Double Valve Baker 4-1/2” Float Shoe @ 14,804 Last Cleanout Depth to 13,133’ where CTU had friction lock 3/31/2019. Possible Liner Damage 12,850 to 12,900. NOTE: REDUCED ID = 3.813 @ 9,469’, 9,578’ & 9,647’ Jet Pump: 9A set 6/25/19 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� (C�/���I P.I. Supervisor FROM: Brian Bixby Petroleum Inspector DATE: September 19, 2021 SUBJECT: Plug Verification MPU S-35 Hilcorp Alaska LLC. PTD 2031430; Sundry 321-343 Section: 12 Depth Btm Township: 12N Range: 10E Meridian: Umiat -" 13,000 ft MD Drilling Rig: NA C.T. Tag - Rig Elevation: NA Total Depth: 14,804' MD Lease No.: ADL 0380109 Operator Rep: Rich Burnett Suspend: X P&A: Casing/Tubing Data: Casing Removal: Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 10 3/4" O.D. Shoe@ 5,816 Feet Csg Cut@ Feet Intermediate: 7 5/8" O.D. Shoe@ 10,751 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 4" O.D. Shoe@ 14,804 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 10,655 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Open Hole Bottom 13,000 ft MD 10,412 ft MD 8.5ppg C.T. Tag - 209 208 Initial 15 min 30 min 45 min Result Tubing 1979 1944 1928 " IA 244 242 240 P OA 211 209 208 Tubing IA OA Initial 15 min 30 min 45 min Result Remarks: I witnessed both the plug tag (with coil tubing) and tubing pressure test for reservoir abandonment/well suspension. Cement Plug is Class "G" 15.8ppg. Coil stacked 5000 pounds on top of plug. Pre -Test Pressures TWO = 0/238/212; pumped 2.2 bbls and returned 2 bbls; good test. Attachments: none rev. 11-28-18 2021-0919_Plug_Verification_M PU_S-35_bb 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: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,804 N/A Casing Collapse Conductor N/A Surface 2,090 psi Production 4,790 psi Liner 6,590 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7/21/2021 dgorm@hilcorp.com 4" MILNE PT UNIT S-35 C.O. 477.05 HES TNT Pkr & ZXP Liner Top Pkr and N/A 9,546(MD) / 3,882(TVD)& 10,657(MD)/ 4,077(TVD) and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 14,804' Authorized Signature: 10,751' 4-1/2" Perforation Depth MD (ft): See Schematic See Schematic 110' 20" 10-3/4" 7-5/8" 5,816' N/A 7,910 psi4,154' 10,751' 3,580 psi 6,890 psi 2,904' 4,089' 4,111' 5,816' 850 N/A MILNE POINT / SCHRADER BLUFF OIL 110' 110' 12.6 / 13CR-80 / VAM Top & TC-II TVD Burst 10,655 MD Hilcorp Alaska LLC Length Size 4,110 13,133 4,094 Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 / ADL0025639 203-143 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23175-00-00 Tubing Grade: Tubing MD (ft): COMMISSION USE ONLY Authorized Name: Perforation Depth TVD (ft): ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:54 am, Jul 12, 2021 321-343 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.07.08 16:01:46 -08'00' Chad Helgeson (1517) MGR12JUL21 DLB 07/12/2021 X 10-404 AOGCC witnessed tag and pressure test of reservoir abandonment plug w/ expected TOC ~10,500' MD, pressure tested to 1500 psi. 0025906 DLB DSR-7/13/21  JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 11:22:42 -08'00' RBDMS HEW 7/14/2021 Reservoir Suspension Well: MPS-35 Date: 07/08/2021 Well Name:MPU S-35 API Number:50-029-23175-00-00 Current Status:Flowing Oil Well [Jet Pump] Pad:Milne Point S-Pad Estimated Start Date:July 21, 2021 Rig:CTU #6 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:203-1430 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Reservoir Suspension Current Bottom Hole Pressure: 777 psi @ 3,853’ TVD (Last BHP measured 1,190 psi 02/20/2015) Maximum Expected BHP:1,250 psi @ 4,000’ TVD (No new perfs being added) MPSP:850 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU S-35 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump. In 2012, Doyon 14 pulled the completion and replaced 4.5” L-80 tubing with 4.5” 13 Chrome tubing. In September 2012, 1.75” CT performed N2 FCO to 13,135’ MD. In March 2013, 1.75” CT successfully performed N2 FCO to 9,457’ MD and pulled jet pump. A nitrified fill cleanout with 2” CT in May 2016 cleaned out the liner to 13,077’ MD. In September 2018, 2” CT with tempress tool attempted nitrified FCO of the lateral, but could not proceed beyond 11,600’ MD. In March 2019, 2” CT with extended reach vibratory tool performed nitrified FCO to 13,133’ MD before coil lockup. In June 2019, after unsuccessful Slickline attempts to pull the jet pump 2”, CT pulled jet pump. CT ran to 10,275’ CTM. Large amount of metal swarf recovered on magnets run on CT. Notes Regarding Wellbore Condition x Deviation at pump (9,469’ MD) is 72°. x Successful MIT-IA to 3,500 psi on 11/18/2015. x The well is currently online flowing at approximately 65 bopd. x New pump (9A) set by slickline on 06/25/2019. SL tagged sand at 9,450’ SLM on 07/06/2019. Objective: To suspend entire horizontal lateral with cement. The planned redevelopment pattern for the S-Pad Schrader Bluff requires this N-sand lateral to be suspended prior to drilling future well MPS-46i due to crossing the planned injector to ensure proper reservoir flooding. MP S-32 must be suspended to ~13,200’ MD (past new injector S-46) to help minimize potential communication (MBE’s). This well has potential UGNU targets in the future which is why a suspension is being requested for S-35. Slickline Procedure: 1. MIRU SL. 2. RIH and pull jet pump from 9,469’ MD. POOH. 3. MU shifting tool. 4. RIH and close HES “XD” Dura sliding sleeve @ 9,469’ MD. 5. D&T, note tag depth and type of fill for CT FCO. Reservoir Suspension Well: MPS-35 Date: 07/08/2021 Coiled Tubing Procedure: (Approved Sundry required prior to proceeding) 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/1% KCl. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. If within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 3. RIH w/ 2” coil and pull jet pump at +/- 9,469’ MD (if not pulled by slickline). 4. RIH w/ 2” coil and shift sliding sleeve closed at +/- 9,469’ MD (if not closed by slickline). 5. Test backside to 3,500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. 6. RIH w/ 2” CT w/JSN and extended reach cleanout BHA and cleanout to PBTD at +/- 14,804’ MD. POOH. a. Circulate out fill using 1% KCl w/ friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b.To minimize potential communication with planned injector (MPS-46), minimum target depth to clean out to is ~13,200’ MD (2,500’ into the liner). c.Contingency: If unable to wash down with nozzle, RIH w/ motor & mill and extended reach cleanout BHA and cleanout to PBTD at +/- 14,804’ MD using 1% KCl w/ liquid foamer and mix with Nitrogen. Utilize defoamer for returns in Kill Tank. (See Nitrogen procedure and flow diagram). 7. POOH. 8. MU ball drop cementing nozzle and RIH to 14,804’ or deepest depth reached during FCO. 9. RU cementers. 10. Mix and pump 40 bbls of 15.8 ppg Class G cement down the coil tubing taking returns up the 4-1/2” tubing. Use freshwater spacers as needed around the cement. a.Contact Engineer and adjust volume based on final cleanout depth reached b. 4” liner vol: 0.0122 x (13,130’ – 10,500’) = ~32 bbls c. 8 bbls of spare volume to squeeze away or contaminate. 11. Allow ~1 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. Pause every 500’ and pressure casing side up to 500 psi to squeeze cement until coil is at 10,500’ MD. 12. PU 50’ circulate coil clean and pressure up to 500 psi and attempt to squeeze cement into well. If well pressures up with no injection, swap to contaminate and circ coil clean. a. If able to pump into well, lay in and squeeze the remaining 7 bbls until a bump in pressure is observed. 13. Swap to contaminate and RIH to circulate to 10,500’ MD (planned TOC).Circulate a minimum 3x bottoms up. 14. Circulate tubing on entire trip back out of hole to clean up wellbore. Hold constant ECD to prevent reservoir backflow or cement flow into the reservoir. 15. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole 16. Wait on cement to gain a minimum 1,000 psi compressive strength. 17. Pressure test the cement to 1,500 psi for 30 minutes (charted). a. If the pressure test of the cement plug fails, contact the Operations Engineer to discuss pumping additional cement. Reservoir Suspension Well: MPS-35 Date: 07/08/2021 b. Notify AOGCC 24 hours in advance to witness tag with slickline and pressure test. 18. Freeze protect well. POOH. 19. RD CT unit. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coiled Tubing BOPE Schematic 4. N2 Procedure & Flow Diagram for contingency (if necessary) _____________________________________________________________________________________ Revised By: STP 8/07/2019 SCHEMATIC Milne Point Unit Well: MPU S-35 Last Completed: 8/15/2012 PTD: 203-143 TD =14,804’(MD) / TD = 4,110’(TVD) 20” Orig. DF Elev. = 71.68’ / Orig. GL Elev.= 37.9’ Doyon 14 7-5/8” 3 6 7 8 9 & 10 11 2 1 NOTE: Flush IA after pulling JP, Brush SS while flushing .IA sands up due to being last well on well row. Min ID 3.725” 9,647’ MD 5 4 10-3/4” Fill on jet pump 9,450’ SLM 7/06/19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 5,816’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 10,751’ 0.0459 4” Production Liner 9.5/ L-80/ IBT 3.548 10,650' 14,804’ 0.0122 4” Screen C27 Liner 9.5/ L-80/ IBT-M 3.548 10,761’ 14,757’ N/A TUBING DETAIL 4-1/2” Tubing 12.6/ 13Cr-80/ VAM 3.958 Surface 10,655’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,066’ SLB 4.5” x 1”KGB-2 GLM 2 9,457’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 3 9,469’ 4.5” HES ‘XD’ Dura Sliding Sleeve –3.813” ID, Opens Down 9A JP Set 6-25-19 4 9,479’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 5 9,546’ 7-5/8” x 4.5” HES TNT Packer – 3.856” ID 6 9,578’ 4.5” HES X-Nipple –3.813” Packing Bore 7 9,647’ 4.5” HES XN-Nipple -3.813” x 3.725” No-Go 8 10,650’ Baker Tie Back Sleeve 9 10,657’ Baker ZXP Liner Top Packer 10 10,663’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 11 10,655’ WLEG –4,077’ TVD OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 910sx Arctic Set Light, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 750sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 304’ MD Hole Angle Passes 70 Deg. @ 2,600’ Max Hole Angle in Tubing = 77 deg. 71 Deg. @ Sliding Sleeve WELLHEAD Tree 4-1/16” – 5M CIW Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger. 4” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23175-00-00 Drilled and Completed by Doyon 14 - 9/27/2003 Recompleted by Doyon 14 – 8/15/2012 NOTE: 1. 2’ Blast Rings Below Tubing Hanger. 2. Casing Test to 3,500psi @ 9,546’ 8/17/2012 Double Valve Baker 4-1/2” Float Shoe @ 14,804 Last Cleanout Depth to 13,133’ where CTU had friction lock 3/31/2019. Possible Liner Damage 12,850 to 12,900. NOTE: REDUCED ID = 3.813 @ 9,469’, 9,578’ & 9,647’ Jet Pump: 9A set 6/25/19 _____________________________________________________________________________________ Revised By: TDF 6/4/2021 PROPOSED Milne Point Unit Well: MPU S-35 Last Completed: 8/15/2012 PTD: 203-143 TD = 14,804’ (MD) / TD = 4,110’(TVD) 20” Orig. DF Elev. = 71.68’ / Orig. GL Elev.= 37.9’ Doyon 14 7-5/8” 3 6 7 8 9& 10 11 2 1 NOTE: Flush IA after pulling JP, Brush SS while flushing .IA sands up due to being last well on well row. Min ID 3.725” 9,647’ MD 5 TOC @ ±10,500 4 10-3/4” Fill on jet pump 9,450’ SLM 7/06/19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 5,816’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 10,751’ 0.0459 4” Production Liner 9.5/ L-80/ IBT 3.548 10,650' 14,804’ 0.0122 4” Screen C27 Liner 9.5/ L-80/ IBT-M 3.548 10,761’ 14,757’ N/A TUBING DETAIL 4-1/2” Tubing 12.6/ 13Cr-80/ VAM 3.958 Surface 10,655’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,066’ SLB 4.5” x 1”KGB-2 GLM 2 9,457’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 3 9,469’ 4.5” HES ‘XD’ Dura Sliding Sleeve –3.813” ID, Opens Down 9A JP Set 6-25-19 4 9,479’ SLB Multi-drop Sapphire Gauge – 3.958” ID, SGM-NDPG-CA 5 9,546’ 7-5/8” x 4.5” HES TNT Packer – 3.856” ID 6 9,578’ 4.5” HES X-Nipple –3.813” Packing Bore 7 9,647’ 4.5” HES XN-Nipple -3.813” x 3.725” No-Go 8 10,650’ Baker Tie Back Sleeve 9 10,657’ Baker ZXP Liner Top Packer 10 10,663’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger 11 10,655’ WLEG –4,077’ TVD OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 910sx Arctic Set Light, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 750sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 304’ MD Hole Angle Passes 70 Deg. @ 2,600’ Max Hole Angle in Tubing = 77 deg. 71 Deg. @ Sliding Sleeve WELLHEAD Tree 4-1/16” – 5M CIW Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger. 4” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23175-00-00 Drilled and Completed by Doyon 14 - 9/27/2003 Recompleted by Doyon 14 – 8/15/2012 NOTE: 1. 2’ Blast Rings Below Tubing Hanger. 2. Casing Test to 3,500psi @ 9,546’ 8/17/2012 Double Valve Baker 4-1/2” Float Shoe @ 14,804 Last Cleanout Depth to 13,133’ where CTU had friction lock 3/31/2019. Possible Liner Damage 12,850 to 12,900. NOTE: REDUCED ID = 3.813 @ 9,469’, 9,578’ & 9,647’ Jet Pump: 9A set 6/25/19 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coil Tubing UnitFluid Flow DiagramCleanout w/ Nitrogen & FoamUpdated 9/22/16LEGEND:Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveCheck Valve Manual ChokePressure Gauge500 BBL KILL TANKChoke ManifoldP400 BBL UPRIGHTPOpenVBRBLINDCOIL PUMP400 BBL UPRIGHTOpenClosedOpenOpenOpenOpenOpenOpenOpenPSW or KCLW/FOAMERORFRIC TIONREDUCER50 BBL FREEZEPROTECT TANKSW or KCLW/FOAMERORFRIC TIONREDUCERTo FlowlineNITROGEN PUMP & TANKPCOIL UNIT WITH 1.5” to 2.0” COIL400 BBL UPRIGHTSEAWATERW/DEFOAMERTRIPLEX STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 4 MAY 0 6 2019 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown 11 Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing El Remove and Replace Jet PL* ❑� Plug for Redrill ❑ srforate New Pool ❑ RepairWell[-] Reenter Susp Well ❑ Other: CT Fill Clean-out w/ N2 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Stratigraphic❑ Exploratory ❑ Service ❑ 203-143 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23175-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADLO380109 /ADL0025906 MILNE PT UNIT S-35 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 14,804 feet Plugs measured N/A feet true vertical 4,110 feet Junk measured N/A feet 9,546 Effective Depth measured 13,133 feet Packer measured 10,657 feet 3,882 true vertical 4,094 feet true vertical 4,077 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 12.6 / 13CR-80 / Tubing (size, grade, measured and true vertical depth) 4-1/2" VAM Top & TC -ll 10,655' 4,077' HES TNT Pkr & Packers and SSSV (type, measured and true vertical depth) ZXP Liner Top Pkr N/A See 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: 70 112 550 3,479 234 Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required Per 20 MC 25.070, 25.071, & 25283) 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 El Gas ❑ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-003 Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -Fr/ Authorized Title: Operations Manager Contact Email: twellman2hllcorp.com Authorized Signature: Date 4/24/2019 Contact Phone: 777-8449 iA RBDMS�MAY 0 7 2019 Form 10-404 Revised 4/2017 / Submit Original Only 0 Hileora Alaska, I Orig. DF Elev. = 71.69 / Orig. GL ON. 37.5 Doyon 14 Milne Point Unit Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 PTD: 203-143 WELLHEAD TD =14,804' (MD) / TD=4,11U(TVD) Tree 4-1/16"-5M CIW Wellhead 11"x4.5"5M Gen. 6w/4.5"TC-IIT&B Tubing Hanger. 4" CIW "H" BPV Profile OPEN HOLE/ CEMENT DETAIL PArct20" 260sx of ic Set (Approx) in 42" Hole 30-3/4 9305x Arctic Set Light, 275sx Class'G' in a 13-1/2" Hole 7-5/8" 1 750sx Class "G" in 9-7/8" Hole CASING DETAIL Type Wt/Grade/Conn ID Top Btm BPF Conductor 92/H-40 N/A Surface 110' N/A Surface 45.5 / L-80 / Btc 9.950 Surface 5,816' 0.0962 Intermediate 29.7 / L-80 / BTC -M 6.875 Surface 10,751' 0.0459 Production Liner 9.5/ L-80/ IBT 3.548 10,650' 14,804' 0.0122 Screen C27 Liner 9.5/ L-80/ IBT-M 3.548 10,761' 14,757' N/A TUBING DETAIL Tubing 12.6/ 13Cr-80/ VAM 1 3.958 1 Surface 1 10,655' 0.0152 WELL INCLINATION DETAIL KOP @ 304' MD Hole Angle Passes 70 Deg. @ 2,600' Max Hole Angle in Tubing = 77 deg. 71 Deg. @ Sliding Sleeve JEWELRY DETAIL h Item 51 SLB 4.5"x1"KGB-2 GLM r' SLB Multi -drop Sapphire Gauge —3.958"ID, SGM-NDPG-CA 1' 4.5" HES'XD' Dura Sliding Sleeve w/ Jet Pump —3.813" to, Opens Down -Open 4/3/2019 1' SLB Multi -drop Sapphire Gauge —3.958"to, SGM-NDPG-CA 7-5/8"x4.5"HES TNT Packer — 3.856" ID V 4.5" HES X -Nipple — 3.813" Packing Bore r 4.5" HES XN-Nipple - 3.813" x 3.725" No Go V Baker Tie Back Sleeve T Baker ZXP Liner Top Packer 3' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5' WLEG-4,077-TVD GENERAL WELL INFO API: 50-029-23175-00-00 Drilled and Completed by Doyon 14 - 9/27/2003 Recompleted by Doyon 14 — 8/15/2012 Jet Pump Set - 4/20/2019 NOTE: 1.2' Blast Rings Below Tubing Hanger. 2. Casing Test to 3,500psi @ 9,5468/17/2012 re CTU had friction lock 3/31/2019. to 12,900. Double Valve Baker 4-1/2" Float Shoe @ 14,804 Revised By: TDF 4/24/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig I API Number Well Permit Number Start Date End Date MP 5-35 CTU 50-029-23175-00-00 1 203-143 3/31/19 4/20/19 Daily Operations. 3/27/2019- Wednesday No activity to report. 3/28/2019 -Thursday No activity to report. 3/29/2019 - Friday No activity to report. 3/30/2019 -Saturday No activity to report. 3/31/2019 -Sunday MIRU CTU #6 - 2" CT. Stand by to raise mast until wind speed reduces. Raise Mast. NU BOPE on well and function test. PU injector and 20' of lube. MU Quadco BHA #1- CTC, 2.7" OD XO sub, 2.88" OD DBPV, Jars, Hyd Disco(7/8" ball), 3.63" OD 4" GS spear. CAL = 9.11'. Stab on well, PT low and high- 300/4,OOOpsi. Bleed down to 2,OOOpsi perform check valve test - good. Pad Op shut well in. Close wing valve. Install fusible cap - Open Well to 230/1,500/210. IA pressure falling. RIH with BHA #1. Wt Ck = 18.4k, RIH Wt = 2.8k at 9,303'. Pumping 60/40 down coil at 1.7 bpm. Set down at 9,480' ctmd. SO pumping. Increase s ack off. PU and pull to 40k before freeing X -Lock and Jet Pump. POOH. Tag up at surface. Close SV, BD and pop off well. Recovered jet pump BP -1094 - 3" with 8C ratio. L D tools. MU 4-1/2" BO42 shifting tool set up to shift upwards. Back on well with injector. PT via backside to 300psi / 2,700psi. Open Well and RIH with BHA #2. Wt Ck = 16k, RIH Wt = 3k at 9,400' ctmd. RIH to 9,520', PUH through SS and see Wt increase to 21k at 9,473' (SS at 9,469' MD). Repeat pass with no overpull. SS closed. POOH. Load IA with 40 bbis power fluid/ 45 bbls 60/40. PT SS to 1,575psi - 5 min - 21psi lost. Bleed down to 300psi. Tag up at surface. Close SV, BD and POP off well. L/D tools. Shifting tool pin not sheared. MU Cleanout BHA for tomorrow. Secure well. Night cap BOPE. Remove fusible. SDFN. 4/1/2019 - Monday CT crew/ HAL N2 on site - PJSM. RU N2. PU injector, lubricator, FCO BHA and head to well. Stab on. BHA #3 = 2" CTC, 2.7" OD XO sub, 2.88" OD DBPV, Wt Bar, XRV(extended reach vibratory tool) 2.88" OD Jet swirl nozzle. OAL = 9.82'. PT to 300psi / 2,580psi via backside. Bleed IA from 2,600psi to 300psi. Open Well and RIH with 2.88" OD nozzle. At 5,300' while RIH, PT N2 line to 5,000psi. Start pumping N2 at 1000 scf/m - Fluid rate at 1.5 bpm (SLK 1%) Returns established at 5,700' while RIH with 200psi WHP and FOC - Set pumping parameters with Fluid rate at 1.3 bpm / N2 rate at 1,300 scf/m for maintaining returns with positive WHP. Enter liner, clean out in 300' bites with 900' wiper trips. Pumped 5 bbl N -Vis Gel w/.6% NXS lube for gel sweeps on every bite. Coil went to lockup at 13,133' so unable to get deeper. Pump 35 bbl final gel sweep off bottom. Able to keep 70-150psi WHP throughout and -60% returns. POOH, chasing returns to surface at 80%. Bleed IA pressure off 3 times throughout day due to thermal expansion, as it is fluid packed. At surface. Close SV, BD, and pop off. L/D tools. Bleed down IA to Opsi. RDMO. 4/2/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Slickline 50-029-23175-00-00 203-143 3/31/19 4/20/19 Daily Operations. 4/3/2019 - Wednesday PT PCE 250psi LOW, 3,500psi HIGH. SHIFT XD SLIDING SLEEVE DOWN TO THE OPEN POSITION @ 9,438' SLM (9,469' MD). SET 4-1/2" X -LOCK W/ 3" JET PUMP & SCREEN IN XD SLIDING SLV @ 9,435' SLM / 9,469' MD (oal-70, ratio -8C, ser.# - BP - 1038). OPERATION UNABLE TO BRING WELL ON-LINE, IA PRESSURES UP TO 3,500psi. PULLING 4-1/2" X -LOCK W/ 3" JET PUMP FROM XD SLIDING SLV @ 9,435' SLM / 9,469' MD (8C -ration, ser.# - BP -1038). 4/4/2019 - Thursday PT PCE 250psi LOW, 3,500psi HIGH. SHIFT XD SLIDING SLEEVE TO THE OPEN POSITION @ 9,435' SLM / 9,469' MD, GET STUCK IN XD SLIDING SLEEVE WHILE ATTEMPTING TO SETJET PUMP. DROP ROLLER STEM CUTTER BAR ASSEMBLY. WIRE DIDN'T CUT. TOOL STRING CAME FREE. PULL UP HOLE. TOOL STRING STUCK AT 2,661' WLM. WAITING ON ANOTHER CUTTER. 4/5/2019 - Friday DROPPED 3 MORE CUTTER BAR ASSEMBLIES. PT PCE TO 250psi, 3,500psi HIGH. LATCH CUTTER BAR @ 2,599' SLM & PUSH TOOLS DOWN TO 2,702' SLM BUT SHEAR 2-1/2" RS INSIDE 3.60 BELL GUIDE. LATCH CUTTER BAR @ 2,700' SLM AND HIT 8/10 SPANG LICKS AND SEE 50# WEIGHT INCREASE BUT NO CUTTER BAR ON TOOLS. 4/6/2019 -Saturday PT PCE TO 250psi LOW, 2,500psi HIGH. RETRIEVED 1-7/8" CUTTER BAR W/ ONE 3.00" CENT. RETRIEVED 1.88" CUTTER BAR W/ TWO 3.25" CENTS. 4/7/2019 -Sunday PT PCE TO 250psi LOW, 2,500psi HIGH. PLANT 4-1/2" BAIT SUB, 2'x1-7/8" STEM, 3.61" CENT, 2 -PRONG WIRE GRAB W/ CENTER SPEAR ON FISH @ 2,706' SLM. PULL FISH UP TO 1,809' SLM. SHEAR OFF AND LEAVE FISH THERE. GATHER UP RISER & OTHER TOOLS FOR JOB TOMORROW. 4/8/2019 - Monday PT PCE TO 200psi LOW, 300psi HIGH. PULLED APPROX 40 BALL OF.125 STAINLESS WIRE W/ 2' PRONG WIRE GRAB W/ CENTER SPEAR'. PULLED 8' OF .125 STAINLESS WIRE W/ BRUSH & SCRATCHER ASSEMBLY TOP OF FISH @ 2,794' SLM. 4/9/2019 -Tuesday PT PCE: 10OL/ SOON. Multiple runs to fish for wire and cutter bars. Got 5' of out. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Slickline 50-029-23175-00-00 203-143 3/31/19 4/20/19 Daily Operations. 4/10/2019- Wednesday WELL S/I UPON ARRIVAL, CONTACT PAD -OP, PT PCE: 10OL/ SOON. Slickline fish approx. 24.5' of wire and flat btm go devil bar. WELL S/I UPON DEPARTURE, NOTIFY PAD -OP. 4/11/2019 - Thursday WELL S/I UPON ARRIVAL, CONTACT PAD -OP, PT PCE: 10OL/ SOON. RUN 3.25" LIB, S/D @ 2,804' SLM, GET F/N. IMPRESSION OF CUTTER BAR. PULL FINAL CUTTER BAR ASSEMBLY FROM 2,804' SUM. GET IMPRESSION OF WIRE @ 9,422' SUM. FIELD HAS GONE PHASE 2, L/D FOR HIGH WINDS. 4/12/2019 - Friday No activity to report. 4/13/2019 -Saturday No activity to report. 4/14/2019 -Sunday WELL S/I UPON ARRIVAL, CONTACT PAD -OP, PT PCE: 100L/ 500H. MAKE MULTIPLE RUNS WITH WIRE GRAB FISHING ASSEMBLY. GO AS DEEP AS 3500' SLM BUT RECOVER NOTHING. WELL S/I UPON DEPARTURE, NOTIFY PAD -OP. 4/15/2019 - Monday Well shut in upon arrival. (frz prt Tbg & IA). Pressure test 250/3,000 surface line and equipment. Freeze Protect (Pre Slickline work) Pump 10 bbls 60/40 down IA. Pump 10 bbls 60/40 down Tbg. Well left shut in upon depature - notified pad op of well status. 4/16/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 3/31/19 4/20/19 Daily Operations. 4/17/2019- Wednesday No activity to report. 4/18/2019 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, 3RD PARTY CRANE, PT PCE 250L/2,500H. LRS PUMPED 180bbls PRODUCED WATER/30bbls 60/40. RUN 3.00" LIB TO 9,195' SLM (no impression on bottom, small marks around edge, possible wire). RUN 3-1/2" GR, 3-1/2" BAIT SUB, 4.5" WIRE FINDER, 4.5" BRUSH, 4.5" SCRATCHER, 2-1/2" JUS (split skirt) TO 9,424' SLM (nothing recovered). **L/D FOR THE NIGHT, NOTIFY PAD -OP. 4/19/2019 - Friday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, 3RD PARTY CRANE, PT PCE 250L/2,500H. Fished approx. 20' of wire, toolstring and jet pump from 9,417' SLM. RUN 3.805" G -RING TO 9,466' SLM (hang up —15min at 9,456' SLM) **L/D FOR THE NIGHT, NOTIFY PAD -OP. 4/20/2019 -Saturday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. PERFORMED B&F WHILE INJECTING POWER FLUID AT —1,500bwpd. SET 3"" JET PUMP (serial# BP -1038, ratio: 8C, OAL=70"", sec lock) IN XD -SS AT 9,469' MD WITH POWER FLUID AT-1500bwpd. TAG WELL. NOTIFY PAD -OP TO BRING WELL ONLINE, RDMO. 4/21/2019 -Sunday No activity to report. 4/22/2019 - Monday No activity to report. 4/23/2019 -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 S-35 Permit to Drill Number: 203-143 Sundry Number: 319-143 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.aogcc.olaska.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, Daniel T. Seamount, Jr. Commissioner DATED this day of March, 2019. RBDMS ZA/MAR 2 9 2019 RECEIVED STATE OF ALASKA MAR 2 2 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 1. Type of Request: Abandon ❑ Plug Perforations V Mli GJ.G.v ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Remove and Replace Jet Pump ❑� Plug for Redrill El Perforate New Pool ❑ Re-enter Sus P Well El Alter Casing El Other: CT N2 Fill Clean-out ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development:E] • 203-143 - Stratigraphic ❑ Service 6. API Number: 3.Address: 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 50-029-23175-00-00 7. If perforating: 6. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No Q - MILNE PT UNIT S-35 9. Property Designation (Lease Number): .zs 10. Field/Pool(s): (' ADL0380109 / ADLO 9 MILNE POINT / SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi):Plugs (MD): Junk (MD): 14,804 4,110 - 12,756 4,099 850 N/A 12,756 (Fill) Casing Length Size MD ND Burst Collapse Conductor 110 20" 110' 110' N/A N/A Surface 5,816 10-3/4" 5,816 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,75V 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6 11 13CR-80 / VAM Top & TC -II 10655 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): HES TNT Pkr & ZXP Liner Top Pkr and N/A 9,546(MD) / 3,882(TVD)& 10,657(MD)/ 4,077(TVD) and N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 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: 3/29/2018 OIL ❑✓ WIND ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Chad Helgeson Contact Name: Taylor Wellman -7n/ Authorized Title: Operations Manager Contact Email: iWBII111BD hIICOr .COrn Contact Phone: 777-8449 Authorized Signature: Date: 3/22/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 319 -1y Z) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ ?MAR J QBDMS 2 9 2019 Spacing Exception Required? Yes E]( No ©' Subsequent Form Required: / ©� [ o APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dater L I 31�411°� �b 1a� 1,4�44ra Form 10-403 Revised 4/2017 A Submit Form and pproved appli ti al fo NALm the date of approval. Attachments in Duplicate 3 zG "q K Hikorp Alaska, LG CT N2 Foam FCO Well: MP 5-35 Date: 03/22/2019 Well Name: MPU 5-35 API Number: 50-029-23175-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S -Pad Estimated Start Date: March 29, 2019 Rig: Coil Tubing Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-143 First Call Engineer: Taylor Wellman (907) 777-8449 (907) 947-9533 (C) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: Coil Foam Cleanout Current Bottom Hole Pressure: 1,250 psi @ 4,000' TVD (Last BHP measured 2/20/2015) Maximum Expected BHP: 1,250 psi @ 4,000' ND (No new perfs being added) MPSP: 850 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU 5-35 was drilled in 2003 using Doyon 14 and completed as a single -lateral in the Schrader Bluff N sand with a Jet Pump. The completion was pulled and changed out in 2012 using Doyon #14 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome. A fill cleanout in late November 2015 was unable to cleanout fill due to not being able to lift fluids effectively to surface. An N2 fill cleanout in May 2016 cleaned out to 13,077' md. An N2 foam fill cleanout in May 2017 cleaned out to 12,756' md. The September 2018 N2 cleanout reached 12,800' md. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.7" @ 3,540'). Deviation at pump is 72°. • Casing last tested to 3,500 psi for 30 min down to 9,546' on 11/18/2015. • Jet Pump pulled on 09/29/2018 using coil. New pump (8C) set by s� lickline on 10/07/2018. Obieetive: 5:C,3 Perform a nitrified foam clean out of the lateral to regain production from the toe of the well. Procedure: Slickline (Non Sundried Operations) 1. RU SL and pressure test PCE to 250psi/1,500psi high. 2. Pull 3" Jet pump from 9,469' md. a. Ability to pull JP has had success and failure with slickline. Displacing tubing to clean fluid 5 Q with pump truck and assistance to pump to depth may be required. {� 55 b. Description of JP set on 10/07/2018: 3" JET PUMP (serial# BP -1094, ratio: 8C, OAL=70"", sec lock C (off down) IN XD -SS AT 9469' MD. 3. RIH w/ shift SSD closed (up to close). a. Confirm by pressuring the IA with 1,500psi for 5 min. ✓ 4. RD SL unit. Coiled Tubing 5. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 6. Pressure test BOPE to 250 Low/ 3,500psi Hi, 10 min Hi, 5 min Low each test ,/ a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. CT N2 Foam FCO Nilcora Alaska, LU Well: MP 5-35 Date:03/22/2019 b. Each subsequent test of the lubricator will be to 250 Low/ 3,500psi Hi to confirm no leaks. c. No AOGCC notification required. d. Record BOPE test results on 10-424 form. 7. Conti (if Slickline unable to recover Jet Pump) - RIH w/ 2.00" coil and pull jet pump at 9,469' md. a. WSM discretion to pump metal to metal friction reducer out of coil while RIH to prevent coil abrasion from 13Crtbg. 8. Contingency (if Slickline unable to shift closed) - RIH w/ 2.00" coil and shift SSD closed (up to close) at 9,469' md. a. Test backside to 1,500 psi for 5 min to confirm closed. 9. RIH w/ 2.00" coil w/ 2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA (Tempress or similar tool) and cleanout to PBTD at+/- 14,804' MD. POOH. a. Note there is possible liner damage noted at ±12,800' md. Ensure all edges on BHA are smooth and beveled (no hard ledges) on top/bottom to prevent hang up passing this point. The BHA's from 2016-2018 changed slightly. Recommend using a larger than 2.3" nozzle to reach beyond 12,800' md. Review WSR's from May 2016, May 201717, and September 2018. A `v b. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix withN� itrogen (see Nitrogen 'v © procedure and diagram). Utilize defoamer for returns in Kill Tank. L During the 2017 FCO foamer was used and returns were better than in the 2018 FCO. c. Use gel sweeps as needed and mix in metal to metal friction reducer as needed into either chase fluid or gel sweeps. Contact OE for discussion on type of friction reducer to be used. 10. Once final depth is achieved POOH and freeze protect well. 11. RIH and shift sliding sleeve open at 9,469' MD. a. Contact OE prior to this step for discussion. If extends to an additional day to achieve this step may be attempted with SL. b. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 12. RD Coiled Tubing and ancillary equipment. Slickline 13. RU SL and pressure test PCE to 250psi/1,500psi high. 14. Set 3" Jet pump from 9,469' md. a. Description of JP set on 10/07/2018: 3" JET PUMP (serial# BP -1094, ratio: 8C, OAL=70"", sec lock down) IN XD -SS AT 9469' MD. 2. RD SL unit. Attachments: 1. As -built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram rT I Ong. DF Elev. = 71.68 / Orig. GL EIW. 37.9' Doyon 14 103/4 FF NOTE: MINIMUM ID=3.813 @ 9,469', 9,578'& 9,647' 2 3 q P ,/„ 4 6 7 5 Milne Point Unit Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 PTD: 203-143 WELLHEAD OPEN HOLE / CEMENT DETAIL 20" --!6-Os- of Arctic Set (Approx) in 42" Hole 935x Arctic Set Light, 275sx Class'G' in a 13-1/2" Hole 7-5/8" 1 7505x Class "G" in 9-7/8" Hole CASING DETAIL Size Tree 4 -1/16" -SM CIW ID Wellhead 11"x4.5"SM Gen. 6w/4.5"TC-IIT&B Tubing Hanger. 4" CIW "H" BPV Profile OPEN HOLE / CEMENT DETAIL 20" --!6-Os- of Arctic Set (Approx) in 42" Hole 935x Arctic Set Light, 275sx Class'G' in a 13-1/2" Hole 7-5/8" 1 7505x Class "G" in 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID I Top I Btm BPF 20" Conductor 1 92/H-40 I N/A I Surface 1 110' N/A 10-3/4" Surtace 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/ L-80/ IBT 3.548 10,650' 14,804' 0.0122 4" Scfeen C27 Liner 1 9.5/ L-80/ IST -M 3.548 10,761' 14,757' N/A TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP IT 304' MD Hole Angle Passes 70 Deg. @ 2,600' Max Hole Angle in Tubing = 77 deg. 71 Deg. @ Sliding Sleeve JEWELRY DETAIL No I Depth Item 1 2,066' SLB 4.5" x 1"KGB-2 GLM 2 9,457' SLB Multi -drop Sapphire Gauge - 3.958" ID, SGM-NDPG-CA 3 9,469' 4.5" HES 'XD' Dura Sliding Sleeve -3.813" ID, Opens Down (8C Jet Pump) 5/17/2017 4 9,479' SLB Multi -drop Sapphire Gauge - 3.958" ID, SGM-NDPG-CA 5 9,546' 7-5/8"x4.5"HES TNT Packer - 3.856" ID 6 9,578' 4.5"HES X -Nipple - 3.813" Packing Bore 7 9,647' 4.5" HES XN-Nipple - 3.813" x 3.725" No Go 8 10,650' Baker Te Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 1010,663' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 11 10,655' 1 WLEG - 4,077'TVD LAST TAG @ 11,600' 10/2/2018 Possible Liner Damage 12,850 to 12,900. TD =14,804' (MD) / TD = 4,110'(TVD) GENERAL WELL INFO API: 50-029-23175-00-00 Drilled and Completed by Doyon 14 - 9/27/2003 Recompleted by Doyon 14 - 8/15/2012 NOTE: 1. 2' Blast Rings Below Tubing Hanger. 2. Casing Test to 3,500psi @ 9,546' 8/17/2012 Double Valve Baker 4-1/2" Float Shoe @ 14,804 Revised By: TDF 10/16/2018 0 1 COIL BOPE MILNE POINT UNIT MPU S-35 Ilileorp AI:�=ka, LLf. MPU S-35 20X10%X7%X4X Coil Tubing BOP Crossover spool 4 1/16 10M X 4 1/16 5M Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic Valve, Lower Master, WKM-M, 4 1/16 5M FE Tubing Adapter, 4 1/16 5M Lubricator to injection head 0, S,. S yaAge,0.1�16 1502 Union STANDARD WELL PROCEDURE IGlcorpAlaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 n Ill.., to." 1.M Open Open open Open 500 BBL KILL TANK 50 BBL FREEZE PROTECTTANK Updated 922/16 Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam SW or KCL W/ 400 BBL UPRIGHT FOAMER OR FRICTION 400EGLUPRMHT I SW.' KCL W/ FOAMER OR FRICTION COIL UNIT WITH 1.5- to 2.0" COIL Choke Manifold COILPUMP NITROGEN PUMP & TANK LEGEND: Fluids Pumped . en open 400 BBL UPRIGHT SEAWATER I9 -— W/ DG open DEFOAMER T_TFlowiine Check Valve N open yj em:ea Pressure Gauge Op open TRIPLE% e4 500 BBL KILL TANK 50 BBL FREEZE PROTECTTANK Updated 922/16 Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam SW or KCL W/ 400 BBL UPRIGHT FOAMER OR FRICTION 400EGLUPRMHT I SW.' KCL W/ FOAMER OR FRICTION COIL UNIT WITH 1.5- to 2.0" COIL Choke Manifold COILPUMP NITROGEN PUMP & TANK LEGEND: Fluids Pumped . Fluids Returned Q Valve Open Valve Closed Gate Valve DG Ball Valve CGtt Butterfly Valve Lo Torq Valve tMJ Check Valve N Manual Choke 9 Pressure Gauge Op OF Tit • • �sA THE STATE Alaska Oil and Gas ��,. �� Of LAcc Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 () 411.1.A511-1.' P Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager ����E� :JAN Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU S-35 Permit to Drill Number: 203-143 Sundry Number: 318-003 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, Hollis S. French l� '� Chair 1. DATED this day of January, 2018. V • • RECEIVED STATE OF ALASKA JAN 0 2 OI8 ALASKA OIL AND GAS CONSERVATION COMMISSION / 1 d APPLICATION FOR SUNDRY APPROVALS � 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Remove and Replace Jet Pump 0• Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out D• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Wf N Z Hilcorp Alaska LLC • Exploratory ❑ Development Q. 203-143' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service a 6.API Number: Anchorage Alaska 99503 50-029-23175-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05' Will planned perforations require a spacing exception? Yes ❑ No ❑ ! MILNE PT UNIT S-35 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109/ADL0025639 ' i 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): 14,804 4,110 - 12,756 . 4,099 850 N/A 12,756(Fill) Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/13CR-80/VAM Top&TC-II 10655 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES TNT Pkr&ZXP Liner Top Pkr and N/A • 9,546(MD)/3,882(TVD)&10,657(MD)/4,077(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development Q' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/17/2018 Commencing Operations: OIL Q ' WINJ ❑ WDSPL ❑ Suspended a 16.Verbal Approval: Date: GAS a WAG a GSTOR ❑ SPLUG a Commission Representative: GINJ a Op Shutdown a Abandoned a 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: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhoIa(p,hiIcorp.com Contact Phone: 777-8412 Authorized Signature: 2172 --s--- Date: 1/2/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3 j Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance a Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes a Nod Subsequent Form Required: I Q ( 0 4,4 APPROVED BY I l I Approved by: COMMISSIONER THE COMMISSION Date: ( led 4t( �� ORIGINAL , ' Submit Form and Form 10 403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate \, • • Well Prognosis Well: MP S-35 1:Iilcorp Alaska,LL Date: 1/02/18 Well Name: MPU S-35 API Number: 50-029-23175-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: January 17th, 2018 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-143 First Call Engineer: Stan Porhola (907) 777-8412 (907) 331-8228 (C) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Job Type: l Foam Clear p , Current Bottom Hole Pressure: 1,250 psi @ 4,000' TVD (Last BHP measured 2/20/2015) Maximum Expected BHP: 1,250 psi @ 4,000' TVD (No new perfs being added) ✓ MPSP: 850 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU S-35 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump.The completion was pulled and changed out in 2012 using Doyon#14 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome. A fill cleanout in late November 2015 was unable to cleanout fill due to not being able to lift fluids effectively to surface. A fill cleanout in May 2016 cleaned out to 13,077' MD. A fill cleanout in May 2017 cleaned out to 12,756' MD. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.7° @ 3,540'). Deviation at pump is 72°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546' on 8/14/2012. • Polished tie-back sleeve with Doyon#14 in 2012. • Jet Pump pulled on 5/12/2017 using coil. New pump (8C) set by slickline on 5/17/2017. • ***Jet Pump may be pulled by slickline, not coil tubing unit*** • ***Sliding sleeve may be shifted closed/open by slickline, not coil tubing unit*** Objective: The purpose of this work/sundry is to pull the existing Jet Pump, perform a foam cleanout of the lateral and run a new Jet Pump. ✓ Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and pull jet pump at+/-9,469' MD (if not pulled by slickline). 4. RIH w/2.00" coil and shift sliding sleeve closed at+/-9,469' MD (if not closed by slickline). • Well Prognosis Well: MP S-35 IIilcorn Alaska.LL Date: 1/02/18 5. Test backside to 3,500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. 6. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. 7. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. C' a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 8. RIH and shift sliding sleeve open at+/-9,469' MD (if not to be opened by slickline). 9. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 10. PU to 2,500' and freeze protect well. POOH w/coil. 11. RD Coiled Tubing and ancillary equipment. 12. Turn well over to production. ,31 .1 A-4'v!Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen&Foam Flow Diagram •H H . • Milne Well: Point MPU 5-35Unit SCHEMATIC Last Completed: 8/15/2012 Hilcorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"-5M CIW Orig.DF Elev.=71.68'/Orig.a Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.4"CIW"H"BPV Profile j , t OPEN HOLE/CEMENT DETAIL 20 ? 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class`G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP@304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 10-3/4'1 4 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down(8C Jet Pump)5/17/2017 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG—4,077'TVD " ° NOTE: GENERAL WELL INFO P P' MINIMUM ID=3.813 @ API:50-029-23175-00-00 9,469',9,578'&9,647' Drilled and Completed by Doyon 14 -9/27/2003 V 2 f" — Recompleted by Doyon 14—8/15/2012 it [ a a �I 1 13 NOTE: m. 4 1.2'Blast Rings Below Tubing Hanger. 2.Casing Test to 3,500psi @ 9,546'8/17/2012 1 s 4 a 7 4, I v LAST TAG @ 12,756'5/13/2017 Possible Liner Damage 12,850 to \s.„......... 9 12,900. l' &10 im- 7-5/8 11� Double Valve Baker 4-1/2" Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) i , Revised By:TDF 5/24/2017 • • . fi COIL BOPS MILNE POINT UNIT MPU S-35 liilcorp Alaska,LLC 1/02/2018 MPU S-35 20 X 10% X 7% X 4/2 Coil Tubing BOP f Lubricator to injection head JCI 0 1 l 43) 2.00"Single Stripper i/ie is = Blind/Shear Blind/Shear — _ :Di €= Blind/Shear Blind/Shear, 1 ,.,0 Eo mil _ um ——_ Slip111111— Slip 11111.(1 11 € - Pipe '■ Pipe 114 MIL Crossover spool 4 1/16 10M X 4 1/16 5M goo Pump-In Sub It'" t 1 � 1111:1°I�� 4 1/16 5M iI. ( :/ ` hill 1502 Union Manual Gate Manual Gate Valve,Swab,WKM-M, r• 2 1/8 5M 2 1/8 5M 4 1/16 5M FE si- �� { (o) Valve,Upper Master,Baker, ,• , 4 1/16 5M FE,w/Hydraulic O ; .., Valve,Lower Master,WKM-M, bt o" 4 1/16 5M FE iidi lima 111 MT III Tubing Adapter,4 1/16 5M r 111WIL fir • • STANDARD WELL PROCEDURE Hik oipAlaska.11€ NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 0 l rP x -1___A ON , . " > o E YW Q U W Q id A O . w > ro aa ~ a _ u °wo3o � o3oE V A z a a `s„e j a a' `° > own Z c A v y. oz O -,-._ Fcc m W m y • URU -1riffillii 1..; x •i- : ?� r ' .a Z . o 2 ca0 L V • IME I 7 Leti.'''' 0. TM , 3 V ' k6,,Ni ,.. 1 II - 1 A0055 11g19 Am liil IIl] $/ ,11;011,, ( j]j] ■me lilt lin ee 4 4 O O O W Y W Z W W F O. fYiLL0 iii O p O p m W tG ~ n 5 Va ro- 8 Z-E>.- z W W Q Q Q 3 o Y z L.,- F J 1- Y x LI m C m a o N 0 0 0 0 a 0 • STATE OF ALASKA AIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Remove and Replace Jet Pump 0 Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development 0 Exploratory ❑ 203-143 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-23175-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109/ADL0025639 MILNE PT UNIT S-35 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 14,804 feet Plugs measured N/A feet true vertical 4,110 feet Junk measured 12,756(FILL) RECEIVED 9,546 Effective Depth measured 12,756 feet Packer measured 10,657 feet MAY 2 ,5 2017 3,882 true vertical 4,099 feet true vertical 4,077 feet . OGCC Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation depth Measured depth See Schematic feet2 s`ANN�® - i f\' r, 1 True Vertical depth See Schematic feet 12.6/13CR-80/ Tubing(size,grade,measured and true vertical depth) 4-1/2" VAM Top&TC-ll 10,655' 4,077' HES TNT Pkr& Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top Pkr N/A See 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: 53 30 342 3,403 239 Subsequent to operation: 20 8 769 3,476 240 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 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR 0 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: 317-126 Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title. Operations Manager Contact Email: Sporhola@hilcorp.corn 7. Authorized Signature:` 4,•/; %,. Date 5/24/2017 Contact Phone: 777-8412 Form 10-404 Revised 4/2017 Submit Original Only RBDMS A9 252017 . II • Ill Milne Point Unit • Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 tlileorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"—5M CIW Orig.DF Elev.=71.68'/Orig.GL Elev.37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-Il T&B Tubing Hanger.4"CIW"H"BPV Profile 20" L' x OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP@304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL 3.0-3/4"4No Depth Item 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down(8C Jet Pump)5/17/2017 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' W LEG—4,077'TVD NOTE: GENERAL WELL INFO Ps 7 MINIMUM ID=3.813 @ API:50-029-23175-00-00 }: '' 9,469',9,578'&9,647' .i % Drilled and Completed by Doyon 14 -9/27/2003 2 ' Recompleted by Doyon 14—8/15/2012 4 x 1 3 v NOTE: )1 4 t' 1.2'Blast Rings Below Tubing Hanger. l, 2.Casing Test to 3,500psi @ 9,546'8/17/2012 1 ' '1 6 i /2 LAST TAG @ 12,756'5/13/2017 Possible Liner Damage 12,850 to 8 12,900. 7-5/8"k''' 11 9&10 \`\ sM! Double Valve Baker 4-1/2" 4` Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Revised By:TDF 5/24/2017 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 5/12/17 5/15/17 Daily Operations; j.. 5/10/2017-Wednesday No activity to report. 5/11/2017-Thursday No activity to report. 5/12/2017-Friday Road CT equipment from MPI-12 to MPS-35 MIRU Halliburton CT with 2"Coil. BOPE test MU BHA for run#1-Pull Jet pump.Get on well. PT 250/3,500psi. Install fusible cap.Open well-T/I/0=0/173/206 RIH with BHA#1-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD U/D jars,2x Wt Bars,2.13"OD hyd disconnect(5/8" ball),X0,3.5"OD(4"GS). OAL=18.51'. (JP is 5.8'+18.51'=24.31').Set down at 9,481'ctmd,set down 5k at 9484, PU to 31k. Hit jar lick,Straight pull to 33.5k and pull free. RBIH to 9,484'set down 5k. PU to 23k,wt broke over. POOH Tag up at surface.Close swab, BD,and pop off well. Recovered jet pump(BP-1084 3"8C).Also recovered 3 balls of metal shavings on tools. L/D pump and MU B042 shifting tool set to shift sleeve up to close.OAL of BHA#2=20.01'. Back on well. PT via back side to 250/3,500psi. RIH with BHA#2-shifting tool.Wt Ck At 9400'-16.8k. RIH past SS at 30 fpm. RIH Wt=2,234 lbs. PUH 25 fpm to shift sleeve closed.Saw 3k overpull at 9,486'ctmd.good indication. RBIH past sleeve.Saw sleeve again on 2nd pass up same depth. RBIH and repeat. Fill IA with power fluid to pressure up to—3,300psi."3,300psi on Annulus.Sleeve appears closed.Chart pressure for 10 min.OOH Tag up at surface.Close swab, BD,and pop off well.OOH with shifting tool. Pin not sheared. Stand back injector. Night cap BOPE.Secure Well. MU BHA for Foam clean out operation. PT BHA to 3,500psi. Leave location.SDFN. 5/13/2017-Saturday Crews on site. Fire up equuipment. PJSM-Discuss job procedure,hazards associated with N2,wind direction,muster, emergency contacts,good communication.Stab on well. Fluid pack out to tanks.SI and PT low-250psi/3550psi-high. BD to 500psi.Open well.T/I/O=0/0/6 RIH with BHA#3-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD U/D jars, 2.13"OD hyd disconnect(5/8" ball),Burst sub(6k),Tempress scree sub,Tempress tool,2.3"OD JSN.OAL=13.85'.Choke closed PT N2 hardline to 5k. Park coil at 3500'. Bring N2 on 750 scf/m.Open choke full open. 20,000 scf pumped. No returns. Returns started. Mostly gas/slight fluid. RIH at 30 fpm Start pumping foam with coil at 6370'ctmd. RIH to TT. 1- 1.5 bpm fluid/1,500 scf/m N2-3,800-4,200psi CTP/280-400psi WHP. From TT, RIH taking 300'bites,50 ft short trip for wt check and spacer in between bites. Repeat until lockup at 12,455'.Trip up to 10,000 ft. RIH to lockup at 12,575'.Trip up to 10,000'. RIH to lockup at 12,700'.Trip up to 10,000'. RIH to lockup at 12,756',unable to get deeper POOH from 12,756'at 6-10 fpm jetting liner clean.At,12,300'while pooh 100 fpm,shut down pumping fluid,pump N2 Only at 1500 scf/min.Shut down N2 at 6,000'. Let well bleed down from 225psi WHP.Tag up at surface.Close swab, BD,and Pop off well.Secure well Stand back injector.SDFN. i • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 5/12/17 5/15/17 Daily Operations: 5/14/2017-Sunday Crew on site. Fire up equipment. PJSM with HES and BOT. LID tools from FCO operation. MU B042 shifting tool set to shift sleeve down to open.On well. PT via backside 250psi low/3,550psi high.Open well. Install fusible cap.T/I/0= 234/130/218 RIH with BHA#1-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD U/D jars,2x Wt Bars,2.13"OD hyd disconnect(5/8" ball),XO. B042 shifting tool.OAL=20.01'. Pressure up IA while RIH to 900psi.Wt Ck=13.7k, RIH Wt= 700 lbs at 9,153'. RIH at 35 fpm to shift sleeve open, RIH Wt=1300 lbs(sleeve at 9469')Took 6 attempts to open sleeve. Would just stack out on it. Reduced IAP to 300psi after 2nd try. Reduced it 44psi after 3rd try.Try#6-RIH 95 fpm,set down-30k,got wt back and passed through sleeve. Make U/D pass through sleeve to confirm. POOH.Turn on power fluid at 3300 bpd,no IAP increase. IA on vac Tag up at surface,close swab, BD,and pop off well. L/D shifting tool. Pin not sheared. MU BHA#2-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD U/D jars,2.13"OD hyd disconnect(5/8" ball),2.11"OD Si Di hiptripper,XO to SR,4-1/2 X-Line running tool,4-1/2"X-Lock,3" RC OM jet pump Serial#BP-1082/ Ratio 8C. (JP is 5.8')OAL=21.59") PT tool string to 3,500psi.On well. PT via backside Open well. RIH with Jet pump.Wt Ck= 13.2k, RIH Wt=700 lbs-6000'.Wt Ck=18.5k, RIH Wt=3000 lbs-9,405' Ran in hole past SS to 9,500'. Pull up through sleeve to shift lock into control position.Saw overpull at 9,480'. RBIH to locate X-nipple. Ran past sleeve did not locate. PUH to shift lock again.Tag up on nipple and overpull up to 31,000 lbs.Stop coil.Wait for jars to fire.Jars didn't fire. Straight pull up to 40k.Can't pull through. RBIH to 9,500'. PUH and pull through will a a little bobble. RBIH to locate X- nipple. Locate and set down 20k.Wait for jars to fire. PU to neutral wt and bring pump on line down coil.Catch fluid and RIH slowly hip-tripping to shear upper pin.2nd stall at 9,479'. FS of hip tripper is 1.2 bpm at 1,870psi.Stall pressure went to 3,500psi. Hip trip down at 1.5 bpm to stall.Set down 20k.Jars fired. PU and watch for overpull.Saw 10k overpull then shear off.Turn on power fluid. IA building pressure. IAP stabilized.Waiting for WHP to increase. Power fluid rate stopped. No flow through jet pump. POOH.Shut in power fluid,shut in casing valve. Bleed IAP down to 660psi.Tag up at surface, close swab,BD,and pop off well.Jet pump recovered. L/D tools. MU tools for shifting tool run.Secure well and equipment. SDFN. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 5/12/17 5/15/17 Daily Op6rations:' 5/15/2017-Monday Arrive on location. PJSM. MU Shifting tool BHA.On Well. PT 205psi low/2370psi high-via backside. Open well-T/I/0=0/633/203 RIH with BHA#1-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD U/D jars,2x Wt Bars,2.13"OD hyd disconnect(5/8" ball),XO. B042 shifting tool.OAL=20.01'. Wt Ck at 9,280'=13.6k. RIH Wt=2k Set down to 9494'with 20k down.Jars fire. PUH and RBIH to open sleeve Tag sleeve,set down 20k again. No shift,but losing IAP. PUH and RBIH again.Set down on sleeve again. No shift PUH above sleeve make 4th pass down to open sleeve.Open sleeve on 4th attempt. IAP dropped off. Make U/D pass through sleeve.Good. POOH Whille POOH,turn on power fluid to IA at 1800 bpd.After 25 minutes, no increase in IAP Tag up at surface.Close swab, BD,and POP off well. LID shifting tool. Pin not sheared. MU BHA#2-2"OD internal dimple connector,2.12"OD DBPV,2.25"OD ACCL,2 x wt bars,2.25"OD U/D jars,2.13"OD hyd disconnect(5/8" ball),2.11"OD Si Di hiptripper,XO to SR,4-1/2 X-Line running tool,4-1/2 X-Lock,3" RC OM jet pump Serial#BP-1082/Ratio 8C. (JP is 5.8') OAL=35.17').On Well. PT via backside low/high Open Well and RIH with jet pump.T/I/O=0/16/197.At 8000' RIH,Turn power fluid on to start filling annulus-1750 bpd.Wt Ck at 9200'is 17,600 lbs. RIH at 30 fpm to locate X-nipple at 9,469' MD Locate nipple at 9488'.Set down 15k at 9494'. Let jars fire. PU to neutral wt,pump down coil at 1-1.3 bpm, RIH firing hip- tripper until stall,set down 20 to 30k after stall and fire jars trying to shear upper pin and close lock. Repeated this process 10 times.Good indication of hip-tripper action.Jars fired all times. PU for overpull. Pull to 32k,stop to fire jars and shear off lower pin. Pulled free.Turn on power fluid. NO increase in IAP. RBIH to locate on X-nipple again. Ran past sleeve. Keys on lock retracted. POOH. Isolate power fluid.Tag up at surface.Close swab, BD,and POP off well. Recovered Jet pump. Keys on lock are retracted. Lower packing all in place, upper packing missing 1/2 of 1 packing ring. L/D all BHA. Upper pin to set lock is not sheared. Lower pin may be sheared,causing keys to retract. Rig up N2 to blow down reel. Back on well. Boost pump on N2 unit not working.Call out 2nd unit.2nd N2 unit on site. Blow reel down with 90,000 scf N2. RDMO CT equipment. Haul off all Returns.Wells Support rig off well. 5/16/2017-Tuesday No activity to report. • VOF ?11 w\��\�y/��s� THE STATE Alaska Oil and Gas ti�►:.'s=����, of T cKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFALAS Main: 907.279.1433 Fax907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCANNED APR1f)2017 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU S-35 Permit to Drill Number: 203-143 Sundry Number: 317-126 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, P22.44.,14- Cathy . Foerster Chair DATED this day of March, 2017. RBDMS LOPR - 3 1017 III • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 4 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ID Suspend El Perforate ❑ Other Stimulate El Pull Tubing ❑ Remove and Replace Jet PumpE Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out CI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑' ' 203-143 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23175-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 - ?4t6 Will planned perforations require a spacing exception? Yes 0 No Q ✓ MILNE PT UNIT A S-35 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109/ADL0025639 - 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): 14,804 . 4,110 14,804 • 4,110 . 850 N/A 10,715(Fill) Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic i See Attached Schematic 4-1/2" 12.6/13CR-80/VAM Top&TC-II 10,655' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES TNT Pkr&ZXP Liner Top Pkr and N/A . 9,546(MD)/3,882(TVD)&10,657(MD)/4,077(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 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: Commencing Operations: 4/5/2017 OIL Q^ WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. 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 StP Email sporholaCcr�hilcorp.com Printed Name Bo York r (nS �J Title Operations Manager Signature PI"� 14 YJ l.4^rJ&Phone 907-777-8345 Date 3/24/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317 - /2z_f Plug Integrity ❑ BOP Test n Mechanical Integrity 9 Y Test 0 Location Clearance 0 t.,1s 7, 1t51, 'cl- Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /0 —go if RBDMS'UL Al-t' - 3 2017 D APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: 3 ,2'_/7 r'itu 3� 17- a,. I A 3f&17 -2q-17 Form 10-403 Revised 11/2015 ® RitGaipNtiA t lid for 12 months from the date of a roval. Submint Form ane pp Attachments in Duplicate • • Well Prognosis Well: MPS-35 I1ikøri Alaska.Lb Date: 3/23/17 Well Name: MPU S-35 API Number: 50-029-23175-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: April 6th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-143 First Call Engineer: Stan Porhola (907) 777-8412 (907) 331-8228 (C) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number:, Job 4'pe: L, 1 Coil Foam l anol,t Current Bottom Hole Pressure: 1,250 psi @ 4,000' TVD (Last BHP measured 2/20/2015) Maximum Expected BHP: 1,250 psi @ 4,000' TVD (No new perfs being added) MPSP: 850 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU S-35 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump. The completion was pulled and changed out in 2012 using Doyon #14 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome. A fill cleanout in late November 2015 was unable to cleanout fill due to not being able to lift fluids effectively to surface. A fill cleanout in May 2016 cleaned out to 13,077' MD. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.7° @ 3,540'). Deviation at pump is 72°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546' on 8/14/2012. • Polished tie-back sleeve with Doyon#14 in 2012. • Jet Pump pulled on 10/29/2016 using coil. New pump (8C) set by slickline on 11/04/2016. v, • ***Jet Pump may be pulled by slickline, not coil tubing unit*** + • ***Sliding sleeve may be shifted closed/open by slickline, not coil tubing unit*** Objective: The purpose of this work/sundry is to pull the existing Jet Pump, perform a foam cleanout of the lateral and run a new Jet Pump. Work Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. '01= c. Record BOPE test results on 10-424 form. 3. RIH w/2.00" coil and pull jet pump at+/-9,469' MD (if not pulled by slickline). 4. RIH w/2.00" coil and shift sliding sleeve closed at+/-9,469' MD (if not closed by slickline). 5. Test backside to 3,500 psi for 5 min to confirm closed (if shifted closed by coil). POOH. • • Well Prognosis Well: MP S-35 Mean)meta.Lb Date:3/23/17 6. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. b. Contingency: If unable to wash down with nozzle, RIH w/3.0" to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. 7. RIH w/2.00" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see_Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/- 14,804' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 8. RIH and shift sliding sleeve open at+/-9,469' MD (if not to be opened by slickline). 9. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open (if shifted open). POOH. 10. PU to 2,500' and freeze protect well. POOH w/coil. 11. RD Coiled Tubing and ancillary equipment. 12. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram . . Milnlle PointMPU UnitS-35 We : 1 SCHEMATIC Last Completed: 8/15/2012 Iiilcorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"—5M CIW Orig.DF Elev.=71.6g/Orig.GL Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-IIT&B Tubing Hanger.4"CIW"H"BPV Profile 20 °+ OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP @ 304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 10-3/4'4 0 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES`XD'Dura Sliding Sleeve—3.813"ID,Opens Down(7C Jet Pump)5/11/2016 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG—4,077'TVD k, GENERAL NOTE: ko GENERAL WELL INFO ,w PMINIMUM ID=3.813 @ API:50-029-23175-00-00 9,469',9,578'&9,647' + Drilled and Completed by Doyon 14 -9/27/2003 64 2 4w Recompleted by Doyon 14—8/15/2012 4,^1 lirIA 111 3 re 4 NOTE: i a M¢ 1.2'Blast Rings Below Tubing Hanger. R� 2.Casing Test to 3,500psi @ 9,546'8/17/2012 ti 11 I 4t4 9:" a* LAST TAG @ 13,077'5/10/2016 tA Possible Liner Damage 12,850 to 8 12,900. 7.5/8„� I®9&10 11 '40.00:4`. Double Valve Baker 4-1/2" +. Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Revised By:TDF 5/11/2016 • • Milne Point Unit COIL BOPE MPU 5-35 ita.fp t ..LL(. 3/23/2017 MPU S-35 20 x 10% x 7% x 4% Coil Tubing BOP To injection head 2.00"Double Stripper Lubricator ---_i //-–_` -Blind 41/16 15 � Blind _4 J - _\ // = Shear Shear = 1 ¢ -� 0% —— aO i —; f'' Slip IIIII SlipMlle 0111 MIMI _ _ ra _ _� Pipe Pipe MIR _ Crossover spool 4 1/16 15M X4 1/16 10M Ix xt Crossover spool 4 1/16 10M X 4 1/16 5M1: Pump-In Sub Zr JC— = *5o•�i 41/165M o "' -oti q '�_ 4 I�� 1502 Union F Manual Gate Manual Gate Valve,Swab,WKM-M, "r.c 2 1/8 5M 2 1/8 5M 4 1/16 5M FE -,.(4o `�\LV', ee,u. „ rrrr \CI'S � t� Ja\sle'Qtih6 4 Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic x ,• IE Valve, Lower Master,WKM-M 1,..,;'•=t1--- ;,,, ate, 4 1/16 5M FE ECI Tubing Adapter,4 1/16 5M moi/ IN • STANDARD WELL PROCEDURE IlikorpAlaska.LIR. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • t 1:00 • b > Y N o Z > u > z z a: � K z ce -o > ? H 0 LL 3 0 LL o `,_ f Z ec e 2 t22 0 -- i J a -a .c 0 ci_0- 0 O w Ca E a > -8 - O _ 0 > .�. '�- c co m co m y r5i 2 'IF 16— �.. m C7O v v �. O O o a a '^ z a w > C7 W U a` - - ri a •2 H 3 H _ co z s 4 Q m O r; • v 0 s i u • ... . C LL f7 0l ss — a 0 ��:,�; ill in.1[1111 - • i. ;a.4 llama I g 1 ,.} �..�g I!1 Itllllr n Ni Z w F CC C. U O O O m W m 1-- L K a V 111" 101 Z ed CC LU w 4-4 Q 0 Y z vw O F 1- 2 2 m O m K O a om Inm m 0 0 a 212 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION CON SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon [J Plug Perforations ❑ Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Remove&Replace Jet Pump Q Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT FCO ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 203-143 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23175-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380109/ADL0025639 MILNE PT UNIT SB S-35RECEI ED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL JUL 2 5 2016 11.Present Well Condition Summary: AOGCC Total Depth measured 14,804 feet Plugs measured N/A feet true vertical 4,110 feet Junk measured 10,715 feet Effective Depth measured 14,804 feet Packer measured 9,546 feet true vertical 4,110 feet true vertical 3,882 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/*4" 5,816' 2,904' 3,580psi 2,090psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890psi 4,790psi Liner 4,154' 4" 14,804' 4,111' 7,910psi 6,590psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 12.6#/13CR-80/ Tubing(size,grade,measured and true vertical depth) 4-1/2" Vam Top&TC-II 10,655' 4,077' 9,546'MD N/A Packers and SSSV(type,measured and true vertical depth) HES TNT N/A 3,882'ND N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNED FEB 6 6 2017, 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: 139 30 65 3,256 230 Subsequent to operation: 59 12 806 3,231 230 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations LI Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ 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: 316-247 4 Contact Ted Kramer Email tkramer(cr�hilcorp.com Printed Name Ted Kramer�� Title Operations Engineer l- Signature -4 --� -` Phone 777-8420 Date 7/22/2016 Form 10-404 Revised 5/2015 Afet t(��BDMS Uv It" 2 0 2016 Submit Original Only II 0 • Milne Point Unit Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 Hikorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"—5M CIW Orig.DF Elev.=71.68'/Orig.GL Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.4"CIW"H"BPV Profile 20' L OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole a CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP@304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 10-3/4'1 II 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down(7C Jet Pump)5/11/2016 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG—4,077'TVD NOTE: GENERAL WELL INFO MINIMUM ID=3.813 @ API:50-029-23175-00-00 9,469',9,578'&9,647' Drilled and Completed by Doyon 14 -9/27/2003 2 Recompleted by Doyon 14—8/15/2012 4 NOTE: 1.2'Blast Rings Below Tubing Hanger. 2.Casing Test to 3,500psi @ 9,546'8/17/2012 5 6 Ni d--1 7 '4 s* LAST TAG @ 13,077'5/10/2016 Possible Liner Damage 12,850 to ., 8 12,900. 7-5/8" 810 11 5551 Vt Double Valve Baker 4-1/2" :4£ Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Revised By:TDF 5/11/2016 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 5/6/16 5/11/16 Daily Operations: 4a, 5/4/2016-Wednesday No activity to report. 5/5/2016-Thursday No activity to report. 5/6/2016- Friday Fire equipment. Move coil unit to S pad. Hold safety meeting review slb JSA. Rig up SLB CTU 14 with 2.0" CT. Start BOPE test.Test all rams and valves to 250psi low/4,500psi high. BOP test complete. Make up BHA. CC, DFCV, Hyd, G force Jars, Disconnect, 4" GS spear. 2.6" OD. Pressure test MHA. 250psi low/4,500psi high. Stack injector head on deck. Install night cap on BOPE. Well site secure. Crews off location. 5/7/2016-Saturday Fire equipment. Hold safety meeting. Discuss job procedures and associated risks. Review and discuss SLB JSA. Stab on well.Tools string: 2.88 CC, DFCV,Jars, Disco,4" GS spear. 11.8' length. Pressure test stack to 250psi low/4,500psi high. RIH 15.5' stack weight. GS spear hanging up in tubing hanger. Work pipe. Pass tubing hanger. RIH perform weight check above jet pump at 9,400' 18K up. RIH to latch fishing profile.Tag top of fish at 9,442' coil depth. Pick up to 22k 4k overpull. RIH to tag fish.Tagged same spot 9,442'. Pick up again 24k 6k over pull weight bouncing may be latched. POOH to surface. Pop off no fish. Check GS spear and clean. Still functioning correctly. Small bits of sand in GS. Install 4' extra weight bar. Stab on well. Pressure test stack 250psi low/4,500psi high. RIH at 80 ft/min pumping safe lube down backside at .5 bbls/min. Perform weight check at 9,400' 18k . RIH to latch fishing profile at 50 ft/min. While pumping seawater down coil at 2bbls min to clean fishing neck.Stack 10k down @ 9,438' Circulated 15 bbls of seawater. Shut down fluid pump. Pick up 6k over pull. Feels latched. Run back in stack 15k down. Pick up 6k overpull again. POOH to check for fish. No fish. No fish.Take off statewide GS. re-inspect and measure. Looks like dogs are not relaxing to Full OD of profile. Could be due to debris inside GS or weak spring. Instal slick line GS pinned with 1/4" steel rod. Stab on well. Pressure test 250psi low/4,500psi high. RIH at 80 ft/min pumping safe lube down CTxtubing annuli at .5 bbls/min. WHP increase indicating Jet pump still in profile. Bleed of as needed. Stacking weight at 9,423' 15' higher than previous. Onlnie down ct with sewater at 2 bbls a minute to attempt to wash. NO luck making hole. Multiple attempts at picking up and RIH 100 ft/min. Attempt to pressure up tubing to 1,500psi and RIH. No luck. Hold safety meeting with Pad operator. Discuss bringing on power fluid while trying to latch fish. Power fluid pressure increasing to 750psi. RIH made it past 9,423' Stack 15K at 9,443'. Pick up not latched.Attempt to pressure up tubing and latch to see a pressure drop. No luck.4 attempts to latch jet pump. 5th attempt Pull heavy to 30k. FISH LATCHED. Normal CT weight 18k Start with over pulls to 40k. NO luck. IA pressure 750psi. Attempt jar licks at 35k. 10 jar licks Pump not moving. Max overpull on Pump to 50k. NO luck. Slack off.Water cooling down in reel. Freeze protect coil with 50 bbls of 60/40 also allowing jars to cool down. Pick up 55k weight breaking back. Continue to POOH heavy from 30-40k weight jet pump free. Check IA valve. Wellbore on vac. POOH to surface. Fish recovered. SDFN. Wellsite secure. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 5/6/16 5/11/16 Daily Operations: 5/8/2016-Sunday Fire equipment. Hold safety meeting. Discuss job procedure. Review SLB JSA. Pick up injector head from back deck. Remove jet pump and G spear. Break down BHA.Trim 2" Ct 200' due to crome tubing abrasion. Make up BHA. 2.88" OD CC, DFCV, Jars, Hyd Disco, x over, B042 shifting tool pinned to shift closed or up. Stab on well. Pressure test stack to 250psi low/ 4,500psi high. Open well. RIH pumping safe lube down backise at .5 bbls/min. Stop CT. Small leak in reel swivel. Change out CT reel swivel. Pressure test new reel swivel to 250psi low/4,500 psi high. Continue to RIH, weight check at 9,300' 14.5K. RIH to 9,500'. Pick up at 20 ft/min. May have saw small indication of sleeve shifting at 9,443' 1500 lbs increase on weight cell. Continue up hole to 9,400'. Run back in to 9,500'. Pick up OOH at 10 ft/min to ensure sleeve is closed. No indication of weight bobble at previous depth of 9,443'. RIH and repeat the same one more time. POOH to surface.Tagged up. Close tree. Blow down stack pop off. Shear pin still intact. Sleeve must have shifted. Halliburton N2 on location. Spot in and rig up N2 pump truck. Install Jet swirl nozzle on tool string. 2.88" OD. SDFN. Ordered 100 bbls of FloVisc from MISWACO to arrive in the AM. 5/9/2016- Monday Hold safety meeting. Discuss JSA. Pick injector head.Stab on well. PT stack 250psi low/4,500psi high. Bleed down. Open well 23.5 turns RIH. Pumping safe lube at .5 bbls/min down back side. Coil counter quite working. cycle pipe up and down. Coil counter working again. Continue to RIH @ 3,200' start cooling down N2. Pressure test N2 iron 250/4500 psi. Open Halliburton N2 to CT reel. Online 600 scf/min. CT @ 4,000'. 7,000 gallons on location. Start POOH 950psi CT pressure starting to drop. Increase rate to 800 scf/min. PU to 3,148'. Fluid returns to surface. 200 psi on choke. Start RIH pumping 800 scf/min and .5 bbls/min. Incresase rate to .75 bbls/min. Perform wieght check 10,000' 10,800', 11,005', 11667', 11887', 12,258', all clean from 18-20k. Stacking weight at 12,401'. Pick up clean 23k. Wiper trip 100'. Rih stack weight 12,500'. Pumping 800 scf/min and 3/4 bbl/ min. Swap to gel. Not able to make hole past 12,500'. PU wiper trip 100'. Not able to make back down to 12,500'. Start POOH whp dropped rapily from 150psi to 0. Returns stopped. Normal up weight 20k. Pulling 35k @ 11,335'. Continue to work pipe up and down. No movement. 1,000 scf/min and 1.5 bbls/min. Circ pressure 3,600psi. Working pipe up and down. Not able to move in hole or out. Still able to circulate down CT but no returns. Pulled to 52k at 11,335'. Weight limiter tripped. CT stopped. Looked like jars hit. Reset trip. POOH look to be free. Increase speed to 80 ft/min. Still no returns. PU to top of 4" liner. Returns established. Continue to PU to sliding sleeve. WHP increasing to 265 psi. Circulate two equivalent bottoms up with nitrified fluid. Continue in hole. Performing weight checks every 500'. Swap back to water 20 bbls of gel pumped @ 12,000'.Taking 100' bites and wiper trip back to 12,000' each time. Cleaned out to 12,941'. Continue to stack weight and loose hole. Not sure if we are fighting sand dunes falling out of fluid behind coil, or if we are getting friction bite from dry chrome tubing and CT. 1,000 gallons of N2 left. Wait on gel to hit nozzle. Pump 2,500' behind pipe start POOH at 30 ft/min wiper trip to tubing tail. Clean OOH weights.WHP 275psi. Good returns. Shut down fluid @ 3,000'from surface. Continue to blow N2 until CT reaches 1,000'. Shut donw N2. Isolate P subs. Bleed CT down back side line to return tank.Tagged up. Close master and swab. 260 PSI SITP. Open choke bleed down stack. Pop off well. SDFN. Wellsite secure. 6,700 gallons of N2 pumped for cleanout. 406 bbls of fluid pumped. 465 estimated bbls of fluid returned to surface. 5/10/2016-Tuesday • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 5/6/16 5/11/16 Daily Operations: Fire equipment. Hold safety meeting. Pick injector head. Make up XRV extended reach tool on exisiting MHA. 2.88 CC, DFCV,Jars, Disco, XRV, nozzle. 15.6' in length. Stab on well. Pressure test stack to 250psi low/4,500psi low. Bleed down. Open well and RIH. WHP 418psi. (N2 pressure left on well from previous day) @ 2,500' start cooling down N2. 3,500'. Online with N2 @ 800 scf/min. N2 returns at surface. Increase fluid rate to .5 bbls/min of safe lube. Increase N2 rate to 1,000 scf/min. Increase fluid rate to .75 bbls/min. Good returns. 250psi WHP. Start stacking weight at 12,824'. Pick up and attempt to work through. Swapped to gel. Pumping at 1,000 scf/min and 1 bbl/min. Not able to pass 12,850'. Stack 15k down. Wiper trip back to tubing tail. Made it past 12,850' but stacking weight for 50' then popped loose and gain 6k string weight. RIH weight-3,200. Stacking to-14,765. Popped back and ran in hole at-7,000 from 12,900-13,077'. Started stacking again at 13,077'. PU 110' wiper trip. Multiple attempts at 13,077'. No luck making it past. Deviation survey indicates going up hill and making a corner at current depth. Possible liner damage 12,850-12,900. Start Wiper trip OOH to clean up tubing. Calcualte bottoms up. Let 20 bbls equivalent turn corner of coil. Start chasing it OOH. Down on fluid and N2. Let well bleed down slowly to Pigging tank.Tagged up.Shut in wellhead. Bleed down pop off. Start rigging down SLB. 41, Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 CTU 50-029-23175-00-00 203-143 5/6/16 5/11/16 Daily Operations: 5/11/2016-Wednesday "**WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/3500H**. SET 3"" RC OM JET PUMP (serial# BP-1028, ratio: 7C) IN XD SLIDING SLEEVE AT 9469' MD. **RDMO** 5/12/2016-Thursday No activity to report. 5/13/2016- Friday No activity to report. 5/14/2016-Saturday No activity to report. 5/15/2016-Sunday No activity to report. 5/16/2016- Monday No activity to report. 5/17/2016-Tuesday No activity to report. OF Tom • • A THE STATE Alaska Oil and Gas ' 4? ;;,.�� of//A� A 'C)KA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^ti Main: 907.279.1433 F ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCAltt 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU SB S-35 Permit to Drill Number: 203-143 Sundry Number: 316-247 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, Cathy P Foerster Chair DATED this Gel day of April, 2016. RBDMS L 9 2016 • • RECEIVED STATE OF ALASKA APR 2 6 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION OTS f(2..r)/1, APPLICATION FOR SUNDRY APPROVALS A C. ( 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Remove and Replace Jet Pump 0- Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: A,, Hilcorp Alaska, LLC Exploratory ❑ Development E. 203-143 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23175-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No .❑ /' MILNE PT UNIT SB S-35 ' 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109/ADL0025639 . 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): 14,804 4,110 ' 14,804 4,110 850 N/A 10,715(Fill) Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580 psi 2,090 psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890 psi 4,790 psi Liner 4,154' 4" 14,804' 4,111' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR-80/VAM Top&TC-II 10,655' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HES TNT Pkr&Liner Top Pkr and N/A . 9,546(MD)/3,882(TVD)&10,657(MDy 4,077(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑., Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/10/2016 Commencing Operations: OIL Q - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved pma , k, herein will not be deviated from without prior written approval. Contact Ted Kramer S SLAW 065 Email tkramer@hilcorp.com Printed Name ir Bo York Title Operations Manager Signature ( L% Phone 907-777-8345 Date 4/26/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ® Mechanical Integrity Test El Location Clearance ❑ S-4)4) Other: k q "s.. /nt ' s' 4- ( C 71 Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS /.),-, APR L 9 2016 Spacing Exception Required? Yes ❑ No �' Subsequent Form Required: / ' s"rr `( afe67p APPROVED BY �� Approved by: COMMISSIONER THE COMMISSION Date: ¢L�- ,,,,, �7�� f �/D))!' of f OkRteiittnAtd Submit Form and Form 10-403 Re ed 11/2015 for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MP S-35 Hilcorp Alaska,Lb Date:4/25/16 Well Name: MPU S-35 API Number: 50-029-23175-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point S-Pad Estimated Start Date: 5/10/16 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-143 First Call Engineer: Ted Kramer _(907) 777-8420 (0) (907)867-0665 (C) Second Call Engineer: Stan Porhola (907) 777-8412 (907) 331-8228 (C) AFE Number: Current Bottom Hole Pressure: 1,250 psi @ 4,000' TVD (Last BHP measured 2/20/201,5) Maximum Expected BHP: 1,250 psi @ 4,000' TVD (No new perfs being added) �/ Max. Predicted Surf Pressure: 850 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU S-35 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump.The completion was pulled and changed out in 2012 using Doyon #14 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome. A fill cleanout in late November 2015 was unable to cleanout fill due to not being able to lift fluids effectively to surface. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.7° @ 3,540'). Deviation at pump is 72°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546' on 8/14/2012. ✓ • Polished tie-back sleeve with Doyon#14 in 2012. • Jet Pump pulled in late November 2015. New pump to be set by slickline. Objective: The purpose of this work is to pull the existing Jet Pump, cleanout the lateral and run a new Jet Pump. Coiled Tubing Procedure: 1. MIRU CTU. Notify AOGCC 24 hours`+i o testing BOP. 2. Pressure Test BOPE to 250psi low/ psi high. Fill out state BOPE test form and submit within 5 days. „IA.0; 3. Pick up lubricator. 2, Ifo 4. Stab on well. Pressure test stack 250/ si. . 5. Open tree and count turns on valves. Record in ops cab. Start RIH, perform weight checks as needed. Coil tubing speed not to exceed 80 ft/min due to SLB standards of running in chrome tubing. 6. Contingency: If jet pump set previously on slickline. a. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/-9,469' MD. POOH. 7. RIH w/2.00" coil w/shifting tool and shift sliding sleeve closed at+/-9,469' MD. POOH. • • • ll Well Prognosis Well: MPS-35 Ihicorp Aia,ka,LL Date:4/25/16 8. Make up coil connector pull test 25k. Make up Cleanout BHA with nozzle or MHA and extended reach vibratory tool. RIH W/Coil at running speeds not to exceed 80 ft/min due to SLB standards of running in chrome tubing. Note: Min ID is 3.725" through XN Nipple. 9. Attempt to dry tag fill. Estimated top of fill is 10,715' 10. Start cleaning out fill from 10,715'to PBTD. Come online with 2%safe lube if needed. This should aid with metal to metal friction. N 11. Come online with N2 at 800-1500 scf/min and fluid rate of 1.5 bbls/mi.n . Cleanout to PBTD at+/- , ;j 14,757' MD. Adjust N2 and fluid rate accordingly. Watch returns. Ensure return tanks is strapped to ensure 1:1 . Adjust rates accordingly. 12. Contingency: If no returns are seen at surface even with nitrified fluid, rig up to put nitrogen down the 4-1/2" by 7-5/8" annulus via choke to aid in lifting the well. Note: a button orifice may need to be inserted below the sliding sleeve to get nitrogen assist. 13. Once PBTD or max coil depth is reached continue to circulate bottoms up. 14. Start POOH . Come offline with N2 and fluid. Bleed N2 down . 15. RIH W/2.00" coil shifting tool and shift open sliding sleeve at+/-9,469' MD. POOH. 16. RIH W/2.00" coil W/ RXN running tool and jars to set Jet Pump at+/-9,469'MD. a. Confirm adequate shear pins set in X-lock to set with adequate force applied. 17. PU above jet pump and start circulation of power fluid to confirm jet pump set. a. Contingency: If pump not set, re-pin and attempt to set again in sliding sleeve profile. 18. POOH w/coil. LD RXN running tool and jars. 19. RDMO Coil Unit. 20. Turn we'll over to production. Attachments: 1. Nitrogen Procedure 2. Nitrogen Flow Diagram 3. Nitrogen Flow Diagram (Contingency Nitrogen down Backside) 4. Well Schematic 5. Proposed Well Schematic 6. Coil BOPE Schematic • • STANDARD WELL PROCEDURE Hikorp Alaska,LL( NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Press ru a test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 0 x I_ W x 2 0 a at m _., . a < EH °L4 a on -,n 0 02 .•:: .• • ''' Fi '''. 3 .7 0 0 :i *: ,.. 0 ,- cp -E-2 ‘0' ° > ''' 100' •-',2 = P. .7 :.„:.... I='4' rj •-c0 F .) ..., . .C1 a -6. t : " *:..... .., „, > . z . . F 10 CL w C0 I— L0 r•:. ... •2 : *.. .2 :.. • 7› -7 I : 4---. (...) C...) 3 4 3 3 4 4 o 4 0 I g...0 r , - _ vl LA —4111111.11—.— • 111XZ Z 0 k. _ . ON 4,-s, p .. ....: z — w , 0 : •i- • • : r.....: : • tz •.... w .., . > t ..6 ,, a : . z 1... w 0 -o cg ! ... 02 fi. : : : / r: r.••• i•-** L4: L7. > L7 a7 i u 4: NM 0, 111::) . , 0 Vii I! 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Milne Point Unit • Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 • Hilcorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"-5M CIW Orig.DF Elev.=71.68'/Orig.GL Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.4"CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL 20' 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 �= = 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP @ 304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL 10-3/4"4 No Depth Item 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down(7C Jet Pump) 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA • 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID ,(. 6 9,578' 4.5"HESX-Nipple-3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG-4,077'TVD NOTE: GENERAL WELL INFO S` 1' "' MINIMUM ID=3.813 @ API:50-029-23175-00-00 9,469',9,578'&9,647' Drilled and Completed by Doyon 14 -9/27/2003 2 s, Recompleted by Doyon 14—8/15/2012 • 3 JET PUMP (7C) 11/23/2015 NOTE: 4 aq 1.2'Blast Rings Below Tubing Hanger. 2.Casing Test to 3,S00psi @ 9,546'8/17/2012 k9 � Y � 6 7 8 7-5/8' �� 9&10 LAST TAG @ 10,715' 11/18/2015 J Double Valve Baker 4-1/2" . . + .x17111:1�1.1.1.1.1.1.1.Y jtµ*. " '�'�'�'�'�'�'�'�'�'�'�'- - Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Created By:TDF 4/26/2016 H . Milne Point Unit IIII Well: MPU S-35 PROPOSED Last Completed: 8/15/2012 Hilcora Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"—5M CIW Orig.DF Elev.=71.68'/Orig.GL Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.4"CIW"H"BPV Profile kil OPEN HOLE/CEMENT DETAIL 20' 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole j CASING DETAIL 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 5,816' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 10,751' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP @ 304'MD _ Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. I 71 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 103/4'4 11 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES`XD'Dura Sliding Sleeve—3.813"ID,Opens Down(7C Jet Pump) 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer-3.856"ID 6 9,578' 4.5"HESX-Nipple-3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG-4,077'TVD t , NOTE: GENERAL WELL INFO MINIMUM ID=3.813 @ } API:50-029-23175-00-00 '14: 1x 9,469',9,578'&9,647' Drilled and Completed by Doyon 14 -9/27/2003 P, 2 Recompleted by Doyon 14—8/15/2012 0 • 3 11 INSTALL NEW JET PUMP NOTE: i 4 1.2'Blast Rings Below Tubing Hanger. 4 it 1 2.Casing Test to 3,500psi @ 9,546'8/17/2012 tli 111;"91 6 t vJ 7 i 7-5/8" 11 98,10 111 . PROPOSED CLEANOUT TO PBTD \\ Double Valve Baker 4-1/2" quo Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Created By:TDF 4/26/2016 S ID Milne Point Unit COIL BOPE MPU S-35 11/23/2015 Harm?,4Ia.ka,TLC MPU S-35 20X10% X 7% X 4% Coil Tubing BOP # Lubricator to injection head I(61 ATI) 2.00"Single Stripper aillielli Jii 1111 Blind/Shear =41/1610 !:BIh /s - hear ,I,' •_ __ -; 1,11 an= 6 ja•'.I,I Blind/Shear _ 5-Blind/Shear I® C istmil _ — Slip Slip U ii C Li Mk Iiiii )11111 Pipe1E111 5 Pipe uIu'.: NMI— IFN ' t ESA Crossover spool 4 1/16 10M X4 1/16 5M ler .st Pump-In Sub e 4 1/16 5M alli ars, lfr i ® I���� 1502 Union Manual Gate Manual Gate Valve,Swab,WKM M, -.(;, (1- 4 •' 2 1/8 5M 2 1/8 5M mac 4 1/16 5M FE ----' -, * 34\(°' i , p. ,2„\-,e,„\ -cos Valve,Upper Master,Baker, ''' 4 1/16 5M FE,w/Hydraulic 0 IJVI,• Valve,Lower Master,WKM-M '! 4 1/16 5M FE Ing,4,7,1.7 711E111 Tubing Adapter,41/16 5M e STATE OF ALASKA A SKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon-LI Plug Perforations Li Fracture Stimulate Li Pull Tubing U Operations shutdown u Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Remove&Replace Jet Pump ❑✓ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CT FCO 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development❑✓ Exploratory ❑ 203-143 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-23175-00-00 7.Property Designation(Lease Number): '8.Well Name and Number: -. ADL0380109/ADL0025639 MILNE PT UNIT SB S-35 ii V 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL �V Ui . ""S i 11.Present Well Condition Summary: AOGCC Total Depth measured 14,804 feet Plugs measured N/A feet true vertical 4,110 feet Junk measured 10,715 feet Effective Depth measured 14,804 feet Packer measured 9,546 feet true vertical 4,110 feet true vertical 3,882 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/*4" 5,816' 2,904' 3,580psi 2,090psi Production 10,751' 7-5/8" 10,751' 4,089' 6,890psi 4,790psi Liner 4,154' 4" 14,804' 4,11�1g' 7,910psi 6,590psi iCANPerforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 12.6#/13CR-80/ Tubing(size,grade,measured and true vertical depth) 4-1/2" Vam Top&TC-II 10,655' 4,077' 9,546'MD N/A Packers and SSSV(type,measured and true vertical depth) HES TNT N/A 3,882'ND 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: 50 78 296 3,232 231 Subsequent to operation: 0 0 0 0 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 El Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas LI WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ 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: 315-514 Contact Stan Porhola Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature '7,PPhone 777-8345 Date 11/30/2015 RBDMS Ca 0 31015 Form 10-404 Revised 5/2015 `z'e Submit Original Only , • . al H i corp Alaska, LLC Weekly Operations Summary ()Cw Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 11/174/2015 11/20/15 Daily Operations: / 11/18/2015-Wednesday 1 t1 j Fire equipment. -20 ambient temperature. Hold safety meeting. Review JSA. Discuss cold weather procedures. Pick injector head.Stab on well. Pressure test stack to 250psi low/4,500psi high Bleed down. Open master swab 18.5 turns.SSV locked in open. RIH. WHP-35psi. RIH. Opened to inside upright with 1%safe lube.Well pulling fluid in at 1 bbl/min without C pump or fluid pump. BHA.CC, DFCV,Jars, Hyd Disc,x over, HES B042 Shifting tool. RIH @ 80 ft/min. 5k RIH Weight. Production shut down annulus fluids. Hooking up to pump IA for flush and PT. Continue RIH at 80 ft/min. RIH wt at 7,700' 6k. Perform weight check at 9,350', 6,200 lbs RIH wt. Pick up weight 18k wt check. Rigging up to perform flush. Safety meeting with pump truck. Pressure test IA pump line to 250psi low/4,500psi high. Online with pumpers down IA with seawater 1 bbl/min. Increase to 4 bbls/min. 10 psi 40 bbls away at 4 bbls/min no increase in surface pressure. 80 bbls away.4 bbls/min, 100 bbls away at 4 bbls/min. No pressure increase 0 psi whp.and 0 psi IA pressure. Pumping sea water down CT string moving pipe across sleeve. 150 bbls away. Flush complete. Swapping to diesel to freeze protect.Start pumping diesel down IA 1.5 bbls/min, 30 bbls diesel away.At 9,500'. Start Picking up. Normal upwieght 18k. Pick up to 20k @ 9,467'. 9,465' weight came to 25k then broke off to 12k. 7k over pull.Sleeve shifted closed. RIH to 9,500'. Pick up through sleeve clean 17k up weight. Small weight bobble at 9,465'. POOH to surface. POOH to surface. IA caught fluid after 45 bbls pumped.Start pressuring up to 3,500 psi.Total volume diesel pumped in annulus 61.3 bbls. 3,583 psi start 30 .._ minute test 13:32 hrs. 14.02 end pressure 3,454 psi Loss of 129 psi. Bleed down IA pressure. Rig down LRS. B Blee_ed back 5 ,.(..etk bbls. 56 bbls diesel in wellbore.Tagged up at surface. Breaking down HES B042 shifting tool. Install XRV extended reach vibratory tool and nozzle. BHA as follows. 2.88" CC, 2.88" DFCV, Logan Hyd Bi-Di CT Jar 2.88",TJ Hyd. Disconnect 2.88",XRV 2.88",Jet swirl wash nozzle 2.88". BHA length 13.44'. Pressure test 250psi low/3,500psi high with 60/40 methanol. RIH at �+ ` 80 ft/min. 9,400'wt check 18k. Wt check at 10,254', 24k. Pumping 1 bbl/min before exiting tubing tail. Pick up weight 11,000' 26.6k-35k. Compared to TFM we are pulling 11k heavy. Looks like we are in fill. Gradual weight increase as picking up. No break over in weight. 36K up weight, 37K up weight, 38k up weight. Weight breaks back 10,541'to normal up weight 25k. RIH at 10,545'. RIH to 10,715'. Perform weight check. Picking heavy again 33k. POOH to surface. Online down CT annulus at 4.5 bbsl/min. Down on pump 156 bbls of safe lube pumped. Swap to 60/40 methanol to freeze protect back side lines and CT while POOH. Swapped to methanol 143 on counter. Coil freeze protected at 187 bbls. At surface.Close master swab 18.5 turns. Blow down to OT. Pop off well. Break down tools. Cut off coil connector. Loction secure. Crews off location. e • ti.. Hi corp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number _ Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 11/174/2015 11/20/15 Daily Operations: 11/19/2015-Thursday Negative 30 ambient. Hold safety meeting. Discuss job procedures. Review SLB JSA. Fire equipment. Pick injector head. Remove night cap on BOPE. Make up coil Connector. Pull test to 25K. BHA 3.12" CC, 3.12" DFCV, 3.12"Ti Hydraulic Disco, 3.03" X over, 2.87" SiDi Hip Tripper, 2.87" Ported x over, (pressure tested MHA to 250psi low/3,500psi high). Make up HES 8042 shifting tool to shift in the down position (open sleeve). Wrong Hip Tripper on location. Waiting for BiDi. Correct hip tripper on location.Vendor brought out SiDi and we needed BiDi hip tripper to shear up on pump. Making up Hip tripper and x over to sucker rod. Install ll HES B042 shifting tool with shoulder facing down. Stab on well. Pressure test 250psi __... __._.._.. low/4,500psi high. Master swab b open 23.5 turns. 0 psi WHP.Well on Vac. Isolate 60/40. Line up off outside upright down to aid CT deployment. Outside upright 220 bbls at 25 on MM.57 bbls of safe lube pumped o liA the back side with safe lube down coil annulus. 5,890' RIH. Pick up weight at 9,350' 21.7K. Clean. RIH wt. 6.5K. Headed into shift sleeve.Tag sleeve at 55 9,474' stack 4k down weight broke back to RIH wt of 7,620 lbs @ 9,476.5'. IA gauge went from 0 psi to-55 psi. Looks good. Pull up. 19K up weight clean. 9,450' headed back through Dura sleeve. Physically confirmed IA on vac. Clean pass through. / POOH to surface.Tagged up at surface. Master swab closed 18.5 turns. Blow down well. Pop off. Break down Shifting tool. Install Pump and X-line tool.Stab on well. PT lubricator with 60/40 meth down back side line. 250psi low/3,500psi high. Total BHA length 22.61'. Master swab confirmed open 18.5 turns. RIH @ 80 ft/min. 0 psi WHP. Well on vac. Online with safe lube 2%down backside while RIH. .8 bbls/min. RIH with RHC jet pump Serial# BP-1071 Setup 7C.X lock serial number 2443046.At 197 swap to 60/40 down back side line to freeze protect. 35 bbls of safe lube pumped down back side. RIH wt at 3,700' 5,100 lbs. Continue RIH. Stop at 9,350. Line up with safe lube down CT @ 254 on totalizer. Fluid pack coil. Online safe lube 1.8 bbls/min. Shut pump down @ 268 bbls. Weight check. 20.5k up weight. 6,187 RIH Wt. Stack 5k down at 9,471'- 9,472'. Come online down CT with safe lube .7 bbls/min @ 268.4,800 lbs down on pump. Increase coil pressure to 3,200psi pick up to RIH weight of 6k. Online with pump .75 bpm. Hip tripper still stalled 3,200psi. Pick up to 15k weight at 9,468'. Circ pressure dropped off to 800psi. Hip tripper off stall. Online with pump. .7 bbls/min RIH 677psi circ pressure. RIH past 9,472'. Looks like Dogs on x lock retracted. 9,490' still not stacking weight. PU through profile. Pick up clean to 9,450'. RIH to try and tag pump. Not stacking on profile. Looks like pump went down hole or dogs retracted. Make another up pass from 9,500'to 9,350'. No heavy pulls. POOH. Online with meth down coil.44 bbls meth pumped. Reel freeze protected. Tagged up at surface. Master swab closed. Blow down. Pop off well. We are still attached to pump. Install night cap. Break down pump for inspection in the morning. 347 bbls pumped for day. Wellsite secure. 1, • 0 El Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-35 Coil 50-029-23175-00-00 203-143 11/174/2015 11/20/15 Daily Operations: 11/20/2015-Friday Hold safety meeting. Discuss JSA and job procedure. Pick injetor head. Install shifting tool and pump. Stab on well. Pressure test to 250 psi low/3,500 psi high. Make up sucke rod x RxN line running tool on BiDi Hip tripper. Bleed down. Open master swab 18.5 turns. RIH at 80 ft/min while trickling in safe lube down back side. 20 bbls of Safe lube pumped. Freeze protect back side line. 2 bbls freeze protect. Isolate 60/40. RIH wt 6k @ 8,680'. 9,350' wt check 22k. RIH to fluid pack coil. Parked at 9,350'. Online with safe lube down CT.Online 1 bbl/min at 22 on totalizer. Pick up weight at 9,350'. 22.5k. RIH stack down slow. RIH wt 6,600 lbs stack 2k at 9,477.22'. Pressure increasing. 1,200psi at .5 bbls/min increasing to 2,200psi. Hip tripper stalled. Stacking weight. Slacking off in 200 lbs incriments. Stack to-3k. 9k down to attempt to shear top pins slacked off to 9,480'. Pick up slow . Pick up at 9,479' @ 5600 lbs. Increase rate to .7 bbls/min 3,200psi. Hiptripper stalled. Pick up to 4.8k. Attempt to pump. .7 bbls/min stalled. 3,300psi. Plck up to 6,500 lbs. Pressure dropped. Online 3,300 psi. Still stalled. Pick up to 7,700 lbs.Attempt to pump. .7 bbls/min. Stall. 3,400 psi. Pick up. 8,000 lbs. Pressure not dropping. 9,500 lbs. no break over. 10k no break over. 12.5k pick up to 9,477.5' 12.2k, bump pump. RIH stack 14k down. 18k picked up @ 35 swap to methanol. Pressure not bleeding off. 15k at .8 bbls min. Set down some weight. 9,476.2'. Light tripper action. Weight break back. Swap meth tanks.Slacking off 9,476', 16k weight. Online with pump .75 bbls min 17k weight. 9,475.5'. Online .75 bbls/min. 9,477.2' stall him tripper. Stack 16k. Pick up to 17k. RIH at 80 ft/min and stack to-13, 20k stacked on pins. Attempt this 8 times without pumping. Doesn't look like Hip tripper is working.Attemping using weight vs hip trippr. Hip tripper is stalling. Not feeling action at surface. Discussed with vendor.Tool hand believes it's working. Pick up to check bottom pin. stack to 12k down. Pick up for overpull. 25k and break over.4k consistent overpull. RIH to tag pump.Tagged at 9,479.8'.Tool hand believes its set. POOH. @ 79 swap back down CT. RIH stack pump 9,476.7'while pumping .6 bbls min. Pick up while pumping clean up weight.Tagged up at surface. Blowing down. Popping off. Pump still at surface. Rigging down CTU #4 Moving to S-34. Broke down setting tool.4 Steel pins have wear marks. Bottom pin completely intact. 11/21/2015-Saturday No activity to report. 11/22/2015-Sunday No activity to report. 11/23/2015-Monday No activity to report. 11/24/2015-Tuesday No activity to report. Milne Point Unit , 13 Well: MPU S-35 SCHEMATIC Last Completed: 8/15/2012 Hilcorp Alaska,LLC PTD: 203-143 WELLHEAD Tree 4-1/16"—5M CIW Orig.DF Elev.=71.68'/Orig.GL Elev.=37.9'Doyon 14 Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-II T&B Tubing Hanger.4"CIW"H"BPV Profile OPEN HOLE/CEMENT DETAIL 20! 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 92/H-40 N/A Surface _ 110' N/A 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 8,302' 0.0962 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 11,009' 0.0459 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' 0.0122 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' 0.0152 WELL INCLINATION DETAIL KOP @ 304'MD Hole Angle Passes 70 Deg.@ 2,600' Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve JEWELRY DETAIL No Depth Item 143/44 11 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down(No Jet Pump 11/17/15) 4 9,479' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG—4,077'TVD NOTE GENERAL WELL INFO MINIMUM ID=3.813 @ API:50-029-23175-00-00 9,469',9,578'&9,647' Drilled and Completed by Doyon 14 -9/27/2003 2 i Recompleted by Doyon 14—8/15/2012 w; 7. 3 ', JET PUMP PULLED 11/17/2015 NOTE: r an 4 ,S 1.2'Blast Rings Below Tubing Hanger. 2.Casing Test to 3,SOOpsi @ 9,546'8/17/2012 ''5 7-5/8"''= 9&10 LAST TAG @ 10,715' 11/18/2015 Double Valve Baker 4-1/2" Float Shoe @ 14,804 TD=14,804'(MD)/TD=4,110'(TVD) Created By:TDF 11/;!3/2015 i,1-8"\\°;;;,4,4',s, THE STATE Alaska Oil and Gas ��►;-i� �, o Conservation Commission (If Conservation x_ 333 West Seventh Avenue of GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Mr;,, Main 907.279 1433 ALAS". Fax 907.276 7542 Oa* � www aogcc.alaska goy Stan Porhola a D� , Operations Engineer 143 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-35 Sundry Number: 315-514 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, CW--44.) Cathy P. Foerster Chair 5I- DATED this 3i day of August, 2015 Encl. RBDMS SEP 0 2 2015 REC DMED STATE OF ALASKA AUG 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 8 11,11 1 S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request' Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other. CT Fill Clean-out Q 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC - Exploratory ❑ Development Q 203-143 ' 3.Address. Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23175-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05/ Will planned perforations require a spacing exception? Yes ❑ No Q✓ MILNE PT UNIT SB S-35 ' 9.Property Designation(Lease Number): 10.Field/Pool(s)• ADL0380109/ADL0025639 . 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): 14,804 . 4,110 - 14,804 - 4,110 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' N/A N/A Surface 5,816' 10-3/4" 5,816' 2,904' 3,580psi 2,090psi Intermediate 10,751' 7-5/8" 10,751' 4,089' 6,890psi 4,790psi Liner 4,154' 4" 14,804' 4,111' 7,910psi 6,590psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft)• See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR-80/VAM Top&TC-II 10,655 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): HES TNT Pckr and N/A 9,546(MD)/3,882(TVD)and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/8/2015 Commencing Operations. OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG El GSTOR ❑ SPLUG ❑ 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 Stan Porhola Tyd- itle Operations Engineer Signature Phone 777-8412 Date 8/21/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 16 — 5lii Plug Integrity El BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: T.sfi 44 -6S(5o rs . Spacing Exception Required? Yes ❑ No Subsequent Form Required: IIA() t; APPROVED BY Approved by. 7'9:t4...4„,sTLale4.7COMMISSIONER THE COMMISSION Date: i_3/... /S---- ?1i3 Z 12aSIIS c .� s3 .,�7 f l// � I S Submit Form and Form 10-403 Revised 5/2015 oA 'OleGplli0 '1 lid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MPU S-35 Hilcorp Alaska,LL Date:8/05/2015 Well Name: MPU S-35 API Number: 50-029-23175-00 Current Status: Oil Well [Jet Pump] Pad: S-Pad Estimated Start Date: September 8th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-143 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: 1,250 psi @ 4,000' TVD (Last BHP measured 2/20/2015) Maximum Expected BHP: 1,250 psi @ 4,000' ND (No new perfs being added) / Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 2/20/2015 and water cut 0 of 50% (0.385psi/ft)with an added safety factor of 1,000' ND of oil cap) Brief Well Summary: MPU S-35 was drilled in 2003 using Doyon 14 and completed as a single-lateral in the Schrader Bluff N sand with a Jet Pump. The completion was pulled and changed out in 2012 using Doyon#14 to replace the 4.5" L-80 tubing with 4.5" 13 Chrome. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.7° @ 3,540'). Deviation at pump is 72°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546' on 8/14/2012. • Polished tie-back sleeve with Doyon#14 in 2012. • Jet Pump currently active, performance continues to degrade(likely solids). Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the lateral and run a new Jet Pump. / Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00" coil w/3.5"wash nozz a an cleanout to top of Jet Pump+/-9,469' MD. POOH. a. Min ID is 3.813"thru Sliding Sleeve. 3. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/-9,469' MD. POOH. 4. RIH w/2.00" coil w/3.5" wash nozzle to sliding sleeve at+/-9,469' MD. 5. Bullhead filtered 8.4 ppg produced water down annulus, lifting sand/solids up the 2.0"coil x 4.5" tubing annulus. POOH. 6. RIH w/2.00"coil w/shifting tool and shift sliding sleeve closed at+/-9,469' MD. POOH. — 7. RIH w/2.00"coil w/3.5"wash nozzle and cleanout to PBTD at+/- 14,757' MD. POOH. a. Min ID is 3.725"thru XN Nipple. 8. RIH w/2.00"coil w/shifting tool and shift sliding sleeve open at+/-9,469' MD. POOH. 9. RIH w/2.00"coil w/GS running tool and run Jet Pump+/-9,469' MD. 10. PU to+/-9,450' MD. Displace well over to 8.4 ppg produced water. Well Prognosis Well: MPU S-35 Hilcora Alaska,LLQ Date:8/05/2015 a. Estimated volume (w/o coil in hole) is 144 bbl. 11. POOH w/coil. LD GS running tool. 12. RD Coiled Tubing. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic .. .. .. ._...__.. .__ Milne Point Unit 14 Well: MPU 5-35 SCHEMATIC Last Completed: 8/15/2012 flilcorp Alaska,LLC PTD: 203-143 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev.=71.68'/Orig.GL Elev.=37.9'Doyon 14 20" Conductor 92/H-40 N/A Surface 110' 10-3/4" Surface 45.5/L-80/Btc 9.950 Surface 8,302' 7-5/8" Intermediate 29.7/L-80/BTC-M 6.875 Surface 11,009' 20.41 4" Production Liner 9.5/L-80/IBT 3.548 10,650' 14,804' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr-80/VAM 3.958 Surface 10,655' JEWELRY DETAIL 01 1 No Depth Item 1 2,066' SLB 4.5"x 1"KGB-2 GLM 2 9,457' SLB Multi-drop Sapphire Gauge—3.958"ID, SGM-NDPG-CA 3 9,469' 4.5"HES'XD'Dura Sliding Sleeve—3.813"ID,Opens Down w/Rev.Circ Jet Pump 4 9,479' SLB Multi-drop Sapphire Gauge-3.958"ID, SGM-NDPG-CA 5 9,546' 7-5/8"x 4.5"HES TNT Packer—3.856"ID 6 9,578' 4.5"HES X-Nipple—3.813"Packing Bore 7 9,647' 4.5"HES XN-Nipple- 3.813"x 3.725"No Go 8 10,650' Baker Tie Back Sleeve 9 10,657' Baker ZXP Liner Top Packer 10 10,663' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 11 10,655' WLEG WELL INCLINATION DETAIL KOP@304'MD Hole Angle Passes 70 Deg.@ 2,600' 10-3/4q Max Hole Angle in Tubing=77 deg. 71 Deg.@ Sliding Sleeve OPEN HOLE/CEMENT DETAIL 20" 260sx of Arctic Set(Approx)in 42"Hole 10-3/4" 910sx Arctic Set Light,275sx Class'G'in a 13-1/2"Hole 7-5/8" 750sx Class"G"in 9-7/8"Hole WELLHEAD Tree 4-1/16"—5M CIW Wellhead 11"x 4.5"5M Gen.6 w/4.5"TC-Il T&B Tubing Hanger.4"CIW"H"BPV Profile GENERAL WELL INFO API:50-029-23175-00-00 Drilled and Completed by Doyon 14 -9/27/2003 Recompleted by Doyon 14—8/15/2012 2 NOTE: 0 6 1.2'Blast Rings Below Tubing Hanger. 4 2.Casing Test to 3,500psi @ 9,546'8/17/2012 6 7 . 8 LI 7-5/8" A Double Valve Baker 4-1/2" Float Shoe @ 14,804 1D=14,804'(MD)/TD=4,110'(TVD) Created By:TDF 8/20/2015 Milne Point Unit COIL BOPE MPU S-35 Uitfor,,Uia4 .IAA. 07/28/2015 MPU S-35 20 X10% X7%X4% Coil Tubing BOP Li Lubricator to injection head 6 O 1.75"Tandem Stripper I I 8-41/1610 _g. •I,I. Blind/Shear _—Blind/Shear .I,I•I_ 11 •I,I,IBlind/Shear- _—Blind/ShearIIIuI. i- 0 s8 Q c __ Slip LOU� Slip 11114'Al 0111111 Pipe — - PipeI Mud Cross mum. ®� 4 1/16 1OM X 41/16 1OM Outlet ./ i w/2-2 1/16 10M full opening FMC valves to illimoso alSt 151 E Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 1_:. ry 2 1/16 10M 2 1/16 10M Crossover spool 1. 4 1/16 10M X 4 1/16 5M Valve,Swab,WKM-M, ' �. ���SFE 4 1/16 5M FE V Ja\�e Q1Iti65 lliill IIII i '*.' i r11111111 Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic 0 Illtt AR. rimmi Valve,Lower Master,WKM-M, toTii. ;q 4 1/16 5M FE . ti imild Tubing Adapter,41/16 5M jjjjj Image .ject Well History File c!er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .2 03 - L 4:- 3 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RES CAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner D Color Items: o Greyscale Items: D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: DatelJ- 13/D5 o Other:: BY: r3 /s/ vY1\P 111/111111111111111 VV\f Project Proofing Scanning Preparation BY: ~ 3 Date Ig).... 1':/ os- x 30 = q() +;J£J = TOTAL PAGES J / 0 '/ (Count does not include cover s~eet) \AA itJ. Date: Ia- la I D.S /s/ V V, , 1111111111111111111 /s/ BY: ~ Production Scanning Stage 1 Page Count from Scanned File: i I J (Count does include cover sheet) Page Count Matches Number in scanni~~ pre!.aration: V YES BY: ~ Date: B- la/OS Stage 1 If NO in stage 1, page(s) discrepancies were found: NO /s/ V\1p YES NO BY: Maria Date: /s/ 111/1111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked "I "111111/ "1111/ 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA RECEIVED AKA OIL AND GAS CONSERVATION CO.ISSION V C V REPORT OF SUNDRY WELL OPERATIONS SEP 1 0 2012 1. Operations Performed: AIasKa Ud & Cias (Ans. GOmmIF' ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter SuspendQdlii" tlrage ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver °Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension RC[P lace' l „ c r p u yvt p 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 203 - 143 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ,t,. 50 029 - 23175 - 00 - 00 7. Property Designation (Lease Numbe,r): � qT . .1 8. Well Name and Number: _ ADL 380109 8,b249.96 C1,1663 it q1,? MPS - 9. Logs (list logs and submit electronic and printed data per 20AA 25.07 ): 10. Field / Pool(s): „ Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 14804' feet Plugs (measured) None feet true vertical 4111' feet Junk (measured) None feet Effective depth: measured 14804' feet Packer: (measured) 9546' feet true vertical 4111' feet Packer: (true vertical) 3882' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 35' - 110' 35' - 110' 1490 470 Surface 5584' 10 -3/4" 34' - 5816' 34' - 2904' 5210 2480 Intermediate 10719' 7 -5/8" 32' - 10751' 32' - 4089' 6890 4790 Production Liner 4751' 4 x 4" 10650' - 14804' 4076' - 4111' Perforation Depth: Measured Depth: 10761' - 14757' True Vertical Depth: 4090' - 4111' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr85 10655' 4077' Packers and SSSV (type, measured and true vertical depth): 7 - 5/8" x 4 - 1/2" HES TNT Packer 9546' 3882' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED 'MAR 012013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 224 0 95 2199 222 Subsequent to operation: 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations 16. Well Status after work: — _1 Oil ❑ Gas ❑ WDSPL ❑ Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. 1 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 David Bjork, 564 -5683 N/A Printed Name Joe Lastufka Title Drilling Technologist Prepared By Name /Number. Signature P e rA ,.. Date Joe Lastufka, 564 -4091 Form 10 -404 Re ReD S SEP 1 1 20 � . , � i somit Original Only • MPS -35, Well History (Pre Rig Workover) Date Summary 06/22/12 RIG UP. FUNCTION TEST BOP'S, RIH W/ BHA; 2.25" CTC, 2.13" DFCV, BI -JARS, DISCO, 2" BURST SUB, 3.13" CROSSOVER, 3.5" OD (4" GS). 06/23/12 Continue POH with JSN BHA. M/U Baker 3.5" G Spear BHA. PT lube. RIH. Latch jet pump at 9577'. Pick V t up, jar one time. Pick up second time and pulled free with 10K overpull. POH with jet pump. Load well 1 down backside while POH. Lay out jet pump and Baker tools. PT Baker MHA. PDS logging tools with j carrier. Log @ 40 fphm from 9700 to 9000'. pooh. Data good. +2' correction to pipe tally. MU and RIH w/ P BHA; 2.25" ctc, 2.14" dfcv, disco, 2" crossover, 1.69" crossover, 1.68" inflation valve,1.72" setting tool, 2.56" setting sleeve, 2.76" CIBP(oal= 17.92) Stop and correct depth @ flag. Set CIBP at target depth of 5e f 9665'. pooh. Lay out running tools. Pressure test surface lines to 4300 psi. Circ 226 bbl hot KCL water C 1 13 1 down IA and up tubing. Freeze protect IA with 64 bbl diesel. Pressure test IA to 4200 psi for 30 min., p r t t- Good Test. 06/24/12 PJSM. M/U PDS GR /CCL logging carrier with Baker MHA and 2.70" JSN. PT lubricator. RIH with memory logging tools. Tag CIBP at 9658' up depth. Log up to 9100'. Log repeat pass. Log up to flag depth at 9601'. Paint new flag at 9601' and POH. PJSM. Lay out logging tools. Good data. RIH w/ BHA 2.25" ctc,2.13" dfcv,disco, 2.15" sealed knuckle joint, E -fire firing head, 2.5" jet cutter (oal= 17.9') Tie in and , stop at 9625 target depth (middle of pup above packer). Go thru E -Fire firing sequence twice and did not get an indication of firing. pooh. Jet utter did fire.. u and I w ctc,2.13" dfcv,disco, 2.04" crossover, two 2" stingers, 2" nozzle (oal= 12.3'). RIH with nozzle to 9600'. Circ 250 bbl hot KCL down coil with returns from IA to open top tank. POH with coil while circ KCL to 6800'. Pump 66 bbls diesel down IA to freeze protect IA to 2500'. POH and lay in diesel in tubing from 4500' to surface, 76 bbl, to chase any crude out of tubing and freeze protect tubing. At surface. Close swab and SSV. L/O BHA. N/D BOPE. N/U tree cap and PT. RDMO CTU. 06/27/12 T /I /O = vac /0/150. Support techs verified barriers (SSV, Master), installed lubricator and PT'd to 300 low 4c + p y and 3500 high. Set 4" CIW BPV to ed at 96" with 2' extension). Removed well house, verified barriers (SSV/Wing, DBB on laterals), removed flowlines from the wing to the 2nd knockout on lateral line. Installed blinds, TQ'd to spec, and leak tested to 3500. Page 1 of 1 • • ! ` f / North America ALAS o perat i on Summa Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/3/2012 00:00 - 07:00 7.00 RIGU P PRE SKID RIG FLOOR, PJSM ON MOVING RIG, JACK UP RIG AND MOVE OFF MPS-41 -MOVE ON TO MPS -35, SPOT RIG ON WELL, LEVEL AND INSTALL SHIMS AROUND RIG WHERE NEEDED - SIM -OPS= LEVEL PAD IN FRONT OF MPS-35 AND SET RIG MATS 07:00 - 09:00 2.00 RIGU P PRE RIG UP CHOKE LINE, MUD PUMP, MUD BUCKET, AND HYDRAULIC LINES UNDER RIG FLOOR - INSTALL STEAM, AIR AND WATER LINES UNDER RIG FLOOR, RIG STOKE COUNTER LINE - NIPPLE UP GAS BUSTER U -TUBE, LOCATING BRACES AND TOP DRIVE ELECTRICAL LINES SIM-OPS= RIG UP MUD PITS TO BRING ON 8.6 PPG SEA WATER 09:00 - 11:00 2.00 RIGU P DECOMP INSTALL SECOND VALVE ON IA, RIG UP HOSES FOR VOIDING DIESEL FROM WELL. -HARD LINE INSTALLING HARD LINE TO CHOKE SKID AND SLOP TANK. - RIG ACCEPTED AT 0900 HRS 8/3/12 - 11:00 - 12:00 1.00 _. WHSUR P DECOMP _PRESSURE TEST FROM TREE TO HARD LINE AND CHOKE SKID, 250 PSI LOW/ 5000 PSI HIGH, FIVE MINUTES EACH 12:00 - 13:30 1.50 WHSUR P DECOMP CONT. HARD LINE CREW PRESSURE TEST ON HARD LINE AND CHOKE SKID. 250 PSI _ LOW/ 3500 PSI HIGH. 13:30 - 14:30 1.00 WHSUR P DECOMP PRESSURE TEST RIG LINES TO HARD LINE 250 PSI LOW/ 3500 HIGH FIVE MINUTES EACH. 14:30 - 15:30 1.00 WHSUR P DECOMP PICK UP LUBRICATOR AND TEST 250 PSI LOW/ 3500 PSI HIGH FIVE MINUTES EACH 15:30 - 16:30 1.00 WHSUR P DECOMP PULL BPV AND LAY DOWN LUBRICATOR 16:30 - 19:30 3.00 CLEAN P DECOMP CIRCULATE OUT FREEZE PROTECT AND DISPLACE WITH CLEAN 8.6 PPG SEA WATER -90 BBL DOWN ANNULUS AT 5 BPM, PSI =900, 110 BBL DOWN TUBING AT 7 BPM AT 1700 PSI. -WAIT 1 HR. PUMP DOWN TUBING 220 BBL, 7 BPM AT 1700 PSI. MONITOR WELL FOR 10 MINUTES - NO FLOW 19:30 - 22:00 2.50 WHSUR P DECOMP PICK UP LUBRICATOR AND TEST 250 PSI LOW/ 3500 PSI HIGH, FIVE MINUTES EACH 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM ON TESTING TWC. R/U TO TEST TWC 7 250 PSI LOW FOR 5 MINUTES, 3500 PSI HIGH FOR 30 MINUTES FROM BELOW. 250 PSI LOW/ 3500 HIGH FOR 5 MINUTES 8/4/2012 00:00 - 01:00 1.00 KILLW P DECOMP CONT. TESTING TWC FROM ABOVE 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES. -RIG DOWN TEST EQUIPMENT AND SECURE THE TREE. 01:00 - 01:30 0.50 KILLW P DECOMP RIG EVACUATION DRILL, ALL PERSONNEL RESPONDED TO A SAFE BRIEFING AREA. Printed 8/27/2012 10.56:50AM P ;: ffi • Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 07:00 5.50 KILLW P DECOMP NIPPLE DOWN TREE AND NIPPLE UP STACK. CHECK THREADS ON HANGER, -TC -II TOOK 8 1/2 TURNS TO TIGHTEN 07:00 - 12:00 5.00 BOPSUR P DECOMP PJSM ON TESTING BOP, RIG UP TEST EQUIPMENT, TEST JTS, FULL OPEN SAFETY VALVE. - TESTING 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH. -BOP DRILL, RESPONSE TIME= 1 MIN. 39 SECONDS. - GAS BUSTER FILL UP = 6 BBLS - WITNESS OF BOP TEST WAS WAIVED BY AOGCC CHUCK SHIEVE rtS 12:00 - 14:30 2.50 BOPSUR P DECOMP CONT. TESTING BOP EQUIPMENT AS PER STANDARD OPERATING PROCEDURE. 1301' -250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH. - 4' AND 4-1/2" TEST JOINT 14:30 - 17:00 2.50 BOPSUR P DECOMP RIG UP DUTCH RISER, PICK UP LUBRICATOR AND TEST W/ DUTCH RISER TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH. PULL TING, NO PRESSURE UNDERNEATH. - LAY DOWN LUBRICATOR AND DUTCH RISER SYSTEM. 17:00 - 18:30 1.50 MOB P DECOMP RIG UP CASING EQUIPMENT AND I-WIRE SPOOLER. - MONITORING WELL WITH TRIP TANK 18:30 - 21:30 3.00 PULL _ P DECOMP PICK UP 4" DP AND MAKE UP TCII X -OVER, MAKE UP TO HANGER., SUCK OUT STACK -BACK OUT LOCK SCREWS AND PULL HANGER, BROKE OVER AT 200K, PUW =140K WITH 50K TOP DRIVE. - SECURE I -WIRE, LAY DOWN HANGER, RUN IN HOLE W/ FIRST JT TO PLACE SLICK PIPE ACROSS STACK. 21:30 - 22:00 0.50 PULL P DECOMP SHUT BAG, LINE UP ON CHOKE AND GAS BUSTER THOUGH SUPER CHOKE. - CIRCULATE BOTTOM UP AT 5 BPM, PS 300 -KICK WHILE DRILLING DRILL= 2:10 MINUTES 22:00 - 00:00 2.00 PULL P DECOMP 10 MINUTES FLOW CHECK, OPEN WELL OBTAIN SLOW PUMP RATE -PRE JOB SAFETY MEETING, PULL OUT OF HOLE FROM 9625', PUW =135, SOW =7 -SLOW PUMP RATE @ 9625 MD , 8.5 PPG MW MUD PUMP #1. 20 SPM =50 PSI, 30 SPM=90 PSI MUD PUMP #2. 20 SPM =50 PSI, 30 SPM=90 PSI 8/5/2012 00:00 - 10:30 10.50 PULL P DECOMP PULL 41/2" IBT CASING FROM 8600' TO 1116' - AT 03:30 TO 04:00 AM CHANGE OUT ELEVATOR SETTING PLATE BOLT 10:30 - 11:00 0.50 PULL P DECOMP MONITOR WELL THE WELL WITH TRIP TANK, INSPECT HYDRAULIC HOSE UNDERNEATH RIG FLOOR 11:00 - 12:00 1.00 PULL N RREP DECOMP CHANGED OUT HYDRAULIC HOSE UNDERNEATH RIG FLOOR, SIM -OPS CLEAN RESIDUAL OIL AND DEBRIS FROM TUBING, HOUSE KEEPING 12:00 - 14:00 2.00 PULL P DECOMP CONT. LAY DOWN 12.6# 4 -1/2" IBT TUBING FROM 1116'. TOOK OUT 232 CLAMPS, I 'T" "" STEEL BAND - FLARE OD= 4 -1/2 ", CUT JOINT= 4.38' Printed 8/27/2012 10:56:50AM North America ALASKA 1 :4, ; F f Operation Summary Report Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 16:30 2.50 FISH P ■- DECOMP CLEAN CASING EQUIPMENT OFF F SPOOLER, MOBILIZE OFF RIG FLOOR. OR. CLEAN RIG FLOOR 16:30 - 17:00 0.50 FISH P DECOMP LUBRICATE RIG 17:00 - 18:30 1.50 FISH P DECOMP 150 PSI ON 0/A, BLEED OFF 0/A (FLUID APPEARS TO BE DIRTY DIESEL - 6.8PPG), 'ICK UP BHA TO DRESS 3 -1/2" TUBING STUB AND SCRAPE THE 7 -5/8" 29.7# CASING SET WEAR BUSHING - -- ID = 9 1/16" 18:30 - 00:00 5.50 FISH P DECOMP MAKE UP BHA AND RUN IN HOLE 4" DP 1X1 FROM PIPE SHED to 3500' -BLED BACK 7 BBL FROM 0/A TO BLEED OFF TANK, 150 PSI ON 0/A 8/6/2012 00:00 - 06:00 6.00 FISH P DECOMP RIH W /BHA 1 O SCRAPE, CASING AND DRESS OFF 3 1/2" TUBING STUB - PICKING UP SINGLES OUT OF THE PIPE SHED - TAGGED 28' IN ON JOINT 294 AT 9626' 06:00 - 06:30 0.50 FISH P DECOMP START CIRCULATING STAGING UP PUMPS TO 96 SPM, 390 GPM W/ 1860 PSI, 60 RPM W/ 90K TORQUE. -OBTAIN SLOW PUMP RATES, PUMP #1- 20 STKS= 150 PSI, 30 STKS= 280 PSI / PUMP #2- 20 STKS= 160 PSI, 30 STKS= 320 PSI WITH 8.5 PPG SEA WATER. POW =180, SOW =65, ROT =110 06:30 - 08:30 2.00 'FISH P DECOMP PUMP 30 BBL ECF -1840 SOAP SWEEP FOLLOWED BY 8.5 PPG SEA WATER. -CIRC. S/S 3900, STKS OVER BOARD SOAP SWEEP TO ROCK WASHER 08:30 - 09:00 0.50 FISH P DECOMP RIH AND DRESS OFF 3 -1/2" TUBING STUB, CIRC 40 SPM, 164 GPM W/ 370 PSI, 60 RPM W/ 7K TORQUE,POW= 145K, SOW =85K -DRESS OFF SHOE SWALLOWED 1.9, PICK UP OFF TUBING STUB. PUMPS ON 40 SPM, 164 GPM W/ 80 RPM, 7K TORQUE -P /U OFF TUBING STUB, RIH W/ PUMPS OFF TO VERIFY TUBING SWALLOWED AND DRESSED OFF. -PULL OFF TUBING STUB AND CIRCULATE. 09:00 - 11:00 2.00 FISH P -_ DECOMP CONT. CIRCULATE, 95 SPM, 387 GPM W/ 1720 PSI 11:00 - 12:00 1.00 FISH P ■- DECOMP PUMP 40 BBL HIGH VIS SWEEP BY 8.5 PPG, S/S STKS 3900, OVERBOARD ERBORBOARD RD HIGH VIS TO ROCK WASHER 12:00 - 12:30 0.50 FISH P DECOMP CONT. CIRCULATE 8 BPM @ 1220 PSI, RPM =60, TORQUE= 5K, PUW =145K, SOW= 87K -OUTER ANNULUS •• 150 PSI 12:30 - 13:30 1.00 FISH P ._ DECOMP SPR, FLOW CHECK 10 MINUTES, POOH FROM 9593' TO 8675' 13:30 - 14:30 1.00 FISH P DECOMP SLIP AND CUT 14:30 - 15:00 0.50 FISH P DECOMP LUBRICATE AND SERVICE RIG 15:00 - 18:30 3.50 FISH P DECOMP CONT. POOH FROM 8675' TO 321' 18:30 - 20:00 1.50 FISH P ._ DECOMP FLOW CHECK 10 MINUTES, RACK BACK 3 STND COLLARS, LAY DOWN BHA 20:00 - 21:00 1.00 FISH P -_ DECOMP TEST 7 -5/8" CASING, 250 PSI LOW FIVE NUTES/ 3500 PSI HIGH 30 MIN T Printed 8/27/2012 10:56:50AM Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 FISH P DECOMP RIG UP SLB WELL SERVICES SLICK LINE UNIT, PICK UP LOGGING TOOLS -0/A @ 100 PSI. BLED OFF 17 BBL TOTAL FOR THE DAY -SPR @ 9593' MD, MW =8.5 -MUD PUMP #1, 20 SPM= 100, 30 SPM= 210 -MUD PUMP #2, 20 SPM= 100, 30 SPM = 210 8/7/2012 00:00 - 05:00 5.00 EVAL N DFAL 1,000.00 DECOMP "RUN PDS MTT LOG W/ SLB SLICKLINE UNIT. -RIH W/ MTT LOGGING TOOL TO 1000 FT AND LOG OUT OF HOLE. 05:00 - 08:00 3.00 EVAL P DECOMP DOWNLOAD INFORMATION FROM MTT TOOL. -TOOL STOPPED RECORDING AT 350 FT. - RU AND RIH W/ CALIPER LOG WHILE TROUBLESHOOTING MTT TOOL. 08:00 - 09:00 1.00 EVAL P DECOMP -RIH W/ CALIPER TOOLS, POOH @ 0900 09:00 - 12:00 3.00 EVAL P DECOMP C/O CALIPER TOOLS TO MTT TOOL AND RIH - OA PRESSURE AT NOON =155 PSI, BLED BACK 7.75 BBLS. 12:00 - 15:00 3.00 EVAL P DECOMP CONT. LOGGING W/ MTT TOOL 15:00 - 16:30 1.50 DEMOB P DECOMP RIG DOWN WIRELINE, LAY DOWN WIRELINE TOOLS AND SHEAVES. -MOBILIZE BHA #2 TO RIG FLOOR. 16:30 - 18:00 1.50 FISH P DECOMP MAKE UP BURN OVER SHOE BHA. -MAKE UP 6 -3/4" X 5 -1/4" BURN OVER SHOE MILL #1 -MAKE UP MILLING BHA #1. 18:00 - 22:30 4.50 FISH P DECOMP TRIP IN HOLE WITH BURN OVER SHOE MILL #1 - PICK UP 33 JTS 4" DP FROM PIPE SHED FROM 375 TO 1420 FT. -RIH FROM DERRICK TO 9625 FT. 22:30 - 00:00 1.50 FISH P DECOMP PJSM ON PACKER GAS AND WELL CONTROL FOR MILLING OPERATIONS. - TAKE SPRS. - ESTABLISH MILLING BASE LINE PARAMETERS: - PU =135K, SO =87K, ROT= 110K, 247 GPM W/ 880 PSI ON AND 830 PSI OFF. - 80 RPM W/ TORQ 7K ON AND 4K OFF. AND WOB= 5K. -TAG TOP OF PACKER AT 9631 FT. *FIRE DRILL= 1:30 MINUTES/ TABLE TOP H2S DRILL *OA PRESSURE AT MIDNIGHT =200 PSI. r On 8/8/2012 00:00 - 12:00 12.00 FISH P DECOMP MILL PREMIER PACKER AT 9631 FT. -247 GPM AT 830 PSI. -80 RPM AT 9K TORQUE. -4 TO 8K WOB. - VARIED WOB FROM 2 TO 22K. - VARIED RPM FROM 60 TO 100. - VARIED PUMP FROM 126 TO 252 GPM. -DRY MILLED FOR 50 MINUTES PER HOUR. - MILLED TOTAL OF 8 INCHES. -OA PRESSURE @ 11:30 = 200 PSI Printed 8/27/2012 10:56:50AM :� N orth America - ALASKA ' Operation Summary Re r Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 00:00 12.00 FISH P DECOMP MILL PACKER FROM 9631 FT. -RPM= 100, TORQ OFF= 9K1 ORQ ON= 12K - GPM= 235, PSI OFF= 654, PSI ON= 654, WOB= 15K -PU= 135K, SO= 87K, ROT= 110K. - VARIED WOB FROM 2 TO 22K. - VARIED RPM FROM 60 TO 100. -VARIED PUMP FROM 126 TO 252 GPM. -DRY MILLED FOR 50 MINUTES PER HOUR. - MILLED 0 INCHES IN 12 HOURS. - TOTAL PACKER MILLED = 8 INCHES. - TORQUE SMOOTH AND 24.0 HOURS ON MILL SHOE #1. - OA PRESSURE @ 23:30 = 250 PSI 8/9/2012 00:00 - 04:00 4.00 FISH P DECOMP PJSM ON PIPE TRIPPING OPERATION. - MONITOR WELL FOR 10 MINUTES - STATIC. -TAKE SPRS. -TRIP OUT OF HOLE WITH MILL SHOE #1 (HOURS AND SMOOTH TORQUE). -FILL HOLE EVERY 5 STANDS. 04:00 - 04:30 0.50 FISH P DECOMP MONITOR WELL FOR 10 MINUTES AT LAST STAND OF DP - STATIC. -PULL 3 STDS DC. 04:30 - 06:00 1.50 _ FISH P DECOMP PJSM ON HANDLING BHA OPERATION. -LD JAR ASSEMBLY. -CLEAN MAGNETS. - LD BOOT BASKETS. -LD BURN SHOE MILL #1. *SKIN OF METAL RECOVERED FROM TOP BOOT BASKET: 5 -1/2" X 3 -1/2 ". *MILL #1: METAL MUNCHER BUTTONS PRESENT AND CUT -RITE WORN SMOOTH. *WATER COURSES STILL AT 7/8". 06:00 - 07:00 1.00 FISH P DECOMP MOBILIZE BHA #3 TO RIG FLOOR - CLEAN OUT BOOT BASKETS. - SERVICE AND LUBRICATE RIG. 07:00 - 12:00 5.00 FISH P DECOMP PJSM ON MAKE UP BHA #3 -MAKE UP BURN SHOE MILL #2 (6 -3/4" X 5- 1/4"). -RUN IN HOLE FROM 375 TO 8937 FT. -FIRE DRILL- RESPONSE TIME= 1 MINUTE, 56 SECONDS -OA PRESSURE @ 11:30= 165 PSI 12:00 - 12:30 0.50 FISH P DECOMP SERVICE/ LUBRICATE RIG 12:30 - 13:00 0.50 FISH P DECOMP RUN IN HOLE, CONT. -FROM 8937 TO 9631 FT. 13:00 - 20:00 7.00 FISH P DECOMP MILL PACKER FROM 9631 FT. -RPM= 100, TORQ OFF= 4K, TORQ ON= 11K. -GPM= 6, PSI OFF= 800, PSI= 880, WOB= 15K. - PU= 155K, SO= 87K, ROT= 110K. -MADE 2" IN FIRST HOUR. - PARAMATERS VARIED AS FOLLOWS: -RPM: 20 TO 120. -WOB: 4 TO 25K. -PUMP: 0 TO 252 GPM. *H2S DRILL/ RIG EVACUATION. Printed 8/27/2012 10:56:50AM r 40, North America - ALASKA Operation Summary R Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:00 2.00 FISH P DECOMP OBSERVE FLUID LOSS OF 16 BBL WHILE MILLING IN 2 MINUTES. -FILL AND MONITOR WELL. OBSERVE FLUID FALL TO GL IN 5 MINUTES. FILL AND REPEAT. -SET 40K WOB AND NO GO. - PICK UP 10 FT AND CLOSE ANNULAR TO BULLHEAD. -PUMP 52 BBL SEAWATER AND STABILIZE RATES: -1.0 BPM DOWN DRILL PIPE AT 1750 PSI AND 3.2 BPM DOWN CASING AT 1850 PSI. - BULLHEAD AN ADDITIONAL 300 BBL SEAWATER. 22:00 - 22:30 0.50 FISH P - ` DECOMP WATCH PRESSURE BLEED FROM 1850 TO 350 PSI IN 5 MINUTES. -BLEED OFF PRESSURE AND OPEN ANNULAR. - MONITOR WELL FOR 10 MINUTES - WELL TAKING FLUID. 22:30 - 00:00 1.50 FISH P DECOMP MILL PACKER FROM 9632 FT. - -RPM= 100, TORQ OFF =4K, TORQ ON= 11K. -GPM= 162, PSI OFF= 300, PSI ON= 300, WOB= 15K. - PARAMETERS VARIED AS FOLLOWS: -RPM: 20 TO 120. -WOB: 4 TO 25K. -PUMP: 0 TO 252 GPM. -PU= 155K, SO= 87K, ROT= 110. *WELL TAKING FLUID AT — 15 BPH. "TOTAL PACKER MILLED 11 INCHES. "TOTAL FLUID LOSS FOR DAY = 390 BBL. *OA PRESSURE AT 23:30= 160 PSI 8/10/2012 00:00 - 03:00 3.00 FISH P DECOMP MILL PREMIER PACKER AT 9632 FT, CONT. - PARAMETERS VARIED AS FOLLOWS: -RPM: 20 TO 120. -WOB: 4 TO 25K. -PUMP: 0 TO 252 GPM. *PACKER FREE AND PUSH TO 9675 FT. 03:00 - 04:00 1.00 FISH P DECOMP MONITOR WELL. -FLUID LEVEL FELL TO GL IN 5 MINUTES. -CLOSE ANNULAR. - BULLHEAD 100 BBL OF SEAWATER DOWN CASING AND DRILL PIPE. -1.5 BPM DOWN TUBING AT 1450 PSI AND 4.5 BPM DOWN CASING AT 1750 PSI. - BLEED OFF FROM 1750 TO 500 PSI IN 2 MINUTES. - OPEN ANNULAR AND MONITOR WELL FOR 10 MINUTES - FLUID FELL TO GL IN 5 MINUTES 2X. 04:00 - 04:30 0.50 FISH P DECOMP PUSH PACKER TO 10,180 FT. - PACKER STOPPED AT 10,180 FT (MILL DEPTH). -SET 30K DOWN 2X. (NOTE: TIE BACK SLEEVE AT 10,650 FT). Printed 8/27/2012 10:56:50AM b -( . ' Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4 -OOWFD E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @s71.68ft (above Mean Sea Level) Date From - To Hr @s Task Code NPT NPT (ft) Depth Phase Description of Operations (hr) 04:30 - 09:00 4.50 FISH P DECOMP PJSM ON TRIPPING OUT OF HOLE OPERATION. -TRIP OUT OF HOLE WITH MILL # 10180 TO 375 FT FILLING HOLE EVERY 5 STDS. FIRST FILL 9.0 BBL (6.5 BBL OVER) *AOGCC: BOB NOBLE WAIVD WITNESS 2.FROM OF BOPS TEST AT 08:20 AM 08- 10 -12. 09:00 - 09:30 0.50 FISH P DECOMP FLOW CHECK W! 1 STD DP AND BHA. -FLUID LEVEL FALLING. -RACK BACK 3 STANDS OF 4 -3/4 COLLARS 09:30 - 11:00 1.50 FISH P DECOMP PJSM ON HANING BHA. HANDLE BHA. - LAYDOWN BOOT BASKETS. E LAYDOWN MILL #2. 11:00 - 12:30 1.50 FISH P DECOMP MOB AND DEMOB FISHING TOOLS TO RIG FLOOR. -DEMOB BOOT BASKETS. -MOB INTENSIFIERS AND OVERSHOT. - CONTINUOUS HOLE FILL. 12:30 - 13:30 1.00 FISH P DECOMP PJSM ON PICKING UP FISHING BHA DRILL #4. HING BH -PICK UPN 6 -1/2" X 5 -3/4" GUIDE. -PICK UP 5 -3/4" OVERSHOT DRESSED W/ 3.5" SPIRAL GRAPPLE AND 3 -5/8" MILL CONTROL/PACK -OFF. - HOLE COLLARS. -PICK RUN UP IN INTENSIFIERS. WITH 13:30 - 16:00 2.50 FISH P DECOMP TRIP IN HOLE WITH OVERSHOT BHA AND FISA #4. -FROM 335 AND IN FT TO 5082 ILL FT. 16:00 - 18:00 2.00 FISH P DECOMP PJSM VIC SLIP AND CUT DRILL LINE OPERATION. -SLIP SE AND CUT DR LINE. - RE INSPECT TOP DRIVE, BLOCKS AND DRAWWORKS 18:00 - 20:00 2.00 FISH P DECOMP LE OPERATION -RUN PJSM IN HOLE FR IN OM 5082 FT TO 10,11 - OBTAIN SLOW PUMP HO RATES AT 10,11. 7 7 FT. . FT 20:00 - 20:30 0.50 FISH P DECOMP ENGAGE FISH. - ESTABLISH PARA RUNNING METERS: -PU 170K AND SO 78K. -4.0 BPM AT 330 PSI. - TORQUE. - ENGAGE FISH 0, -PUMP PRESSURE 5K AT INC REASED FROM 330 TO 62 0 PSI. RPM - UNABLE AT TO SET WEIGHT. FT. 20:30 - 22:00 1.50 FISH P DECOMP CHASE FISH TO TIE 1 BACK SLEEVE AT LINER TOP. - HOL FROM ,173 TO 10,615 FT -SET RUN 30K ON FISH. - PRESS URE T O 400 PSI 10 TO VERIFY FIS . H ENGAGED. Printed 8/27/2012 10:56:50AM " z0 • ,,#ion Summ, Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 FISH P DECOMP DROP OPENING DART FOR PUMP OUT SUB. -LET FALL FOR 20 MINUTES. -PUMP DART DOWN WITH 80 BBLS AT 4.0 BPM AND 2500 PSI. -PUMP OUT SUB SHEARED. - CIRCULATE BOTTOMS UP AT 6.0 BPM AND 910 PSI FOR 4200 STROKES. `FLUID LOSS TO HOLE FOR 24 HOURS = 550 BBL. *OA PRESSURE = 165 PSI. "BARRIERS: TESTED BOPE AND KWF. 8/11/2012 00:00 - 00:30 0.50 FISH P DECOMP TAKE SPRS THROUGH PUMP OUT SUB. - MONITOR WELL -FLOW CHECK FOR 10 MINUTES - FLUID LEVEL FALLING. -SPR @ 10564 FT 8.5 PPG CIRCULATE THROUGH PUMP OUT SUB " #1 MUD PUMP 20 STROKES 100 PSI, 30 STROKES 220 PSI *#2 MUD PUMP 20 STROKES 90 PSI, 30 STROKES 240 PSI 00:30 - 06:00 5.50 FISH P DECOMP TRIP OUT OF HOLE WITH FISH/PACKER. -FROM 10,592 TO 335 FT. -FILL HOLE EVERY 5 STDS. -PULL SLOWLY TO DUE TO FISH AND TO PREVENT SWABBING. 06:00 - 06:30 0.50 FISH P DECOMP FLOW CHECK FOR 10 MINUTES. -FLUID LEVEL FALLING. -RACK BACK 3 STANDS DRILL COLLARS. 06:30 - 09:30 3.00 FISH P DECOMP PJSM ON LAYING DOWN FISHING TOOLS AND FISH OPERATION. - MOBILIZE TOOLS TO RIG FLOOR NEEDED FOR TUBING PUNCH. -LAY DOWN FISHING TOOLS: BOOT BASKETS, MAGNETS AND JARS. -PUNCH HOLES IN TAIL PIPE AND DRAIN. `TOTAL LENGTH OF FISH RECOVERED: 61.83 FT. *PACKER MILLED TO MID BOTTOM SLIPS. "SIM OPS CIRCULATE THROUGH IA TO KEEP HOLE FULL. 09:30 - 11:00 1.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR OF FISHING TOOLS. MAKE UP STACK WASHER AND FLUSH BOP STACK. 11:00 - 11:30 0.50 BOPSUR N RREP DECOMP PJSM ON RIG SHUT DOWN. -POWER DOWN RIG. - TROUBLE SHOOT SCR BANK. -POWER UP RIG. 12:00 - 14:30 2.50 BOPSUR P DECOMP PJSM RIG UP TO TEST BOPE. -RIG UP TEST EQUIPMENT AND CHART RECORDER. -RIG UP TEST JOINT WITH FOSV. Printed 8/27/2012 10:56:50AM North America - ALASKA a k` O • era ion Summary Rep • Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 20:00 6.00 BOPSUR P DECOMP PJSM TESTING BOPE OPERATION. -TEST BOPE: ANNULAR, (2) VBRS, BLIND /SHEARS, HCR CHOKE/KILL, MANUAL CHOKE/KILL. - VALVES 1 THROUGH 14, (3) FOSVS, DART VALVE. - UPPER IBOP, MANUAL IBOP, ADJUSTABLE CHOKE VALVES AND KILL LINE VALVE. -VBRS TESTED WITH 4 -1/2" AND 4" TEST JOINTS. ANNULAR TESTED WITH4" TEST JOINT. - KOOMEY DRAWDOWN TEST. *ALL TESTED TO 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES AND CHARTED. *ALL TEST ACCORDING TO AOGCC AND ADWOP SPECS. * AOGCC, BOB NOBLE WAIVED WITNESS TO BOP TEST. 20:00 - 21:00 1.00 BOPSUR r P DECOMP PJSM RIG DOWN BOPE TEST EQUIPMENT OPERATION. -BLOW DOWN CHOKE MANIFOLD AND CHOKE LINE. -BLOW DOWN KILL LINE. 21:00 - 22:00 1.00 CLEAN P DECOMP PJSM ON MOBILIZE POLISH MILL TOOLS TO RIG FLOOR OPERATION. - MOBILIZE BOOT BASKETS, MAGNETS AND POLISH MILL TO RIG FLOOR. 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM HANDLE BHA OPERATION. - MAKE UP POLISH MILL (BHA #5). -MAKE UP BOOT BASKETS, STRING MAGNETS, BUMPER AND OIL JARS. - RUN 3 STDS DC'S. *FLUID LOSS FOR 24 HOURS: 526 BBL. *OA PRESSURE: 150 PSI. *BARRIERS: TESTED BOPE AND KWF. 8/12/2012 00:00 - 04:30 4.50 CLEAN P DECOMP PJSM ON TRIPPING PIPE OPERATION. -TRIP IN HOLE WITH POLISH MILL. - FROM 345 TO 10,635 FT. 04:30 - 05:00 0.50 CLEAN P DECOMP POLISH MILL OPERATION. -PU 180K AND SO 63K. LOCATE TOP OF SLEEVE AT 10,649 AND BOTTOM AT 10,654 W/O ROTATION. ESTABLISH PARAMETERS: -4.2 BPM AT 420 PSI. -30 RPM AT 8K TORQUE. POLISH MILL PER BAKER REP. - TORQUE INCREASED FROM 8K TO 12K WHEN MILL THROUGH SLEEVE. - POLISH SLEEVE FOR 15 MINUTES AT 60 RPM MAKING MULTIPLE PASSES. -SET 10K W/O ROTATION TO VERIFY BOTTOM AT 10,654 FT. 05:00 - 07:00 2.00 CLEAN P DECOMP PUMP HIGH VISC SWEEPS AND CIRCULATE. -TAKE SPRS. - PUMP 15 BBL HIGH VISC SWEEP #1. -8.7 BPM AT 1600 PSI. -80 RPM AT 10K TORQUE. -CHASE WITH 50 BBL SEAWATER. -PUMP 15 BBL HIGH VISC SWEEP #2. CIRCULATE /SWEEP AND RECIPROCATE/ROTATE AT 8.7 BPM AND 80 RPM. Printed 8/27/2012 10:56:50AM , < . Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 07:30 0.50 CLEAN P DECOMP PJSM LAYING DOWN DRILL PIPE IN PIPE SHED. - FLOW CHECK 10 MINS - FLUID LEVEL FALLING. 07:30 - 12:00 4.50 CLEAN P DECOMP PULL OUT OF HOLE LAYING DOWN DRILL PIPE SINGLES IN PIPE SHED. - FROM 10,654 FT TO 6709 FT 12:00 - 12:30 0.50 CLEAN P DECOMP RIG SERVICE. - SERVICE AND INSPECT TOP DRIVE, DRAWWORKS AND BLOCKS. 12:30 - 18:00 5.50 CLEAN P DECOMP LAY DOWN SINGLES OF DRILL PIPE IN PIPE SHED, CONT. -FROM 6709 FT TO 345 FT FLOW CHECK WITH LAST JOINT OF DRILL PIPE FOR 10 MINUTES - FL FALLING. 18:00 - 19:30 1.50 CLEAN P DECOMP PJSM ON LAYING DOWN BHA OPERATION. -LAY DOWN (9) DRILL COLLARS AND CLEAN/LAY DOWN MAGNETS. -LAY DOWN AND CLEAN BOOT BASKETS. -LAYDOWN POLISH MILL. *POLISH MILL SHOWED WEAR ON MILL AND TATTLE TALES WERE WORN DOWN. 19:30 - 20:30 1.00 CLEAN P DECOMP PJSM DEMOB TOOLS FROM RIG FLOOR OPERATION. -DEMOB FISHING TOOLS FROM RIG FLOOR. -CLEAN RIG FLOOR. -BLOW DOWN TOP DRIVE. 20:30 - 23:00 2.50 BOPSUR P RUNCMP PJSM FUNCTION ON TEST RUNNING TUBING HANGER OPERATION. -PICK UP ONE JOINT 4 INCH DRILL PIPE W/ STACK WASHER. - WASH STACK WITH 11.0 BPM AND RECIPROCATION AND ROTATION. - FUNCTION 2 7/8 INCH X 5 INCH VBRS. - FUNCTION 3 1/2 INCH X 6 INCH VBRS. - FUNCTION ANNULAR AND FLUSH STACK AGAIN. TEST RUN FMC TUBING HANGER. -FMC TECH VERIFIED LANDED. MARK LANDING JOINT. (30.2 FT IN). 23:00 - 00:00 1.00 RUNCOM P RUNCMP MOBILIZE TOOLS TO RUN COMPLETION ASSEMBLY. -MAKE UP SAFTEY JOINT W/ X -OVER TO VAM TOP PIN. - X -OUT TO LONG BALES. - MOBILIZE SLB I -LINE SPOOLER TO RIG FLOOR. - MOBILIZE CANON CLAMPS TO RIG FLOOR. *FLUID LOSS IN 24 HOURS: 590 BBL. *OA PRESSURE: 240 PSI. *BARRIERS: TESTED BOPE AND KWF. (CONTINUOUS HOLE FILL). 8/13/2012 00:00 - 02:00 2.00 RUNCOM P RUNCMP PJSM ON RIGGING UP COMPLETION RUNNING EQUIPMENT. - MOBILIZE CASING RUNNING EQUIPMENT TO RIG FLOOR. - MOBILIZE CANON CLAMPS TO RIG FLOOR. -RIG UP CASING TONGS AND EQUIPMENT. -RIG UP SLB I -LINE SPOOLER. Printed 8/27/2012 10:56:50AM Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4 OOWFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 02:00 - 03:00 1.00 RUNCOM P RUNCMP PJSM ON RUNNING COMPLETION ASSEMBLY. -DOYON DRILLING AND CASING, SLB AND HES PERSONNEL. -PICK UP WIRELINE ENTRY GUIDE AND JOINT #1. 03:00 - 04:30 1.50 RUNCOM N SFAL RUNCMP CHANGE OUT DOYON CASING TONGS. - CRACKED HYDRAULIC FITTING. -TROUBLE SHOOT TORQUE TURN POWER. 04:30 - 12:00. 7.50 RUNCOM P RUNCMP RUN 4 -1/2" COMPLETION ASSEMBLY PER WELL PROGRAM. s 4 - -1/2" 12.6# 13Cr VAM TOP (SUMITOMO). - STABBING GUIDE IN USE. - MAKE -UP TORQUE: 4440 FT -LB USING TORQUE TURN. - THREAD COMPOUND: JET LUBE SEAL GUARD. -RUN IN HOLE FROM SURFACE TO 3286 FT. -TEST I -LINE EVERY 10 JTS. 12:00 - 00:00 12.00 RUNCOM P RUNCMP RUN COMPLETION ASSEMBLY, CONT. -FROM 3286 FT TO 9847 FT. -TEST I -WIRE EVERY 10 JOINTS. *OA PRESSURE: 100 PSI. *24 FLUID LOST TO HOLE: 543 BBL. *BARRIERS: TESTED BOPE AND KWF. 8/14/2012 00:00 - 01:00 1.00 RUNCOM P RUNCMP RUN COMPLETION ASSEMBLY, CONT. -FROM 9847 TO 10,551 FT. - TESTING I -WIRE EVERY 10 JTS. 01:00 - 02:30 1.50 RUNCOM P RUNCMP SPACE OUT TUBING ON DOWNSTROKE. - RUN 3 JOINTS AND TAG AT 10,656 FT. (6 FT INSIDE TIE -BACK SLEEVE). -LD 3 JOINTS AND RUN (4) PUPS (25.54 FT). - RUN 1 JOINT TUBING. 02:30 03:00 0.50 RUNCOM P RUNCMP LAND TUBING IN WELLHEAD. - PU =138K AND SO =72K. -PICK UP LANDING JOINT WITH FMC PORTED TUBING HANGER. - THREAD I -LINE THROUGH HANGER. - PRESSURE TEST PORT TO 5000 PSI -OK. TEST I -LINE FOR CONTINUITY -OK. -TEST PRESSURE GUAGES: 1550 PSI. - LAND HANGER IN WELLHEAD. =FMC TECH VERIFY SET AND RUN IN ULDS. -RAN 251 JOINTS TUBING. -RAN 241 CANON CLAMPS W/ 2 PINS PER CLAMP. - RAN 4 HALF - CLAMPS W/ 1 PIN PER CLAMP. *WLEG AT 10,655 FT. 03:00 - 05:00 2.00 RUNCOM P RUNCMP PJSM ON REVERSE CIRCULATION OPERATION. -RIG UP MANIFOLD, HOSES AND PRESSURE SENSORS. - PRESSURE TEST LINES TO 1000 PSI - LEAK TITE OK. 05:00 - 07:00 2.00 RUNCOM P RUNCMP CHANGE OVER WELL BORE FLUID. - REVERSE CIRCULATE 150 BBL 2% KCL AT 120 DEG. - FOLLOWED BY 250 BBL 2% KCL WITH CORROSION INHIBITOR AT 120 DEG. - CIRCULATE 4.1 BPM AT 420 PSI. Printed 8/27/2012 10:56:50AM ,: . , � Common Well Name: MPS - 35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 09:30 2.50 RUNCOM P RUNCMP SET PACKER. DROP BALL AND ROD AND PUMP DOWN AT 3.OBPM AT 160 PSI. -BALL ON BBL. SET PACKER W/ AT 2800 20.1 PSI. PRESSURE TEST SEAT TUBING TO 250 PSI LOW FOR 5 MINS AND 3500 PSI HIGH FOR 30 MINS CHARTED. -BLE O TUBING TO 1500 PSI. PRESSURE FF TEST IA TO 250 PSI LOW FOR 5 N}INS AND ED 3500 PSI HIGH 30 MINS - CHARTED. D. NOTIFY WTL OF SUCCESSFUL PACKER P -TEST SHEAR AND RECEIVE AUTHORIZTION TO BLEED OFF ' PRESSURES ON IAl AND TUBING AND PRESSURE DCK VALVE. UP IA TO 2200 PSI AND DCK SHEARED. - VERIFY DCK VALVE OPEN: GIRCULATE 5 BBLS DOWN TUBING WITH RETURNS. - CIRCULATE DOWN IA 5 BBLS WITH RETURNS. 09:30 - 11:30 2.00 RUNCOM P RUNCMP RIG DOWN LAAND CROSSOVER. -RIG UP DRY ROD AND NDING INSTALL TWC. -TEST FROM ABOVE 250 JOINT PSI LOW 3500 PSI FOR 5 51\ M - ATED -TEST HIGH FRO BELOW 250 PSI LOW 3500 PSI HIGH FOR MINS - C HARRTED. . 11:30 - 12:00 0.50 RUNCOM P RUNCMP RIG DOWN TEST EQUIPMENT. -BLOW DOWN LINES. 12:00 - 14:00 2.00 BOPSUR P RUNCMP PJSM RIG UP TO TEST 2 7/8 INCH X 5 INCH VBRS. - VACCUUM OUT STACK. -PICK UP TEST JOINT AND FOSV. -0 PSI ON KOOMEY. -M -LAY DOWN TES T JOIN FAILED. FOSV. NNING TOOLS AND `SIM OP: DEMOB TUBING RU AND PL EQUPMENT. TEST ON 14:00 - 15:30 1.50 RUNCOM P RUNCMP G DOWN TU RUNNING TOOLS. CLEAN CROSSOVERS. -RIG RI DOWN SAFTEY BING JOINT FROM PIPE SHED. -DEMOB TUBING RUNNING TOOLS AND EQUPMENT. 15:30 21:30 6.00 BOPSUR P RUNCMP PJSM ON RE RAM OPERATION. - REMOVE OLD TREE FROM BLOCKS R CELL A. FROM - REMOVE (3) SET MOVING S OF RAM BLOCKS THE STACK. OP: A T ON THE FR AND INSPECT. CLE SIM SIM OP: DEMOB N ROTARY OOLS TOOLS FROM RIG LOO RIG FLOOR. Printed 8/27/2012 10:56:50AM N orth America - ; O Pe ration Summa R • Common Well Name: MPS -35 AFE No Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 00:00 2.50 BOPSUR P RUNCMP PJSM NIPPLE DOWN BOPE STACK OPERATION. -BLOW DOWN CHOKE/KILL LINES. -BLOW DOWN HOLE FILL AND BLEEDER LINES. -CLEAN POLLUTION PAN AND MASTER BUSHING. -BLOW DOWN PUMPS. EMPTY PITS AND PREP TO CLEAN. -REMOVE KOOMEY LINES FROM STACK AND VACUUM OUT OUT BOP STACK. "FLUID LOST FOR 24 HOURS: 173 BBL. "OA PRESSURE: 150 PSI. "BARRIERS: TUBING: BALL AND ROD, TWC KWF. IA: TESTED PACKER, TUBING HANGER, KWF. 8/15/2012 00:00 - 03:00 3.00 BOPSUR P RUNCMP PJSM ON NIPPLE DOWN BOPE OPERATION. - NIPPLE DOWN FLOW LINE. -NIPPLE PLE DOWN BOPE. -L/FT STACK AND SET ON STUMP. - " SIM OP: EMPTY AND CLEAN PITS. 03:00 - 05:30 2.50 WHSUR P RUNCMP :NIPPLE UP TUBING HEAD ADAPTER FLANGE. -FMC 11" 5K X 4-1/16" 5K ADAPTER FLANGE. - THREAD I -LINE THROUGH ADAPTER. -TEST I -LINE: CONTINUITY OK. L -GAGE: 1692 PSI AND U -GAGE: 1690 PSI. TEMP: 70.5 DEG. - TERMINATE I -LINE. -TEST TUBING HANGER VOID AND SEALS TO 5000 PSI FOR 30 MINUTES - CHARTED BY FMC. 05:30 - 08:30 3.00 WHSUR P RUNCMP NIPPLE UP TREE ON ADAPTER FLANGE. -FMC 4- 1/16" TREE, -TEST TO 5000 PSI FOR 5 MINUTES AND CHARTED. 08:30 - 11:00 2.50 WHSUR P RUNCMP RIG UP LUBRICATOR. -TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES AND CHARTED. PULL TWC AND VERIFY PRESSURE 0 PSI ON TUBING. -RIG DOWN LUBRICATOR. 11:00 - 16:30 5.50 WHSUR P RUNCMP PJSM ON FREEZE PROTECT OPERATION WITH LITTLE RED. - RIG UP TO WELL HEAD FOR FREEZE PROTECTION. - PRESSURE TEST LINES TO 4000 PSI. - REVERSE CIRUCLATE DOWN IA WITH 85 BBLS DIESEL. -FCP 3 BPM AT TO 900 PSI. - EQUALIZE TUBING AND IA AND ALLOW TO U -TUBE FOR 1 HOUR. 16:30 - 18:00 1.50 WHSUR P RUNCMP PJSM RIG UP LUBRICATOR OPERATION. -RIG UP LUBRICATOR. -TEST TO 250 LOW AND 3500 PSI HIGH FOR 5 MINUTES AND CHARTED. -SET BPV THROUGH LUBRICATOR. - PSI FOR 10 MINUTES AND CHARTED. -BLEED PRESSURE AND SUCTION LINES BACK WITH LITTLE RED. -RIG DOWN LUBRICATOR, CIRCULATION LINES, T'S, HOSES AND VALVES. Printed 8/27/2012 10:56:50AM AF No Common Well Name: MPS -35 Event Type: WORKOVER (WO) Start Date: 8/3/2012 End Date: 8/15/2012 X4- 00WFD -E: (2,200,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 9/7/2003 12:00:00AM R UWI Rig elease: 8/16/2012 Rig Contractor: DOYON DRILLING INC. : Active Datum: ORIG KELLY BUSHING @71.68ft (above Mean Sea Date From - To Hrs Task Code NPT Level) NPT Depth Phase Description AND C of Operations (hr) (ft ) 18:00 - 21:00 3.00 WHSUR P RUNCMP SEL LAR. REMOVE ECURE WELL DOUBLE VALV FROM IA AND INSTALL MOVE 1502 1502 FLANGE FLANGE WITH FROM W GUAGE. ING VALVE. - INSTALL BLANK FLANGE WITH GUAGE ON WING. -WELL SECURE. "OA PRESSURE: 120 PSI. * IA PRESSURE: 0 PSI. "TUBING PRESSURE: 50 PSI. 21:00 00:00 3.00 WHSUR P RUNCMP PJSM CLEAN AND CLEAR RIG FLOOR. -EMP LEAR RIG FLOOR, CO TY AND CLEAN PITS, CONT. -CLEAN AND CNT. Printed 8/27/2012 10:56:50AM I Tree: 4- 1/16" - 5M CIW MPS -35 OF elev. = 71.68' (Doyon 14) Wellhead• 11" x 4.5" 5M Ge O L. elev.= 37.90' (Doyon 14) w/ 4.5" TC -II T &B Tubing Hanger 4" CIW "H" BPV profile Csg test to 3500 psi Q9546' on 8/17/12 f 20" x 34" insulated, 215 #/ft A -53 112' 2` Blast rings below tubing hanger SLB 4.5" x 1" KGB -2 GLM 2066` 10 3/4" 45.5 #/ft L -80 BTC 5,816' , k. ■ KOP @ 304' Hole angle passes 70 degrees @ 2600' Max angle in tubing = 77 degree 71 degrees at sliding sleeve (` TVD) Min. ID through tubing 3813" @ 9469' & 9578' Min. ID through XN 3.725" @ 9647' 7 5/8" 29.7# L -80 BTC -M casing (drift ID = 6.75 ", cap = .0262 BPF w/ Tbg inside) 4.5" 12.6# 13CR -85 VAM, IBT & TC -II tubing (ID = 3.958 ", cap = .0152 BPF) SLB Multi -drop Sapphire Gauge (3.958" ID) 1 9457` I "Reverse C rculation' Jet Pump Confguration SGM - NDPG - CA Pfuau..e r 4.5" HES "XD" Dura sliding sleeve I 9469' I 8- ■ � i I t, 0 . 3.813" ID (Opens down ) a a : G a II I a SLB Multi -drop Sapphire Gauge (3.958" ID) 1 9479 I R, ' SGM - NDPG -CA I 1_, d ...I '\� r' + 7 5/8" x 4.5" HES TNT Pkr (3.856" ID) 9546' 4.5" HES X- Nipple (3.813" Pkg bore) 1 9578` Re oirFivia 4.5" HES XN Nipple (3.813" x 3.725" No Go) I 9647' WLEG 10655' Baker Tie Back Sleeve 10,650' Baker ZXP Liner Top Packer 10,657' Baker 7 5/8" x 5 1/2" HMC Lnr Hgr 10,663' A 7 5/8" HES Float Collar 10,663' 6 1/8" Hole td @ 14,804' ( 4110` TVD ) 7 5/8" HES Float Shoe 10,751' A N Lateral 104 jts 4 ", 9.5 # /ft. Screened Liner & Blanks \\ L -80 IBT (10,650' - 14,757') Dbl valve Baker 4 1/2" float Shoe 14,804' DATE REV. BY COMMENTS MILNE POINT UNIT 09/27/03 MDO Drilled and completed by Doyon 14 WELL S-35 08/15/12 Hulme Recompleted by Doyon 14 API NO: 50- 029 - 23175 -00 BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S : D FF E3 ,d, 4 201? Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3,03 .- (L4 3 333 West 7 Avenue Anchorage, Alaska 99501 r1 r ►6 ps- Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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) MPS -Pad 10111/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS-18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 , Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 , 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS -32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 ----> MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 • • - ,-.~. -- - MICROFILMED 03!01 /2008 DO NOT PLACE ~~.. ~.-. , ANY NEW MATERIAL ,UNDER THIS PAGE F: \LaserFiche\CvrPgs_InsertslMicrofilm_Marker. doc e e éJ03- / L/3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 May 1, 2006 RE: MWD Formation Evaluation Logs MPS-35, PB 1 & PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-35 + PBl + PB2: LAS Data & Digital Log Images: 50-029-23175-00, 70 & 71 1 CD Rom Ä~Ö~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031430 Well Name/No. MILNE PT UNIT SB S-35 Operator BP EXPLORATION (ALASKA) INC .Jp~J 7 ~~J API No. 50-029-23175-00-00 MD 14804 /' TVD 4111 -" Completion Date 9/26/2003 /" Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional S~ ._-^.~._---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, GYRO, PWD, IFRlCASANDRA, ABI, RES Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint --.---"-'-.'.----- Interval OH / Start Stop CH . Received Comments Rpt Directional Survey 12584 14804 10/10/2003 2 reports 1 is MWD i Rpt Directional Survey 11284 13550 1 0/1 0/2003 PB1 - 2 reports, 1 is MWD Rpt Directional Survey 0 11617 10/10/2003 PB2 - 2 reports, 1 is MWD í:::"D Las 12289 Induction/Resistivity 68 14749 Open 12/8/2003 I r"¡~~t¡'¿"'/R.$'i i'itivity J 6a- 1'f74~ Op~n P/8/?M3 ....ED D ~ 12289 Rate of Penetration 68 14749 Open 12/8/2003 Rpt L. t ) Roate of ["\(.I't{.tl"ð~on \ ,V'~ \ ~~ '^~ \,.i -"- 68 14749 Open 12/8/2003 tD D ~ 12290 Induction/Resistivity 68 11562 Open 12/8/2003 PB1 vi :R~t ~lC: u otic ",I[Œ" :;!Ivlty 'J'\f\ ~~v1:._ L ~r ) t,\,,) 68 11562 Open 12/8/2003 PB1 D I.oes" 12290 Rate of Penetration 68 11562 Open 12/8/2003 PB1 ~ ~~to of IìonGtr<>ti"'Q. Eo!2 118~;¡¡ Of.¡g,n 1 ? /R/?Ol)J D~1 . /~~I D L~ 12291 Induction/Resistivity . 68 13495 Open 12/8/2003 PB2 IrW~~tj.ç¡~c!;!tivily' \J'\V"~ "Jl ~ _ L ,\ J}.r f\.~ 68 13495 Open 12/8/2003 PB2 D L..,(" 12291 Rate of Penetration 68 13495 Open 12/8/2003 PB2 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2031430 MD 14804 TVD 4111 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Y / '4 Analysis Received? ~ -.- Comments: --~.'-'- -~_._-~. Compliance Reviewed By: _ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Well Name/No. MILNE PT UNIT SB 5-35 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23175-00-00 Cómpletion Date 9/26/2003 Completion Status 1-01L Daily History Received? Formation Tops ~ Current Status 1-01L ~N ~N Date: UIC N ~- );( þa..~a.ð1o~- . . . . ~ú3- I ~13 WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 04, 2004 RE: MWD Formation Evaluation Logs MPS-35, AK-MW-2651972 1 LIS formatted Disc with verification listing. API#: 50-029-23175-00 J B d å 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed:~e\~j;:0~,~~ RECEIVED DEC 08 2003 Al88ka 0Iì &Gt$ G<m.~, GooIro.n An~ ~~Ä\'-\"~ . . ~C,3-~}ß WELL LOG TRANSMlTfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2003 RE: MWD Formation Evaluation Logs MPS-35 PBl, AK-MW-2651972 1 LIS formatted Disc with verification listing. PùPI#: 50-029-23175-70 )/JfJ 90 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed~C:~:-l IV'-.. ~~~:;,,,"'- RECEI\lED DEC 08 2003 .Alaska Oil & (¡~þ Ç\:;n~. G9rr~"O~rt AnCltmege ~~~\~~0 . . /703 r JJ-J3 WELL WG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2003 RE: MWD Formation Evaluation Logs MPS-35 PB2, AK-MW-2651972 1 LIS formatted Disc with verification listing. llPI#: 50~29-23175-71 1()è9Cì I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~'-~ ,~Q(~~ RECEIVED DEe 08 2003 Alaska Oi¡ & OJfHii. Commi8ðron Ançt¡Gf~"e ~~~\'0\.~ '\ . STATEOFALASKA . ALASKÄ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GR , GYRO, PWD , IFR/CASANDRA , ABI , RES CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BotToM SIZE 35' 110' 42" 34' 5816' 13-1/2" 910 sxArctic Set Light, 275sx Class 'G' 32' 10751' 9-7/8" 750 sx Class 'G' 10650' 14804' 6-1/8" Sand Screen Liner o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3248' NSL, 427' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2241' NSL, 2802' WEL, SEC. 02, T12N, R10E, UM Total Depth: (~fJ ~ 42' NSL, 185' WEL, SEC. 34, TftN, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565584' y- 5999913' Zone- ASP4 TPI: x- 557892 y- 6004123 Zone- ASP4 Total Depth: x- 560487 y- 6007224 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. 20" 10-3/4" 7-5/8" 92# 45.5# 29.7# H-40 L-80 L-80 L-80 5" x4" 15.5# x 9.5# 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 4", 9.5#, L-80 Sand Screens MD TVD MD TVD 10761' - 14757' 4090' - 4111' One Other 5. Date Comp., Susp., or Aband. 9/26/2003 - 6. Date Spudded 9/7/2003 . 7. Date ToO. Reached 9/22/2003 . 8. Elevation in feet (indicate KB, DF, etc.) KBE = 71.68' 9. Plug Back Depth (MD+ TVD) 14804 + 4111 Ft 10. Total Depth (MD+TVD) 14804· + 4111' Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 260 sx Arctic Set (Approx.) 24. SIZE 4-1/2" x 3-1/2-,12.6# x 9.2#, L-80 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-143 13. API Number 50- 029-23175-00-00 14. Well Number MPS-35 15. Field and Pool Milne Point Unit / Schrader Bluff 16. Lease Designation and Serial No. ADL 025639 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PUllED DEPTH SET (MD) 9688' PACKER SET (MD) 9631' 25. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 84 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Oll-Bsl GAs-McF 2359 129 26. Date First Production: October 14, 2003 Date of Test Hours Tested PRODUCTION FOR 10/14/2003 6 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE"" 27. CORE DATA' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atÌ~~èpa~ ¿tlleèt;, ~.necessary). Submit core chips; if none, state "none". rif¡;;~::-:---; n I J""·!c'wn ':, DATE ; None J flt '<'23: l~~:~-¡ O~~IGINAL OIL-Bsl Form 10-407 Revised 2/2003 W A TER-Bsl o GAs-MCF WATER-Bsl CONTINUED ON REVERSE SIDE RBDMS BfL OCT 2 8 2003 toV I GAS-OIL RATIO 55 OIL GRAVITY-API (CORR) CHOKE SIZE SBF21 GEOLOGIC MARKER. NAME MD TVD 10286' 4031' 10359' 4040' 10653' 4077' 10700' 4083' 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28;. SBF2-NA None SBF24-MF SBF1-NB ~. 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra S~-JY~.LG..,,-.__Title Technical Assistant Date I 0 - Z~ 'O_~ MPS-35 203-143 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Matt Green, 564-5581 Permit No.1 Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 . . BP EXPLORATION Operations Summary Report Page 1 of 7 Legal Well Name: MPS-35 Common Well Name: MPS-35 Spud Date: 9/7/2003 Event Name: DRILL +COMPLETE Start: 9/7/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 9/26/2003 Rig Name: DOYON 14 Rig Number: , Date From ~ To Hours Task !Code NPT Phase .. ..Description of Operations· .. . .... -----..--...---.. 9/6/2003 18:00 - 19:00 1.00 MOB P PRE Skid rig floor from drlg position to move position 19:00 - 20:30 1.50 MOB P PRE Move rig off S-14 and onto S-35 - shim rig 20:30 - 21 :30 1.00 MOB P PRE Skid rig floor from move position to drlg position 21 :30 - 22:00 0.50 RIGU P PRE Rig up floor - perpare pits to take on water 22:00 - 23:00 1.00 RIGU P PRE Accept rig 22:00 hrs 9/6/2003 - Nipple up Divertor - Take on water for mixing spud mud 23:00 - 23:30 0.50 RIGU P PRE Load pipe shed with 4" Drill pipe 23:30 - 00:00 0.50 DRILL P SURF Pick up 4" drill pipe from pipe shed and stand back in derrick 9/7/2003 00:00 - 05:00 5.00 DRILL P SURF Pick up 201 joints 4" drill pipe - Standing back in derrick - Mixing spud mud 05:00 - 06:00 1.00 DRILL P SURF Cut drlg line - Service top drive 06:00 - 07:00 1.00 DRILL P SURF Pick up 17 joints of HWDP - Jars - Flex De's 07:00 - 09:30 2.50 DRILL P SURF Handle BHA - Make UP bit - motor - MWD - orient same - Can't MU BHA 09:30 - 10:00 0.50 DRILL P SURF Rig up gyro survey equipment - function test divertor - accumulator test 10:00 - 10:30 0.50 DRILL P SURF Pre-spud meeting - fill stack - check for surface leaks - test mud line to 3000 psi 10:30 - 14:30 4.00 DRILL P SURF Directional drill from 112' to 360' - WOB 40K to 45K - RPM 80- TQ on 1 K - off 1 K - GPM 423 - PP 1200 - off 1040 - PU 85K - SO 65K - Rot 65K 14:30 - 15:30 1.00 DRILL N SFAL SURF Drag chain skipped sproket in cuttings trough - Repair same 15:30 - 00:00 8.50 DRILL P SURF Directional Drill from 360' to 1197' - WOB 40K - 45K - RPM 80 - TQ on 6K - off 2K - GPM 423 - PP on 1470 - off 1140 - PU 1 05K - SO 95K - ROT 1 05K - (total of three gyro surveys ran) 9/8/2003 00:00 - 11 :00 11.00 DRILL P SURF Directional Drill from 1197' to 2446' - WOB 35K - RPM 80 - TQ on 8K - off 5K - GPM 465 - PP on 2200 - off 1710 - PU 115K - SO 85K - Rot 95K 11 :00 - 12:00 1.00 DRILL P SURF Clay balls plugged flow line - clean out same 12:00 - 15:00 3.00 DRILL P SURF Directional drill from 2446' to 3021' - WOB 35K to 40K - RPM 80 - TQ on 9K - off 5K - GPM 486 - PP on 2540 - off 2240 - PU 1 03K - SO 75K - ROT 90K 15:00 - 17:30 2.50 DRILL P SURF CBU 3 X - 15,000 strokes - GPM 486 - PP 2240 - RPM 80 - TQ 5K - PU 105K - SO 75k - ROT 93K 17:30 - 19:30 2.00 DRILL P SURF Pump out to HWDP from 3021' to 816' - Pump at full drilling rate - Hole in good condition - No problems 19:30 - 20:30 1.00 DRILL P SURF RIH from 816' to 3021' - No problems - hole in good shape 20:30 - 00:00 3.50 DRILL P SURF Directional Drill from 3021' to 3694' 9/9/2003 00:00 - 14:00 14.00 DRILL P SURF Directional Drill from 3694' to 5820' - T.D. 131/2" - WOB 35K- RPM 80 - TQ on 12K - off 8K - GPM 508 - PP On 3450 - off 3180 - PU 135K - SO 68K - ROT 96K 14:00 - 20:00 6.00 DRILL P SURF CBU 3 X - 30,000 strokes - GPM 550 - PP 3500 - RPM 100- TQ 8K - PU 135K - SO 68K - ROT 96K (120 spm 1st 15K strokes 130 spm the last 15K strokes) 20:00 - 00:00 4.00 DRILL P SURF Pump out to HWT from 5820' to 1350' - Pump out at drilling rate - tight spot, slight packing off @ 4430' work through section 4420' to 4440' - Con't pump out hole 9/10/2003 00:00 - 01 :00 1.00 CASE P SURF Pump out to HWT - from 1350' to 816' - 100 spm @ 11 OOpsi 01 :00 - 03:00 2.00 CASE P SURF RIH filling every 25 stands - Hole in good shape no problems 03:00 - 06:30 3.50 CASE P SURF CBU 3 X - 30,000 strokes - GPM 550 - PP 3700 - RPM 100- TQ 9.5K - PU 135k - SO 70k - ROT 100k 06:30 - 11 :00 4.50 CASE P SURF Pump out from 5824' to HWT 816' at full drlg rate 11 :00 - 13:00 2.00 CASE P SURF Stand back HWT - Flex dc's - jars - LD 8" BHA Printed: 9/2912003 9:03:35 AM .... A BP EXPLORATION Operation~ Summ:ary.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-35 MPS-35 DRI LL +COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To Houts: Task Code NPT Phase 9/10/2003 13:00 - 13:30 13:30 - 15:00 15:00 - 21 :00 0.50 CASE P 1.50 CASE P 6.00 CASE P SURF SURF SURF 21 :00 - 21 :30 0.50 CASE P 21 :30 - 00:00 2.50 CASE P 9/11/2003 00:00 - 02:30 2.50 CEMT P SURF SURF SURF 02:30 - 03:30 1.00 CEMT P SURF 03:30 - 05:00 1.50 CASE P SURF 05:00 - 06:00 1.00 CASE P SURF 06:00 - 06:30 0.50 CASE P SURF 06:30 - 08:00 1.50 CASE P SURF 08:00 - 08:30 0.50 CASE N RREP SURF 08:30 - 09:30 1.00 CASE P SURF 09:30 - 13:00 3.50 CASE P SURF 13:00 - 13:30 0.50 CASE P SURF 13:30 - 14:00 0.50 CASE P SURF 14:00 - 15:00 1.00 CASE P SURF 15:00 - 15:30 0.50 CASE P SURF 15:30 - 17:30 2.00 CASE P SURF Page 2 of 7 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: Spud Date: 9/7/2003 End: Description of Operations Clear rig floor of all unnecessary tools Rig up casg tools Run 140 joints of 10 3/4" L-80 BTC-M 45.5# casing - Make up hanger - landing joint - land casing - string weight on slack off 100K Lay down Franks fill up tool - Make up Schlumberger Cementing head - cementing lines Break circulation @ 2 bpm 300 psi - stage up pump to 10 bpm 540 psi - Circ 2 casg volume 11700 strokes PJSM - Schlumberger pump 10 bbls water - Test lines to 3500 psi - Pump 40 bbls water - (drop bottom plug last 5 bbls water pumped on the fly) - Mix and pump 910 sxs Type "ASL" (Artie Set Light) - Yield 4.28 cf/sx - 693 bbls slurry mixed at 10.7 ppg - (two gallons dye in first 5 bbls slurry pumped) - Pumped at 7 bpm 700 psi - Mix and pump Tail 275 sxs Class "G" cement with .5% S-001 Accelaerator + .4% D-167 Fluid loss + .3% D-065 Dispersant + .2% D-046 Antifoam - Yield 1.16 cf/sx - 56 bbls slurry - mixed at 15.8 ppg - (pumped at 6 bpm - 1100 psi) - Drop top plug - Kick out top plug with Schlumberger 30 bbls @ 7 bpm 500 psi - Turn to rig - Rig displaced 516 bbls of mud - 9 bpm 600 psi- Slow to 4 bpm at 500 bbls pumped - Bump plug at 546 bbls (total bbls) pumped at 1600 psi 1000 psi over pumping pressure - Held floats for 3 mins - bleed off pressure - floats holding - CIP 03:43 hrs - Cement to surface with 1870 strokes pumped (186 bbls + 30 bbls Schlumberger = 216 bbls) on displacement - 330 bbls cement to surface Flush Divertor - Riser - Flow line with water - Lay down Schlumberger cementing head - Back out landing joint - Lay down landing joint Nipple down riser - Annular divertor - knife valve Nipple up FMC 12" m X 12" m seal casg head - FMC 11" x 11" Tubing head - Test to 1000 psi for 10 mins Nipple up BOP's Repair rotating shot pin assembly on T.D. Set wear ring - Open annulus valves - Rig up testing equipment Test BOP's - Test Annular to 250 low and 3500 high 5 mins each test - Test Top rams - bottom rams - blind rams - choke manifold - Hyd choke / kill valves - Manual choke / kill valves - Upper /Iower IOBP valves - Floor safety valves - Accumulator test - 1 failure - choke line connection leaked - tightened and retested ok - Mr Jeff Jones with AOGCC witnessed the testing of BOP's Rig down testing equipment - Close annulus valves - Pull test plug - install wear ring Pull short bha up to rig floor Make up bit - motor - mwd - orient - Con't make up bha -(Logging tools GR, RES, PWD, DM) RIH with HWT and surface test MWD @ 726' gpm 393 @ 970 psi Con't RIH - from 726' to 5618' - Break circ Printed: 9/29/2003 9:03:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/11/2003 9/12/2003 9/13/2003 9/14/2003 9/15/2003 . . . Page.3 of 7 BP EXPLORATION Op'erati,ottS Summary Report MPS-35 MPS-35 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: Spud Date: 9/7/2003 End: From -To Hours! Task Code NPT I Phase 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 20:00 20:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 03:30 03:30 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 15:00 15:00 - 17:30 17:30 - 18:30 18:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 1.00 CASE P 1.50 DRILL P 1.50 CASE P 0.50 CASE P 2.00 DRILL P 20.00 DRILL P 3.00 DRILL P 1.00 DRILL P 2.00 DRILL P 1.50 DRILL P 1.00 DRILL P 2.00 DRILL P 1.00 DRILL P 2.00 DRILL P 1.00 DRILL P 1.00 DRILL P 0.50 DRILL P 12.00 DRILL P 12.00 DRILL P 3.00 CASE P 2.50 CASE P 1.00 CASE P 4.50 CASE P 1.00 CASE P 1.00 CASE P 0.50 CASE P SURF SURF SURF SURF INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Description of OperatiOns ___0___··_'"-- _~___ Test casing to 2500 psi for 30 mins - record on chart Drill float collar 5729' - Float shoe 5816' - 20 feet new hole from 5824' to 5844' - 393 GPM - 2380 PP - 60 RPM - 1 OK TQ - WOB 20K Displace well with 8.9 - 59 vis - LSND mud - 393 GPM - 1550 psi 60 RPM - TQ 9K FIT - M.D. 5816' - TVD 2903' - Mud weight 8.9 - Surface pressure 420 psi = EMW 11.68 Directional drill from 5844' to 5880' - WOB 35K - RPM 120 - TQ on 8K - off 10K - GPM 100 - PP 2120 on - off 1900 - PU 135K- SO 65K - ROT 90K - Problems trying to slide - Raising lubricant to 3% to 5% - Adding EP Bit Lube to system to help with casing friction Directional Drill from 5880' to 8758' - (Sproradic clay balls from 6000' to 6300' - Plugging shaker box) - WOB 15K to 45K - RPM 120 - TQ on 10K - off 9K - GPM 440 - PP on 3500- off 3350 - PU 140K - SO 75K- ROT 106K CBU 3 X - 21,000 stks - RPM 120 - TQ 9K - GPM 500 - PP 3600 Pump out from 8758' to 7612' at drlg rate Pump out from 7612' to 5785' at drilling rate - Hole in good shape - Monitor well - well static - pump dry job - blow down kelly Can't POH from 5785' to 726' Stand back HWT - Flex dc's - Break off bit - Change motor setting from 1.22 to 1.5 Down load MWD - Change out DM collar - Pulsor - Up load MWD Make up bit - RIH with flex dc's - HWT - change out to 4" handling tools RIH from 726' to 5809' - filling dp @ 3125' - 5809' Cut drilling line - Service top drive RIH from 5809' to 8692' - fill dp @ 7540' Wash last stand to bottom 8692' to 8758' Directional Drill from 8758' to 10,000' - WOB 30K to 40K - RPM 80 - TQ on 11 K - off 8K - GPM 423 - PP on 3250 - off 3070 - PU 150K - SO 70K - ROT 11 OK - Start Azim turn @ 9003' from 293 degree to 330 at present - Start angle build @ 9003' 74 degree to 80 degree at present. Directional Drill from 10,000' to 10,760' - TD 9 7/8" HOLE- WOB 35K - RPM 80 - TQ on 12K - off 7K - GPM 440 - PP on 3430 - off 3150 - PU 145K - SO 75K - ROT 108 CBU 2 X - 18,000 strokes - RPM 100 - TQ 8K - GPM 468 - PP 3200 - PU 145K - SO 75K - ROT 105K Pump out from 10,760' to 8000' @ drillig rate - Hole in good shape RIH from 8000' to 10760' - No problems CBU 3 X - 27000 strokes - GPM 440 - PP 3150 - RPM 100- TQ 10K Pump out @ drilling rate from 10760' to 9176' Pump out from 9176' to 8500' - Full drlg rate 430 gpm - 2730 psi Flow check well - well static - Pump dry job Printed: 9/29/2003 9:03:35 AM ..., A BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: MPS-35 Common Well Name: MPS-35 Spud Date: 9/7/2003 Event Name: DRILL +COMPLETE Start: 9/7/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 9/26/2003 Rig Name: DOYON 14 Rig Number: I .. Date I From - To Hours Task Code NPT Phase Description of Ope rations .._--_.~----.._..- ._-_._~ .--...-"---.- 9/15/2003 01 :30 - 02:30 1.00 CASE P INT1 POH from 8500' to 5809' without pump - hole good - flow check well - well static 02:30 - 04:30 2.00 CASE P INT1 RIH from 5809' to 10760' - filling pipe @ 8212' 04:30 - 08:30 4.00 CASE P INT1 CBU 3 X - 27,000 strokes - GPM 483 - PP 3800 - RPM 100- TQ 9K - Flow check well - well static - pump dry job 08:30 - 13:00 4.50 CASE P INT1 POH from 10760' - to 726' - flow check well @ 5809' - well static 13:00 - 15:00 2.00 CASE P INT1 Stand back one stand HWT - Lay down BHA 15:00 - 16:00 1.00 CASE P INT1 Pull wear ring - Install test plug - change rams to 7 5/8" casing rams - body test to 1500 psi 16:00 - 17:00 1.00 CASE P INT1 Rig up 7 5/8" casing equipment 17:00 - 23:00 6.00 CASE P INT1 Run 133 joints - 7 5/8" 29# L-80 BTC-M casing to 5792' 23:00 - 00:00 1.00 CASE P INT1 Circulate one casing volume - 266 bbls @ 6 bpm - 260 psi - PU 140K SO 95K 9/16/2003 00:00 - 01 :00 1.00 CASE P INT1 PJSM - Con't running 7 5/8" L-80 - BTC-m 29.7# casing from 5792' to 6646" 01 :00 - 02:00 1.00 CASE N SFAL INT1 Casing spiders hung up on top of casing collar damaging hose on Franks fill up tool - Remove hose 02:00 - 03:30 1.50 CASE P INT1 Con't running 7 5/8" casing from 6646' to 8107' filling pipe casing every 10 joints with cement hose 03:30 - 04:00 0.50 CASE N SFAL INT1 Make up hose on Franks fill up tool 04:00 - 06:00 2.00 CASE P INT1 Con't running 7 5/8" casing from 8107' to 10714' - Make up landing joint - hanger - RIH land casing @ 10750' shoe @ 10750, float @ 10663, Total jts run 253 jts 10713 ft. 06:00 - 07:00 1.00 CASE P INT1 Rig down franks tool, rig up cementing head 07:00 - 10:00 3.00 CASE P INT1 Circ two csg volumes 6 bbls min. 600 psi, PJSM on cementing 10:00 - 12:00 2.00 CEMT P INT1 Cement w/ Schlumberger with 5 bbls water, test lines to 3500psi, 5 bbls water,35 bbls mudpush 11 mixed @ 10.2, drop bottom plug, cement with 750 sxs. Class G, 161.6 bbls mixed @ 15.8, drop top plug with 20 bbls water, displace with rig pumps 6.5 bbls min. 9.2 mud, bump plug with 1000 psi over final eire, pressure of 800 psi total 1800 psi, full return tru out job, float held 12:00 - 12:30 0.50 CEMT P INT1 Rig down, Cement head, flush BOP stack 12:30 -13:00 0.50 CEMT P INT1 Ud landing jt. and change bails 13:00 -14:00 1.00 CASE P INT1 Install 10 3/4 x 7 5/8 packoff, test to 5000 psi 14:00 - 15:00 1.00 CASE P INT1 Change rams to 2 7/8 x 5 15:00 -18:00 3.00 CASE P INT1 Install wear ring, picking up 138 jts 4" dp from pipe shed 18:00 - 18:30 0.50 CASE P INT1 Circ to remove scale from pipe 18:30 - 20:00 1.50 CASE P INT1 Tripping out with drill pipe and stand in derrick 20:00 - 00:00 4.00 CASE P INT1 PJSM, Pull wear ring, rig up and test BOPS and manifold with 250-3,500 psi 5 min. per test, Annular 250-2500 psi 5 min. per test, install wear ring,The right to witness test was wavier by Jeff Jones AOGCC 9/17/2003 00:00 - 01 :00 1.00 CASE P INT1 Housekeeping, pickup tools,and clean up rig 01 :00 - 03:30 2.50 CASE P INT1 PJSM, Picking up BHA # 46.125 FM3641with 6 -10 jets, 4 3/4 Sperrydrill with 1.5 bend,float sub, 4 3/4 DGR & EWR, 4 3/4 DM HOC/PWD 4 3/4 TM HOC,3 flex dc,jars,xo 03:30 - 07:00 3.50 CASE P INT1 Tripping in to 10583' 07:00 - 08:00 1.00 CASE P INT1 PJSM, Cut and slip drill line 08:00 - 09:30 1.50 CASE P INT1 PJSM, Change out saver sub on top drive 09:30 - 10:30 1.00 CASE P INT1 Test csg to 3,500psi for 30 min. good test 10:30 - 11 :30 1.00 CEMT P INT1 Drill float and shoe, drill pipe depth on float 10671 shoe 10758', Printed: 9/29/2003 9:03:35 AM .... -- Page 5 of 7 BP EXPLORATION Operations Summary;Re'port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-35 MPS-35 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date Ærom- To Hours Task Code NPT I Phase _...._..... ··.'_n_."_..____... ..... 9/17/2003 10:30 - 11 :30 1.00 CEMT P 11 :30 - 13:30 2.00 DRILL P 13:30 -14:00 0.50 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 00:00 9.50 DRILL P 00:00 - 04:00 4.00 DRILL P 04:00 - 04:30 0.50 DRILL N 04:30 - 05:00 0.50 DRILL N 05:00 - 06:00 1.00 DRILL N 06:00 - 00:00 18.00 DRILL P 00:00 - 04:00 4.00 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 06:30 2.00 DRILL P 06:30 - 16:00 9.50 DRILL P 16:00 - 19:00 3.00 DRILL P 19:00 - 23:00 4.00 DRILL P 23:00 - 00:00 1.00 DRILL N 00:00 - 00:30 0.50 DRILL N 00:30 - 01 :30 1.00 DRILL N 01 :30 - 02:30 1.00 DRILL N 02:30 - 13:30 11.00 DRILL P 13:30 -14:00 0.50 DRILL P 14:00 - 17:00 3.00 DRILL P 17:00 -19:00 2.00 DRILL P 19:00 - 00:00 5.00 DRILL P 00:00 - 11 :00 11.00 DRILL P 9/18/2003 9/19/2003 9/20/2003 9/21/2003 11:00-13:00 2.00 DRILL P 13:00 - 00:00 11.00 DRILL P 9/22/2003 00:00 - 00:30 0.50 DRILL P INT1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: Spud Date: 9/7/2003 End: Description.of Operations. drill new hole 10,760 to 10,775 Displace well with 9.2 Flow-pro mud 250 gals min 2000 psi with 80 rpms 7,000 Torq. Dirctional drill, 10,775 to 10780, circ for ten min. FIT with 9.2 mud, TVD 4,088, Pressure 500 psi= EMW 11.5 Directional drill, 10,780 to 11326' with 250 gals min. 80 rpms, 2400 psi AST 6.42, ART 1.33, TQ 7000 Directional drill, 11326' to 11,617' with 250 gals min. 80 rpms, 2500 psi, Fault @ 11,425, drill out top @ 11,510 Circ for side track Pump out with full drill rate to 11,309' Side tracking well @ 11,326 Directional drill, 11326' to 12408' with 250 gals min. 80 rpms, 2900 psi, AST 5.66 ART 9.92, ECD 12.1 Directional drill, 12408' to 12601' with 250 gals min. 80 rpms, 2800 psi, Packoff and stuck, packoff reaming up,30 ft off bottom, worked free and got circ. slow, ECD was running 12.3 just before pack off Circ and rotate to clean up hole with 250 gals min. 95 rpms 2500 psi, ECD after circ. 12.1 Directional drill, 12601' to 13269' with 250 gals min. 80 rpms, 2800 psi, hole acting up, ECD 12.5 Circ and rotate three bottoms, to clean up hole with 250 gals min. 95 rpms 2500 psi (ECD got as high as 12.9) ECD after circ 12.1 Directional drill, 13,269' to 13,550 with 250 gals min. 80 rpms, 2800 psi ECD 12.5 Circ and rotate one bottoms, to clean up hole for side track, 250 gals min. 95 rpms 2500 psi ECD 12.4 Circ and rotate one bottoms, to clean up hole for side track, 250 gals min. 95 rpms 2500 psi POH with full drill rate to 12,600' Sidetracking well @ 12,602' Directional drill, 12602' to 13174' with 250 gals min. 80 rpms, 2700 psi, ECD Drilling 12.5 Circ. 250 gals min. 90 rpms Directional drill, 13,174' to 13,367' with 250 gals min. 80 rpms, 2800 psi, ECD Drilling 12.7 Circ and rotate two bottoms, to clean up hole, 250 gals min. 100 rpms 2500 psi ECD 12.1 Directional drill, 13,367' to 13,730 with 250 gals min. 80 rpms, 3000 psi, ECD 12.3, AST 4.75, ART 6.84 Directional drill, 13,730 to 14,101' with 250 gals min. 80 rpms, 3000 psi, Cross fault @ 13,700 dropping angle looking for sand., found sand @ 14,020', ECD 12.5 eire, two bottoms up with 100 rpms, 250 gals min, 2900 psi to clean up hole, final ECD 12.1 Directional drill, 14,101' to 14758' with 250 gals min. 80 rpms, 3200 psi ECD 12.6, AST 4.75 ART 8, TQ 9500 Directional drill, 14758' to 14,804' TD with 250 gals min. 80 rpms, 3200 psi ECD 12.6 Printed: 9/29/2003 9:03:35 AM ... .. BP EXPLORATION ... . Operati'ons Summary Report. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-35 MPS-35 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date , From - To Hours i Task Code NPT Phase , . . ."¥n·_v··, _..__.___._._"'__._..._._.__. Description of Qperations 9/22/2003 00:30 - 06:00 5.50 CLEAN P COMP 06:00 - 10:00 4.00 CLEAN P COMP 10:00 - 11 :30 1.50 CLEAN P COMP 11 :30 - 12:00 0.50 CLEAN P COMP 12:00 - 13:30 1.50 CLEAN P COMP 13:30 -14:00 0.50 CLEAN N RREP COMP 14:00 -17:00 3.00 CLEAN P COMP 17:00 - 18:00 1.00 CLEAN P COMP 18:00 - 00:00 6.00 CLEAN N RREP COMP 00:00 - 01 :30 1.50 CLEAN N RREP COMP 01 :30 - 05:30 4.00 CLEAN P COMP 9/23/2003 05:30 - 06:00 06:00 -10:00 10:00 -11 :30 0.50 CLEAN P 4.00 CLEAN P 1.50 CLEAN P COMP COMP COMP 11 :30 -13:00 1.50 CLEAN P COMP 13:00 -13:30 0.50 CLEAN P COMP 13:30 - 17:00 3.50 CLEAN P COMP 17:00 - 20:00 3.00 CLEAN P COMP 20:00 - 21 :30 1.50 CLEAN P COMP 21 :30 - 00:00 2.50 CLEAN P COMP 9/24/2003 00:00 - 01 :00 1.00 CLEAN P COMP 01 :00 - 03:00 2.00 CLEAN P COMP 03:00 - 06:30 3.50 CLEAN P COMP 06:30 - 08:00 1.50 CLEAN P COMP 08:00 - 12:00 4.00 CLEAN P COMP 12:00 - 18:00 6.00 CASE P COMP 18:00 - 20:30 2.50 CASE P COMP 20:30 - 22:00 1.50 CASE P COMP 22:00 - 23:30 1.50 CASE P COMP 23:30 - 00:00 0.50 CASE P COMP Page 6 Qf 7 Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: Spud Date: 9/7/2003 End: Circ. 5 bottoms up with 280 gals min. 2,950 psi, 100 rpms starting ECD 12.75, final ECD 12.6 Pumping out of hole to Csg shoe @ 10750, with full drilling rate, two tight spots, 14450 and 11,600 Circ. bottoms up from 10750' Monitor well Cut drilling line Attempt, repair accumulator 4 way valve, still leaking POH laydown BHA Pull wear ring, close blinds, monitor annulus pressure, remove top rams doors to replace ram seals. close blinds, monitor annulus pressure, remove top rams doors to replace ram seals. Test BOPS and Manifold to 250-3500 psi for 5 min per test, Hydril 250-2500 psi 5 min. per test, pull test plug, install wear ring The right to Witness the BOP test was wavier by Chuck Scheve AOGCC Pickup BHA # 5 Tripping in with hole opener to 11,154 hit tight spot Work and wash out tight spot @ 11,154, trip in with 3 stands tight @ 11421 wash and worked out spot @ 11,421 and 11,460' with 250 gals min. 120 RPMs some packing off on all Three tight spots. Tripping in to 14,750 Wash 14,750 to 14,804, some packing off when we started circ. 250 gals min 2525 psi 120 rpms Circ, Four bottoms up with 280 gals min 120 rpms, 2860 psi Pump out to 10750' with full frill rate Trip back to bottom, no problems eire, Three bottoms up with 280 gals min 120 rpms, 2860 psi eire, Three bottoms up with 280 gals min 120 rpms, 2860 psi Circ displace hole, with 20 bbls spacer, 150 bbls 9.5 brine, follow by 9.5 soilds free Flow-Pro mud displace with 3 bbls min till spacer in csg, 7.5 bbls min till Flow- Pro in csg, 25 rpms Pumping out to CSG shoe @ 10750' with 250 gals min. 1950 psi Circ @ CSG shoe for two bottoms with 280 gals min, 2140psi, 120 rpms Trip out, lay down hole opener Pickup 4" screen liner, Total 104 jts, 48 4' Screen jts., 534" blank jts, 34.5" blank jts. and baker HMc liner hanger and ZXP liner top packer for a total of 4155 ft. Tripping in with liner to 10,700 ft Picking up 4 3/4 collar and 3.5 HWP and stand in derrick in case we need more wt. to get liner to bottom Tripping in with liner to 14804 P/U wt 145,000# S/O wt 60,000 on last stand run, no DC or HWP run Drop ball, pumped to seat, set hanger with 1600 psi, set packer with 3300 psi, shear out ball with 4500 psi, test packer back side to 1,500 psi Printed: 9/29/2003 9:03:35 AM .... . Page7pt 7 BP EXPLORATION Operations.Summary R~port m Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/24/2003 9/25/2003 9/26/2003 MPS-35 MPS-35 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 From - To Hours.. Task Code NPT i Phase 23:30 - 00:00 0.50 CASE P COMP 00:00 - 00:30 0.50 CASE P COMP 00:30 - 02:00 1.50 CASE P COMP 02:00 - 09:00 7.00 CASE P COMP 09:00 - 13:00 4.00 RUNCOI\IP COMP 13:00 - 14:30 1.50 RUNCOI\IP COMP 14:30 - 16:00 1.50 RUNCOI\IP COMP 16:00 - 19:30 3.50 RUNCOI\IP COMP 19:30 - 22:00 2.50 RUNCOI\IP COMP 22:00 - 00:00 2.00 RUNCOI\IP COMP 00:00 - 11 :00 11.00 RUNCOI\IP COMP 11 :00 - 12:30 1.50 RUNCOI\IP COMP 12:30 - 14:00 1.50 RUNCOI\IP COMP 14:00 - 14:30 0.50 RUNCOI\IP COMP 14:30 - 15:00 0.50 RUNCOI\IP COMP 15:00 - 17:30 2.50 RUNCOI\IP COMP 17:30 - 19:30 2.00 RUNCOI\IP COMP 19:30 - 21 :00 1.50 RUNCOI\IP COMP Start: 9/7/2003 Rig Release: 9/26/2003 Rig Number: Spud Date: 9/7/2003 End: Description of Operations Top of liner 10649.98, shoe @ 14804 Release from liner, pull one stand, Cut and slip drill line, service top drive Tripping out with running tool, lay down excess drill pipe Pickup Johnny Wacker, trip in to 10620' Displace well with 8.8 Brine with 450 gals min 2600 psi, 120 rpms Displace 8.8 Brine with 9.2 brine treated with Corrison Inhibitor, 360 gals per min, 1600 psi, 120 rpms Stand back 40 stands in derrick, laying down excess pipe Pull wear ring, Rig up to run Tubing, PJSM Picking up Baker Premier packer, and Phoenix Gauges, and 4.5" 12.6# IBT tubing Picking up 4.5" 12.6# IBT tubing to 9687' 229 jts P/U 115000, S/O 80,000, wire line Guide 9687, XN 9681, Baker packer 9630, X nipple 9620, Phoenix sensor 9604, Sliding sleeve 9585, Phoenix Gauge 9574, GLM 2087,231 clamps, 1 band, test TWC to 1000 psi Nipple down BOPS Nipple up CIW 41/16 tree and adaptor, test to 5,000 psi, test cavity of tree to 4,000 psi Rig up Lubricator and pull TWC Drop ball and rod, rig up circ lines, and test Equipment Set packer with 3200 psi, test tubing 4,000 psi for 30 min., test Annulus 4500 psi for 30 min., bleed down tubing DCK valve shear at 2500 psi, Freeze protect tubing and annulus with HB&R pumped 70 bbls down annulus and let u- tube to tubing. freeze protect 7 5/8 x 10 3/4 annulus with 84 bbls diesel Set BPV , test to 300 psi and secure well, Rig release for rig move 2100 hrs 9/26/2003 Printed: 9/29/2003 9:03:35 AM Legal Name: MPS-35 Common Name: MPS-35 Test Date ----...--.-- 9/11/2003 9/17/2003 FIT FIT Test Type Test Depth (TNiD) 5,816.0 (ft) 10,750.0 (ft) BP EXPLORATION Leak-Off Test Suml11ary . ..........------.---- Test Depth (TVD) 2,903.0 (ft) 4,088.0 (ft) AMW 8.90 (ppg) 9.20 (ppg) Surface Pressure ......----.-------.-------.-- 419 (psi) 500 (psi) Leak Off Pressure (BHP) 1,761 (psi) 2,454 (psi) .:. Page 1 of 1 .....-......,--.......-..--,-. EMW 11.68 (ppg) 11.55 (ppg) . . Printed: 9/29/2003 9:03:13 AM . 803-/l{3 . 09-0ct -03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for WeU MPS-35 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,584.87' MD 12,602.00 I MD 14,804.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager (1f""j ~1 \..> : Attachment(s) \\~;~\\\ ~ Milne Point Unit BPXA Milne Point MPS MPS-35 Job No. AKZZ0002651972, Surveyed: 22 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317500 Surface Coordinates: 5999912.92 N, 565583.96 E (70· 24' 36.7547" N, 149· 27' 57.4954" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71. 68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft !5pE!r"'r"'V-!5U:r, DRIL..L.ING seRVices A Halliburton Company DEFINITIVE . . Survey Ref: svy1285 Þ' Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 Your Ref: APt 500292317500 Job No. AKZZ0002651972, Surveyed: 22 September, 2003 BF' EXPLORATION (ALASKA) INC. BPXA lì'ìiine Point Unit "¡:2sured i.:L:"Sea \':crtica! Lccz! Coordinates G!Cbê! CccrcJinates Dcg:cg \/ e it ¡ c¿ J [epih Inci. Þ2¡n^1. Cc¡;th Depth Northîngs Eastings Northing::: Eastings Rate Secticn Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12584.87 91.610 42.350 4024.16 4095.84 5679.97 N 6481.66 W 6005535.76 N 559052.68 E 5679.97 Tie On Point , 12602.00 91.820 42.270 4023.65 4095.33 ~ 5692.64 N 6470.13 W 6005548.52 N 559064.09 E 1.312 5692.64 Window Point 12627.58 90.190 42.670 4023.20 4094.88 5711.50 N 6452.86 W 6005567.54 N 559081.19 E 6.561 5711.50 12678.12 86.790 40.070 4024.53 4096.21 5749.41 N 6419.48 W 6005605.74 N 559114.24 E 8.467 5749.41 12721.78 88.210 37.030 4026.43 4098.11 5783.51 N 6392.30 W 6005640.08 N 559141.12 E 7.679 5783.51 . 12773.00 89.880 36.020 4027.29 4098.97 5824.67 N 6361.82 W 6005681.50 N 559171.24 E 3.810 5824.67 12819.59 89.320 36.290 4027.61 4099.29 5862.28 N 6334.33 W 6005719.36 N 559198.39 E 1.334 586228 12869.63 89.070 36.140 4028.32 4100.00 5902.65 N 6304.77 W 6005759.98 N 559227.60 E 0.583 5902.65 12913.84 92.660 35.670 4027.65 4099.33 5938.45 N 6278.85 W 6005796.01 N 559253.20 E 8.190 5938.45 12964.71 91.730 34.950 4025.70 4097.38 5979.93 N 6249.47 W 6005837.75 N 559282.22 E 2.311 5979.93 13010.55 92.900 38.080 4023.85 4095.53 6016.74 N 6222.22 W 6005874.79 N 559309.14 E 7.284 6016.74 13060.61 90.250 41 .160 4022.47 4094.15 6055.28 N 6190.32 W 6005913.61 N 559340.71 E 8.114 6055.28 13107.29 90.250 43.350 4022.27 4093.95 6089.83 N 6158.93 W 6005948.43 N 559371.79 E 4.691 6089.83 13167.52 90.680 43.290 4021.78 4093.46 6133.64 N 6117.61W 6005992.61 N 559412.73 E 0.721 6133.64 13203.69 91.420 43.880 4021.12 4092.80 6159.84 N 6092.68 W 6006019.02 N 559437.43 E 2.616 6159.84 13253.58 88.520 45.490 4021.14 4092.82 6195.30 N 6057.60 W 6006054.79 N 559472.19 E 6.648 6195.30 13299.67 88.890 44.800 4022.18 4093.86 6227.80 N 6024.94 W 6006087.58 N 559504.57 E 1.698 6227.80 13351.30 89.070 44.520 4023.10 4094.78 6264.52 N 5988.65 W 6006124.61 N 559540.53 E 0.645 6264.52 13395.06 88.760 42.930 4023.93 4095.61 6296.14 N 5958.41 W 6006156.50 N 559570.49 E 3.701 6296.14 13446.05 89.320 40.200 4024.79 4096.47 6334.28 N 5924.59 W 6006194.93 N 559603.98 E 5.465 6334.28 13491.08 90.620 39.450 4024.81 4096.49 6368.86 N 5895.75 W 6006229.77 N 559632.51 E 3.333 6368.86 13541.69 91.910 38.920 4023.69 4095.37 6408.08 N 5863.78 W 6006269.26 N 559664.14 E 2.756 6408.08 . 13587.73 91.670 38.690 4022.26 4093.94 6443.94 N 5834.94 W 6006305.38 N 559692.66 E 0.722 6443.94 13638.60 91.230 39.050 4020.97 4092.65 6483.53 N 5803.03 W 6006345.25 N 559724.22 E 1.117 6483.53 13683.50 91.730 38.530 4019.81 4091.49 6518.52 N 5774.91 W 6006380.48 N 559752.03 E 1.606 6518.52 13733.71 91.230 39.460 4018.51 4090.19 6557.53 N 5743.33 W 6006419.76 N 559783.27 E 2.102 6557.53 13777.63 90.490 39.730 4017.85 4089.53 6591.37 N 5715.34 W 6006453.85 N 559810.96 E 1.794 6591.37 13828.28 88.520 43.470 4018.29 4089.97 6629.23 N 5681.72 W 6006492.01 N 559844.25 E 8.345 6629.23 13873.75 87.160 43.760 4020.00 4091.68 6662.13 N 5650.38 W 6006525.18 N 559875.30 E 3.058 6662.13 13922.40 86.790 43.940 4022.57 4094.25 6697.17 N 5616.72 W 6006560.51 N 559908.65 E 0.846 6697.17 13968.16 86.170 44.160 4025.38 4097.06 6729.99 N 5584.96 W 6006593.61 N 559940.12 E 1 .437 6729.99 14019.05 86.050 43.960 4028.83 4100.51 6766.48 N 5549.66 W 6006630.41 N 559975.10 E 0.458 6766.48 14064.44 85.740 43.930 4032.08 4103.76 6799.08 N 5518.24 W 6006663.28 N 560006.23 E 0.686 6799.08 14115.00 87.840 42.670 4034.91 4106.59 6835.81 N 5483.62 W 6006700.32 N 560040.53 E 4.842 6835.81 14161.41 88.520 42.270 4036.39 4108.07 6870.03 N 5452.30 W 6006734.81 N 560071.54 E 1.700 6870.03 7 October, 2003 - 7:27 Page 2 of 4 DrillQuest 3.03.02.005 ,.. Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 Your Ref: API 500292317500 Job No. AKZZ0002651972, Surveyed: 22 September, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Point Unit ~:' ì_; L ,·S ea \"er:ic2¡ Lcca! (cordinate:: C1cbol Cccrdinates L.( \Jert¡c;~:¡ L'€p'~; ¡riCL Depth Depth r:h¡r¡gs E2.stinfj:: r·'(;iîh¡n£js Eastings i',é'·''"( ::,ection C c rr¡ (';-'\1::: r:t (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 14211.87 92.280 42.000 4036.04 4107.72 6907.44 N 5418.45 W 6006772.51 N 560105.06 E 7.471 6907.44 14257.56 91.240 42.760 4034.63 4106.31 6941 .17 N 5387.67 W 6006806.52 N 560135.54 E 2.819 6941.17 14307.49 89.880 42.670 4034.14 4105.82 6977.86 N 5353.80 W 6006843.50 N 560169.09 E 2.730 6977 .86 14353.88 88.580 42.430 4034.77 4106.45 7012.03 N 5322.44 W 6006877.94 N 560200.15 E 2.850 7012.03 14404.48 88.150 41.630 4036.21 4107.89 7049.60 N 5288.57 W 6006915.81 N 560233.69 E 1.794 7049.60 . 14450.25 87.160 41.350 4038.08 4109.76 7083.85 N 5258.28 W 6006950.33 N 560263.68 E 2.248 7083.85 14500.43 87.530 4 Î .840 4040.41 4112.09 7121.34N 5225.00 W 6006988.10 N 560296.63 E 1.223 7121.34 14544.40 88.950 40.080 4041.76 4113.44 7154.53 N 5196.19 W 6007021.54 N 560325.14 E 5.142 7154.53 14595.05 88.890 39.680 4042.71 4114.39 7193.39 N 5163.72 W 6007060.69 N 560357.27 E 0.798 7193.39 14640.49 91.850 39.030 4042.42 4114.10 7228.52 N 5134.91 W 6007096.07 N 560385.77 E 6.669 7228.52 14690.81 91.540 38.860 4040.93 4112.61 7267.64 N 5103.30 W 6007135.47 N 560417.04 E 0.703 7267.64 14736.16 90.860 38.910 4039.98 4111.66 7302.93 N 5074.83 W 6007171.01 N 560445.19 E 1.503 7302.93 ,. 14804.00 90.860 38.910 4038.96 4110.64 - 7355.71 N 5032.23 W 6007224.16 N 560487.33 E 0.000 7355.71 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14804.00ft., The Bottom Hole Displacement is 8912.34ft., in the Direction of 325.623° (True). . 7 October, 2003· 7:27 Page 3 of 4 DrillQuest 3.03.02.005 .... Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 Your Ref: API 500292317500 Job No. AKZZ0002651972, Surveyed: 22 September, 2003 BP EXPLORA TION (ALASKA) INC. A'íiine Point Unh BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 12584.87 12602.00 14804.00 4095.84 4095.33 4110.64 5679.97 N 5692.64 N 7355.71 N 6481.66 W 6470.13 W 5032.23 W Tie On Point Window Point Projected Survey . Survey tool program for MPS-35 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 457.00 0.00 456.67 457.00 14804.00 456.67 Tolerable Gyro (MPS-35PB1) 4110.64 AK-6 BP _IFR-AK (MPS-35PB 1) . 7 October, 2003 - 7:27 Page 4 of 4 DrillQuest 3.03.02.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . ðD3-/45 09-0ct-03 Re: Distribution of Survey Data for Well MPS-35 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,584.87' MD 12,602.00' MD 14,804.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment( s) K~~\\ \~ n \.! ,.. Sperry-SUI] Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-35 MWD . Job No. AKMW0002651972, Surveyed: 22 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317500 Surface Coordinates: 5999912.92 N, 565583.96 E (70024' 36.7547" N, 149027' 57.4954" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71. 68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft SpE!ï'í'Y-SUI! ORf LL I N Gse RV Ie: es A Halliburton Company Survey Ref: svy1289 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 MWD Your Ref: API 500292317500 JcL¡ No. AKMW0002651972, Surveyed: 22 September, 2003 BP EXF'LOFi.'A nON (ALASKA) INC. BPXp Milne Point Unit l\ileasured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12584.87 91610 42.330 4024.53 4096.21 5819.05N 6380.83 W 6005675.72 N 559152.28 E 5819.05 Tie On Point 12602.00 91.820 42.270 4024.02 4095.70 5831.71 N 6369.31 W 6005688.48 N 559163.69 E 1.275 5831.71 Window Point 12627.58 90.190 43.220 4023.57 4095.25 5850.50 N 6351.95 W 6005707.41 N 559180.88 E 7.375 5850.50 12678.12 86.790 41.040 4024.90 4096.58 5887.96 N 6318.07 W 6005745.17 N 559214.44 E 7.990 5887.96 12721.78 88.210 37.440 4026.81 4098.49 5921.73 N 6290.48 W 6005779.19 N 559241.72 E 8.856 5921.73 . 12773.00 89.880 36.570 4027.66 4099.34 5962.63 N 6259.66 W 6005820.35 N 559272.19 E 3.676 5962.63 12819.59 89.320 35.760 4027.99 4099.67 6000.24 N 6232.16 W 6005858.21 N 559299.35 E 2.114 6000.24 12869.63 89.070 36.880 4028.69 4100.37 6040.55 N 6202.53 W 6005898.78 N 559328.63 E 2.293 6040.55 12913.84 92.660 36.500 4028.02 4099.70 6076.00 N 6176.12 W 6005934.45 N 559354.72 E 8.166 6076.00 12964.71 91.730 35.760 4026.08 4097.76 6117.05N 6146.15 W 6005975.77 N 559384.33 E 2.336 6117.05 13010.55 92.900 38.810 4024.22 4095.90 6153.49 N 6118.41 W 6006012.45 N 559411.75 E 7.121 6153.49 13060.61 90.250 41.550 4022.85 4094.53 6191.71N 6086.13 W 6006050.95 N 559443.70 E 7.613 6191.71 13107.29 90.250 43.780 4022.64 4094.32 6226 04 N 6054.50 W 6006085.55 N 559475.03 E 4.777 6226.04 1316752 90.680 43.830 4022.16 4093.84 6269.50 N 6012.80 W 600612938 N 559516.33 E 0719 6269.50 13203.69 91.420 44.480 4021.49 4093.17 6295.45 N 5987.61 W 6006155.55 N 559541.30 E 2.723 6295.45 13253.58 88.520 45.920 4021.52 4093.20 6330.60 N 5952.22 W 6006191.01 N 559576.38 E 6.490 6330.60 13299.67 88.890 45.480 4022.56 4094.24 6362.78 N 5919.24 W 6006223.48 N 559609.08 E 1.247 6362.78 13351.30 89.070 45.100 4023.48 4095.16 6399.10N 5882.55 W 6006260.12 N 559645.44 E 0.814 6399.10 13395.06 88.760 43.580 4024.31 4095.99 6430.39 N 5851.98 W 6006291.67 N 559675.74 E 3.544 6430.39 13446.05 89.320 40.780 4025.16 4096.84 6468.16 N 5817.75 W 6006329.75 N 559709.64 E 5.599 6468.16 13491.08 90.620 40.090 4025.19 4096.87 6502.44 N 5788.54 W 6006364.28 N 559738.54 E 3.268 6502.44 13541.69 91.910 39.280 4024.07 4095.75 6541.37 N 5756.23 W 6006403.50 N 559770.51 E 3.009 6541.37 . 13587.73 91.670 39.430 4022.63 4094.31 6576.96 N 5727.05 W 6006439.33 N 559799.38 E 0.615 6576.96 13638.60 91.230 40.920 4021.34 4093.02 6615.81 N 5694.25 W 6006478.48 N 559831.84 E 3.053 6615.81 13683.50 91.730 40.300 4020.18 4091.86 6649.89 N 5665.03 W 6006512.81 N 559860.76 E 1.774 6649.89 13733.71 91.230 39.820 4018.89 4090.57 6688.30 N 5632.73 W 6006551.50 N 559892.72 E 1.380 6688.30 13777.63 90.490 39.280 4018.23 4089.91 6722.16 N 5604.76 W 6006585.61 N 559920.39 E 2.086 6722.16 13828.28 88.520 44.110 4018.67 4090.35 6759.97 N 5571.09 W 6006623.71 N 559953.73 E 10.298 6759.97 13873.75 87.160 44.160 4020.38 4092.06 6792.58 N 5539.45 W 6006656.60 N 559985.08 E 2.993 6792.58 13922.40 86.790 44.380 4022.95 4094.63 6827.37 N 5505.53 W 6006691.68 N 560018.69 E 0.884 6827.37 13968.16 86.170 44.570 4025.76 4097.44 6859.96 N 5473.53 W 6006724.55 N 560050.40 E 1.417 6859.96 14019.05 86.050 44.420 4029.21 4100.89 6896.17 N 5437.95 W 6006761.08 N 560085.66 E 0.377 6896.17 14064.44 85.740 44.660 4032.46 4104.14 6928.44 N 5406.20 W 6006793.62 N 560117.13 E 0.863 6928.44 14115.00 87.840 43.340 4035.29 4106.97 6964.75 N 5371.13 W 6006830.24 N 560151.88 E 4.904 6964.75 14161.41 88.520 42.830 4036.76 4108.44 6998.63 N 5339.45 W 6006864.40 N 560183.26 E 1.831 6998.63 7 October, 2003 - 8:17 Page 20f4 Dril/Quest 3.03.02.005 - Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 MWD Your Ref: API 500292317500 Job No. AKMWOOO2651972, Surveyed: 22 September, 2003 BP EXPLCF.ß TKN (ALASKA) INC. BPX.t Milne Point Unit Measured Sub-Sea Vertical L.ocal Coordinates Global Cocrdinates Dogleg Vertica, Depth incL Azim. Depth [;spth Northings Eastings Northings Eastings Rate Section COlTlment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 1421187 (~280 42.630 4036.41 ¿ 10[;09 7035.69 N 5305.2"1 'IN 6006901.75 N 560217.17 E 7462 7035.69 14257.56 91.240 43.350 4035.01 4106.69 7069.09 N 5274.07 W 6006935.43 N 560248.01 E 2.768 7069.09 14307.49 89.880 43.210 4034.52 4106.20 7105.44 N 5239.85 W 6006972.08 N 560281.92 E 2.738 7105.44 14353.88 88.580 42.960 4035.14 4106.82 7139.32 N 5208.16 W 6007006.23 N 560313.31 E 2.854 7139.32 14404.48 88.150 42.330 4036.59 4108.27 7176.52N 5173.90 W 6007043.73 N 560347.25 E 1.507 7176.52 . 14450.25 87.160 41.790 4038.46 4110.14 7210.47N 5143.26 W 6007077.95 N 560377.58 E 2.463 7210.47 14500.43 87.530 41.600 4040.78 4112.46 7247.90 N 5109.92 W 6007115.67 N 560410.59 E 0.829 7247.90 1454440 88.950 40.430 4042.13 4113.81 7281.06 N 5081.08 W 6007149.09 N 560439.14 E 4.184 7281.06 14595.05 88.890 40.650 4043.09 4114.77 7319.55N 5048.16 W 6007187.86 N 560471.72 E 0.450 7319.55 14640.49 91.850 40.280 4042.80 4114.48 7354.11 N 5018.68 W 6007222.68 N 560500.90 E 6.565 7354.11 14690.81 91.540 39.370 4041.31 4112.99 7392.74 N 4986.47 W 6007261.59 N 560532.77 E 1.910 7392.74 14736.16 90.860 39.830 4040.36 4112.04 7427.68 N 4957.56 W 6007296.78 N 560561.36 E 1.810 7427.68 14804.00 90.860 39.830 4039.34 4111.02 7479.77 N 4914.12 W 6007349.25 N 560604.35 E 0.000 7479.77 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14804.00ft., The Bottom Hole Displacement is 8949.61ft., in the Direction of 326.696° (True). . 7 October, 2003 - 8:17 Page 3 of4 DrillQuest 3.03.02.005 - Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35 MWD Your Ref: API 500292317500 Job No. AI\Mv,con;'C51972, Surveyed: 22 Septembr, :;003 Ei EXPLCFA nON (ALASKA) INC, Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12584.87 12602.00 14804.00 4096.21 4095.70 4111.02 5819.05N 5831.71 N 7479.77 N 6380.83 W 6369.31 W 4914.12 W Tie On Point Window Point Projected Survey . Survey tool program for MPS-35 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 457.00 0.00 456.67 457.00 14804.00 456.67 Tolerable Gyro (MPS-35PB1 MWD) 4111.02 MWD Magnetic (MPS-35PB 1 MWD) . 7 October, 2003 - 8:17 Page 4 of 4 DrillQuest 3.03.02.005 · AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ffC3 -- L13 09-0ct-03 Re: Distribution of Survey Data for Well MPS...35 PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 11,617.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment(s) ~~~v\\~ Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-35PB1 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317570 Surface Coordinates: 5999912.92 N, 565583.96 E (70' 24' 36.75478 N, 149' 27' 57.49548 W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71.68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft SpI!!!I"""I"""Y-SUI! DAII-LING SIiæAVlces A Halliburton Company DEFINITIVE . . Survey Ref: svy1283 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 Your Ref: API 500292317570 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -71.68 0.00 0.00 N 0.00 E 5999912.92 N 565583.96 E 0.00 Tolerable Gyro 186.00 1.250 263.000 114.31 185.99 0.25 S 2.01 W 5999912.66 N 565581.95 E 0.672 -0.25 304.43 2.060 276.090 232.69 304.37 0.18 S 5.41 W 5999912.69 N 565578.55 E 0.750 -0.18 368.00 3.000 279.000 296.19 367.87 0.20 N 8.19W 5999913.05 N 565575.77 E 1 .492 0.20 457.00 4.750 291.000 384.99 456.67 1.89 N 13.93W 5999914.69 N 565570.01 E 2.157 1.89 AK-6 BP _IFR-AK . 576.03 8.080 295.510 503.26 574.94 7.26 N 26.09 W 5999919.95 N 565557.81 E 2.827 7.26 665.62 12.100 296.700 591.44 663.12 14.19 N 40.16 W 5999926.76 N 565543.67 E 4.493 14.19 756.20 16.840 292.730 679.13 750.81 23.53 N 60.76 W 5999935.92 N 565523.00 E 5.343 23.53 852.84 21.090 288.750 770.50 842.18 34.54 N 90.15 W 5999946.66 N 565493.51 E 4.594 34.54 947.01 24.660 290.590 857.25 928.93 46.89 N 124.59 W 5999958.72 N 565458.96 E 3.866 46.89 1043.78 27.470 286.650 944.18 1015.86 60.39 N 164.89 W 5999971.86 N 565418.55 E 3.409 60.39 1140.18 28.840 282.210 1029.18 1100.86 71.68 N 208.92 W 5999982.77 N 565374.42 E 2.596 71.68 1236.07 30.760 283.830 1112.39 1184.07 82.44 N 255.34 W 5999993.11 N 565327.91 E 2.171 82.44 1332.87 34.260 282.960 1194.01 1265.69 94.47 N 305.94 W 6000004.70 N 565277.20 E 3.648 94.47 1429.41 38.320 283.590 1271.81 1343.49 107.60 N 361.54 W 6000017.34 N 565221.49 E 4.223 107.60 1525.08 41.420 283.710 1345.22 1416.90 122.07 N 421.13 W 6000031.29 N 565161.77 E 3.241 122.07 1620.55 41.410 283.500 1416.82 1488.50 136.93 N 482.51 W 6000045.61 N 565100.26 E 0.146 136.93 1717.06 45.050 282.900 1487.13 1558.81 152.01 N 546.86 W 6000060.12 N 565035.79 E 3.796 152.01 1813.46 44.520 284.780 1555.55 1627.23 168.25 N 612.79 W 6000075.78 N 564969.71 E 1.480 168.25 1909.59 47.010 285.860 1622.61 1694.29 186.46 N 679.21 W 6000093.41 N 564903.14 E 2.712 186.46 2006.46 51.900 286.150 1685.56 1757.24 206.75 N 749.94 W 6000113.08 N 564832.23 E 5.053 206.75 2100.78 53.850 288.170 1742.49 1814.17 228.95 N 821.78 W 6000134.65 N 564760.20 E 2.681 228.95 . 2195.99 52.980 286.700 1799.23 1870.91 251.87 N 894.72 W 6000156.92 N 564687.07 E 1.540 251.87 2293.26 58.960 285.530 1853.65 1925.33 274.20 N 972.13 W 6000178.57 N 564609.46 E 6.228 274.20 2389.32 64.200 286.240 1899.35 1971.03 297.33 N 1053.36 W 6000200.99 N 564528.03 E 5.493 297.33 2485.47 67.560 288.070 1938.64 2010.32 323.23 N 1137.19 W 6000226.15 N 564443.98 E 3.902 323.23 2581.44 69.890 290.340 1973.46 2045.14 352.65 N 1221.62W 6000254.83 N 564359.29 E 3.279 352.65 2677.91 71.640 293.400 2005.25 2076.93 386.59 N 1306.13 W 6000288.02 N 564274.49 E 3.501 386.59 2773.79 73.720 295.290 2033.79 2105.47 424.32 N 1389.51 W 6000325.03 N 564190.78 E 2.872 424.32 2868.81 74.810 295.140 2059.56 2131.24 463.29 N 1472.25 W 6000363.26 N 564107.69 E 1.157 463.29 2962.92 75.390 295.110 2083.76 2155.44 501.90 N 1554.59 W 6000401.15 N 564025.02 E 0.617 501.90 3060.38 75.130 297.340 2108.56 2180.24 543.55 N 1639.14 W 6000442.05 N 563940.11 E 2.229 543.55 3155.80 74.430 298.670 2133.61 2205.29 586.78 N 1720.43 W 6000484.57 N 563858.44 E 1.532 586.78 3252.28 74.490 297.470 2159.46 2231.14 630.51 N 1802.45 W 6000527.58 N 563776.05 E 1.200 630.51 3347.97 76.030 295.470 2183.81 2255.49 671.75 N 1885.28 W 6000568.09 N 563692.85 E 2.584 671.75 7 October, 2003 - 7:20 Page 2 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 Your Ref: AP/500292317570 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 3443.78 77.050 293.510 2206.11 2277.79 710.37 N 1970.07 W 6000605.97 N 563607.72 E 2.256 710.37 3540.02 77.740 293.630 2227.11 2298.79 747.93 N 2056.16 W 6000642.77 N 563521.31 E 0.727 747.93 3635.71 76.670 292.760 2248.30 2319.98 784.68 N 2141.93 W 6000678.76 N 563435.23 E 1.427 784.68 3731.81 73.990 291.830 2272.64 2344.32 819.95 N 2227.93 W 6000713.28 N 563348.91 E 2.942 819.95 3828.64 72.040 293.080 2300.93 2372.61 855.32 N 2313.51 W 6000747.89 N 563263.02 E 2.362 855.32 . 3922.92 73.460 293.230 2328.88 2400.56 890.72 N 2396.30 W 6000782.57 N 563179.93 E 1.514 890.72 4019.72 73.850 294.120 2356.12 2427.80 928.02 N 2481.37 W 6000819.12 N 563094.54 E 0.970 928.02 4115.57 73.330 294.860 2383.20 2454.88 966.13 N 2565.04 W 6000856.49 N 563010.54 E 0.918 966.13 4207.86 72.630 296.100 2410.22 2481.90 1004.10 N 2644.70 W 6000893.75 N 562930.54 E 1.492 1004.10 4308.20 74.230 295.290 2438.83 2510.51 1045.79 N 2731.36 W 6000934.69 N 562843.52 E 1.772 1045.79 4402.98 73.540 295.860 2465.14 2536.82 1085.10 N 2813.50 W 6000973.27 N 562761.04 E 0.929 1085.10 4498.62 75.010 294.980 2491.06 2562.74 1124.61 N 2896.64 W 6001012.05 N 562677.55 E 1.774 1124.61 4594.67 75.260 294.940 2515.70 2587.38 1163.79N 2980.81 W 6001050.49 N 562593.05 E 0.263 1163.79 4690.87 74.700 295.040 2540.63 2612.31 1203.04 N 3065.02 W 6001089.00 N 562508.49 E 0.591 1203.04 4786.44 74.750 294.890 2565.81 2637.49 1241.95 N 3148.60 W 6001127.17 N 562424.57 E 0.160 1241.95 4883.75 74.810 295.340 2591.36 2663.04 1281.80N 3233.62 W 6001166.28 N 562339.21 E 0.450 1281.80 4978.39 75.210 294.890 2615.84 2687.52 1320.60 N 3316.40 W 6001204.35 N 562256.09 E 0.624 1320.60 5074.64 75.190 295.850 2640.42 2712.10 1360.47 N 3400.48 W 6001243.48 N 562171.67 E 0.965 1360.47 5170.84 75.650 295.910 2664.64 2736.32 1401.11 N 3484.24 W 6001283.38 N 562087.55 E 0.482 1401.11 5265.25 74.620 297.440 2688.86 2760.54 1442.07 N 3565.78 W 6001323.63 N 562005.66 E 1.909 1442.07 5361.26 75.450 295.020 2713.66 2785.34 1483.06 N 3648.97 W 6001363.88 N 561922.10 E 2.584 1483.06 5456.75 76.090 294.360 2737.13 2808.81 1521.72 N 3733.07 W 6001401.80 N 561837.67 E 0.948 1521.72 . 5551.87 76.090 295.030 2760.00 2831.68 1560.30 N 3816.96 W 6001439.64 N 561753.45 E 0.684 1560.30 5649.12 74.940 293.690 2784.32 2856.00 1599.14N 3902.73 W 6001477.72 N 561667.34 E 1.783 1599.14 5760.08 72.630 294.200 2815.31 2886.99 1642.37 N 4000.10 W 6001520.10 N 561569.59 E 2.128 1642.37 5835.94 71.590 293.370 2838.61 2910.29 1671.49 N 4066.16 W 6001548.64 N 561503.28 E 1.722 1671.49 5931.68 73.090 293.500 2867.65 2939.33 1707.77 N 4149.86 W 6001584.18 N 561419.27 E 1.572 1707.77 6028.46 74.360 292.700 2894.77 2966.45 1744.22 N 4235.31 W 6001619.88 N 561333.50 E 1.533 1744.22 6124.79 73.480 293.550 2921.46 2993.14 1780.57 N 4320.43 W 6001655.48 N 561248.06 E 1.246 1780.57 6221.35 76.290 292.720 2946.63 3018.31 1817.18 N 4406.15 W 6001691.34 N 561162.03 E 3.026 1817.18 6318.01 77.700 293.860 2968.38 3040.06 1854.42 N 4492.65 W 6001727.82 N 561075.20 E 1.857 1854.42 6413.83 77.330 294.010 2989.10 3060.78 1892.38 N 4578.16 W 6001765.02 N 560989.36 E 0.415 1892.38 6508.44 76.180 294.510 3010.78 3082.46 1930.21 N 4662.12 W 6001802.12 N 560905.07 E 1.320 1930.21 6604.98 75.740 294.250 3034.20 3105.88 1968.87 N 4747.42 W 6001840.03 N 560819.43 E 0.525 1968.87 6701.31 75.080 294.040 3058.46 3130.14 2007.01 N 4832.49 W 6001877.42 N 560734.03 E 0.717 2007.01 7 October, 2003 - 7:20 Page 3 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 Your Ref: API 500292317570 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6798.09 75.470 294.130 3083.06 3154.74 2045.21 N 4917.94 W 6001914.86 N 560648.25 E 0.413 2045.21 6894.59 75.730 294.430 3107.06 3178.74 2083.64 N 5003.14 W 6001952.55 N 560562.71 E 0.404 2083.64 6989.78 75.610 294.630 3130.62 3202.30 2121.93 N 5087.05 W 6001990.10 N 560478.48 E 0.239 2121.93 7086.29 75.750 295.080 3154.49 3226.17 2161.23 N 5171.90 W 6002028.66 N 560393.29 E 0.475 2161.23 7182.68 74.970 295.270 3178.85 3250.53 2200.91 N 5256.30 W 6002067.59 N 560308.54 E 0.831 2200.91 . 7280.25 74.240 295.060 3204.75 3276.43 2240.91 N 5341.44 W 6002106.84 N 560223.05 E 0.776 2240.91 7375.67 72.950 294.620 3231.70 3303.38 2279.36 N 5424.50 W 6002144.56 N 560139.65 E 1.422 2279.36 7470.85 71.790 294.430 3260.53 3332.21 2317.01 N 5507.03 W 6002181.49 N 560056.80 E 1.234 2317.01 7566.87 74.100 294.240 3288.69 3360.37 2354.84 N 5590.66 W 6002218.57 N 559972.84 E 2.413 2354.84 7663.38 75.390 296.110 3314.08 3385.76 2394.44 N 5674.92 W 6002257.44 N 559888.23 E 2.298 2394.44 7759.08 75.450 296.230 3338.18 3409.86 2435.29 N 5758.04 W 6002297.56 N 559804.76 E 0.137 2435.29 7855.19 75.010 295.800 3362.68 3434.36 2476.05 N 5841.56 W 6002337.58 N 559720.88 E 0.630 2476.05 7951.72 73.980 296.380 3388.48 3460.16 2516.96 N 5925.10 W 6002377.75 N 559636.99 E 1.214 2516.96 8047.53 73.720 296.700 3415.13 3486.81 2558.08 N 6007.43 W 6002418.15 N 559554.30 E 0.420 2558.08 8143.13 72.970 296.280 3442.53 3514.21 2598.93 N 6089.40 W 6002458.28 N 559471.97 E 0.890 2598.93 8239.77 74.820 296.320 3469.34 3541.02 2640.07 N 6172.63 W 6002498.68 N 559388.38 E 1.915 2640.07 8336.00 76.410 294.450 3493.25 3564.93 2680.02 N 6256.84 W 6002537.90 N 559303.83 E 2.505 2680.02 8430.71 75.550 294.600 3516.19 3587.87 2718.16 N 6340.44 W 6002575.30 N 559219.90 E 0.921 2718.16 8527.17 75.200 294.020 3540.55 3612.23 2756.59 N 6425.50 W 6002612.98 N 559134.50 E 0.686 2756.59 8623.72 75.390 294.030 3565.05 3636.73 2794.61 N 6510.80 W 6002650.25 N 559048.88 E 0.197 2794.61 8717.63 75.080 294.890 3588.99 3660.67 2832.21 N 6593.45 W 6002687.12 N 558965.89 E 0.945 2832.21 8811.95 74.690 294.710 3613.58 3685.26 2870.40 N 6676.11 W 6002724.59 N 558882.90 E 0.453 2870.40 . 8908.66 75.200 294.620 3638.70 3710.38 2909.37 N 6760.98 W 6002762.81 N 558797.69 E 0.535 2909.37 9003.59 74.820 293.840 3663.26 3734.94 2947.01 N 6844.60 W 6002799.71 N 558713.74 E 0.889 2947.01 9098.35 75.980 296.340 3687.15 3758.83 2985.89 N 6927.64 W 6002837.87 N 558630.37 E 2.831 2985.89 9195.90 76.810 301.360 3710.11 3781.79 3031.63 N 7010.65 W 6002882.87 N 558546.96 E 5.073 3031.63 9292.49 74.560 308.240 3734.01 3805.69 3084.98 N 7087.46 W 6002935.55 N 558469.68 E 7.283 3084.98 9324.53 72.900 309.900 3742.99 3814.67 3104.36 N 7111.34 W 6002954.72 N 558445.63 E 7.182 3104.36 9356.41 72.380 310.140 3752.50 3824.18 3123.93 N 7134.64 W 6002974.08 N 558422.16 E 1.782 3123.93 9388.29 72.500 310.720 3762.12 3833.80 3143.64 N 7157.78 W 6002993.59 N 558398.85 E 1.775 3143.64 9483.34 71.920 313.070 3791.17 3862.85 3204.07 N 7225.14 W 6003053.42 N 558330.96 E 2.432 3204.07 9579.17 71.530 316.170 3821.22 3892.90 3267.98 N 7289.91 W 6003116.76 N 558265.64 E 3.099 3267.98 9674.90 73.100 319.630 3850.31 3921.99 3335.64 N 7351.03 W 6003183.88 N 558203.92 E 3.814 3335.64 9771.29 75.830 323.680 3876.13 3947.81 3408.47 N 7408.61 W 6003256.20 N 558145.71 E 4.940 3408.47 9867.14 77.690 328.390 3898.10 3969.78 3485.83 N 7460.71 W 6003333.10 N 558092.93 E 5.162 3485.83 7 October, 2003 - 7:20 Page 4 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 Your Ref: API 500292317570 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9962.86 78.880 333.250 3917.54 3989.22 3567.64 N 7506.38 W 6003414.51 N 558046.54 E 5.124 3567.64 10058.20 82.140 338.000 3933.27 4004.95 3653.26 N 7545.16 W 6003499.79 N 558007.02 E 5.986 3653.26 10154.30 84.430 343.550 3944.51 4016.19 3743.34 N 7576.56 W 6003589.59 N 557974.83 E 6.211 3743.34 10250.88 83.130 347.430 3954.98 4026.66 3836.27 N 7600.61 W 6003682.30 N 557949.96 E 4.214 3836.27 10347.16 82.820 347.860 3966.76 4038.44 3929.61 N 7621.06 W 6003775.46 N 557928.69 E 0.548 3929.61 . 10443.32 82.700 350.940 3978.88 4050.56 4023.37 N 7638.60 W 6003869.06 N 557910.32 E 3.180 4023.37 10539.32 82.630 356.030 3991.14 4062.82 4117.93 N 7649.40 W 6003963.53 N 557898.69 E 5.259 4117.93 10633.66 83.310 358.850 4002.69 4074.37 4211 .46 N 7653.58 W 6004057.01 N 557893.69 E 3.053 4211.46 10692.46 82.390 358.950 4010.01 4081.69 4269.79 N 7654.70 W 6004115.33 N 557892.06 E 1.574 4269.79 10754.11 84.000 0.190 4017.32 4089.00 4331.00N 7655.16 W 6004176.54 N 557891.06 E 3.288 4331.00 10802.66 87.780 1.160 4020.79 4092.47 4379.42 N 7654.59 W 6004224.95 N 557891.21 E 8.037 4379.42 10853.03 89.570 7.820 4021.96 4093.64 4429.59 N 7650.65 W 6004275.16 N 557894.71 E 13.687 4429.59 10898.93 90.930 15.620 4021.76 4093.44 4474.49 N 7641.33 W 6004320.14 N 557903.63 E 17.249 4474.49 10945.08 88.950 21.320 4021.81 4093.49 4518.25 N 7626.72 W 6004364.02 N 557917.86 E 13.074 4518.25 10995.19 88.390 25.930 4022.97 4094.65 4564.13 N 7606.65 W 6004410.08 N 557937.53 E 9.265 4564.13 11045.76 91.670 31.450 4022.95 4094.63 4608.4 7 N 7582.38 W 6004454.63 N 557961.40 E 12.696 4608.4 7 11091.17 92.100 35.090 4021.45 4093.13 4646.41 N 7557.49 W 6004492.79 N 557985.96 E 8.067 4646.41 11142.80 90.860 40.050 4020.12 4091.80 4687.31 N 7526.03 W 6004533.96 N 558017.06 E 9.899 4687.31 11188.07 89.940 45.110 4019.80 4091.48 4720.63 N 7495.41 W 6004567.55 N 558047.39 E 11 .360 4720.63 11235.31 87.900 47.590 4020.69 4092.37 4753.22 N 7461.24 W 6004600.44 N 558081.27 E 6.797 4753.22 11284.27 89.260 47.010 4021.90 4093.58 4786.42 N 7425.27 W 6004633.95 N 558116.95 E 3.020 4786.42 11334.21 89.880 46.390 4022.28 4093.96 4820.66 N 7388.93 W 6004668.52 N 558152.99 E 1.756 4820.66 . 11380.82 89.880 45.600 4022.38 4094.06 4853.05 N 7355.40 W 6004701.19 N 558186.23 E 1.695 4853.05 11430.92 90.120 45.820 4022.38 4094.06 4888.03 N 7319.54 W 6004736.49 N 558221.78 E 0.650 4888.03 11476.89 90.860 45.880 4021.98 4093.66 4920.05 N 7286.56 W 6004768.80 N 558254.48 E 1.615 4920.05 11527.24 91.360 46.770 4021.01 4092.69 4954.81 N 7250.15 W 6004803.88 N 558290.58 E 2.027 4954.81 11549.80 91.730 45.750 4020.40 4092.08 4970.40 N 7233.86 W 6004819.61 N 558306.74 E 4.808 4970.40 11617.00 91.730 45.750 4018.37 4090.05 5017.27 N 7185.74 W 6004866.90 N 558354.44 E 0.000 5017.27 Projected Survey 7 October, 2003· 7:20 Page 50f6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 Your Ref: API 500292317570 Job No. AKZZ0002651972, Surveyed: 18 September, 2003 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit BPXA p,il cata is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) . Based upon Minimum Curvature type calculations, at a Measured Depth of 11617.00ft., The Bottom Hole Displacement is 8764,01ft., in the Direction of 304.924° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11617.00 4090.05 5017.27 N 7185.74 W Projected Survey Survey tool program for MPS-35PB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 457.00 0.00 456.67 457.00 11617.00 456.67 Tolerable Gyro 4090.05 AK-6 BP JFR-AK 7 October, 2003 - 7:20 Page 6 of 6 DrillQuest 3.03.02.005 · AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 .003-/10 Re: Distribution of Survey Data for Well MPS...35 P81 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00 I MD 11,617.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) ~~~{\\~ 09-0ct-03 err}f>!, Drilling Se'tvices Milne Point Unit BPXA Milne Point MPS MPS-35PB1 MWD . Job No. AKMW0002651972, Surveyed: 18 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317570 Surface Coordinates: 5999912.92 N, 565583.96 E (70024' 36.7547H N, 149027' 57.4954H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71. 68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft spe............v-sul'1 DRILLING SERVICES A Halliburton Company Survey Ref: svy1286 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 MWD Your Ref: API 500292317570 Job No. AKMW0002651972, Surveyed: 18 September, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milrl0 Point Uni¡ Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -71.68 0.00 0.00 N 0.00 E 5999912.92 N 565583.96 E 0.00 Tolerable Gyro 186.00 1.250 263.000 114.31 185 99 0.25 S 201 W 5999912.66 N 565581.95 E 0672 -0.25 304.43 2.060 265.890 232.68 304.36 0.56 S 5.42 W 5999912.32 N 565578.55 E 0.687 -0.56 368.00 3.000 279.000 296.19 367.87 0.38 S 8.20W 5999912.47 N 565575.76 E 1.727 -0.38 457.00 4.750 291.000 384.99 456.67 1.31 N 13.94 W 5999914.10 N 565570.01 E 2.157 1.31 MWD Magnetic . 576.03 8.080 296.070 503.26 574.94 6.75 N 26.06 W 5999919.44 N 565557.84 E 2.835 6.75 665.62 12.100 297.270 591 .44 663.12 13.82 N 40.07 W 5999926.39 N 565543.77 E 4.493 13.82 756.20 16.840 293.340 679.13 750.81 23.38 N 60.57 W 5999935.76 N 565523.19 E 5.341 23.38 852.84 21.090 289.320 770.50 842.18 34.68 N 89.84 W 5999946.81 N 565493.82 E 4.598 34.68 947.01 24.660 291.170 857.25 928.93 47.38 N 124.16 W 5999959.21 N 565459.39 E 3.867 47.38 1043.78 27.470 287.200 944.18 1015.86 61.28 N 164.32 W 5999972.75 N 565419.11 E 3.416 61.28 1140.18 28.840 282.770 1 029.18 1100.86 72.99 N 208.24 W 5999984.08 N 565375.09 E 2.592 72.99 1236.07 30.760 284.360 1112.39 1184.07 84.19 N 254.56 W 5999994.87 N 565328.67 E 2.165 84.19 1332.87 34.260 283.510 1194.01 1265.69 96.70 N 305.05 W 6000006.94 N 565278.08 E 3.646 96.70 1429.41 38.320 284.210 1271.81 1343.49 110.40N 360.50 W 6000020.15 N 565222.50 E 4.227 110.40 1525.08 41.420 284.280 1345.22 1416.90 125.49 N 419.94 W 6000034.72 N 565162.93 E 3.241 125.49 1620.55 41.410 284.010 1416.82 1488.50 140.92 N 481.18 W 6000049.61 N 565101.56 E 0.187 140.92 1717.06 45.050 283.430 1487.13 1558.81 156.59 N 545.39 W 6000064.71 N 565037.22 E 3.794 156.59 1813.46 44.520 285.110 1555.55 1627.23 173.32 N 611.20 W 6000080.87 N 564971.26 E 1.345 173.32 1909.59 47.010 286.140 1622.61 1694.29 191.88 N 677.52 W 6000098.85 N 564904.78 E 2.702 191.88 2006.46 51.900 286.500 1685.56 1757.24 212.57 N 748.14 W 6000118.91 N 564833.98 E 5.056 212.57 2100.78 53.850 287.540 1742.48 1814.16 234.59 N 820.04 W 6000140.30 N 564761.89 E 2.247 234.59 . 2195.99 52.980 287.820 1799.23 1870.91 257.80 N 892.88 W 6000162.87 N 564688.85 E 0.944 257.80 2293.26 58.960 286.650 1853.64 1925.32 281.65 N 969.84 W 6000186.04 N 564611.68 E 6.228 281.65 2389.32 64.200 286.210 1899.34 1971.02 305.53 N 1050.85 W 6000209.21 N 564530.47 E 5.470 305.53 2485.47 67.560 288.370 1938.63 2010.31 331.63 N 1134.61 W 6000234.57 N 564446.48 E 4.051 331.63 2581.44 69.890 291.090 1973.46 2045.14 361.83 N 1218.77 W 6000264.03 N 564362.06 E 3.587 361.83 2677.91 71.640 294.240 2005.25 2076.93 396.93 N 1302.80 W 6000298.40 N 564277.72 E 3.577 396.93 2773.79 73.720 298.700 2033.80 2105.48 437.73 N 1384.70 W 6000338.48 N 564195.47 E 4.942 437.73 2868.81 74.810 301.580 2059.57 2131.25 483.66 N 1463.78 W 6000383.70 N 564115.99 E 3.135 483.66 2962.92 75.390 303.030 2083.77 2155.45 532.26 N 1540.65 W 6000431.63 N 564038.70 E 1.611 532.26 3060.38 75.130 296.280 2108.60 2180.28 578.87 N 1622.50 W 6000477.52 N 563956.44 E 6.703 578.87 3155.80 74.430 299.870 2133.66 2205.34 622.18 N 1703.72 W 6000520.12 N 563874.84 E 3.704 622.18 3252.28 74.490 296.940 2159.51 2231.19 666.40 N 1785.48 W 6000563.61 N 563792.70 E 2.927 666.40 3347.97 76.030 296.160 2183.85 2255.53 707.76 N 1868.26 W 6000604.24 N 563709.56 E 1.792 707.76 7 October, 2003 - 7:30 Page 20f6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 MWD Your Ref: API 500292317570 Job No. AKMW0002651972, Surveyed: 18 September, 2003 BP EXPLOF?A 7 ION (ALASKA) INC. BPXA Milm; Foint unii Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3443.78 77050 294.670 2206.16 2277.84 747.74 N 1952.41 W 6000643.49 N 563625.05 E 1.850 747.74 3540.02 77.740 298.860 2227 17 2298.85 79003 N 2036.25 W 600068504 N 56354085 E 4.309 790.03 3635.71 76.670 297.380 2248.36 2320.04 834.01 N 2118.54 W 6000728.30 N 56345817 E 1.878 834.01 3731.81 73.990 294.460 2272.70 2344.38 874.65 N 2202.13 W 6000768.20 N 563374.23 E 4.052 874.65 382864 72.040 296.960 2300.99 2372.67 914.81 N 2285.57 W 6000807.63 N 563290.45 E 3.186 914.81 . 3922.92 73.460 295.890 2328.95 2400.63 954.88 N 236620 W 6000846.98 N 563209.47 E 1.856 954.88 4019.72 73.850 287.970 2356.23 2427.91 989.53 N 2452.29 W 6000880.88 N 563123.08 E 7.861 989.53 4115.57 73.330 295.380 238334 2455.02 1023.46 N 2537.66 W 6000914.05 N 563037.41 E 7.435 1023.46 4207.86 72.630 297.010 2410.36 2482.04 1062.41 N 2616.85 W 6000952.31 N 562957.89 E 1.851 1062.41 4308.20 74.230 290.510 2439.00 2510.68 1101.11 N 2704.82 W 6000990.24 N 562869.58 E 6.410 1101.11 4402.98 73.540 285.160 2465.33 2537.01 1128.99 N 2791.46 W 6001017.36 N 562782.70 E 5.471 1128.99 4498.62 75.010 292.600 2491.28 2562.96 1158.78N 2878.49 W 6001046.38 N 562695.41 E 7.644 1158.78 4594.67 75.260 291.900 2515.92 2587.60 1193.93 N 2964.41 W 6001080.77 N 562609.18 E 0.751 1193.93 4690.87 74.700 294.820 2540.86 2612.54 1230.76N 3049.70 W 6001116.86 N 562523.57 E 2.989 1230.76 4786.44 74.750 295.120 2566.03 2637.71 1269.68 N 3133.27 W 6001155.04 N 562439.66 E 0.307 1269.68 4883.75 74.810 297.570 2591.58 2663.26 1311.35 N 3217.41 W 6001195.96 N 562355.16 E 2.430 1311.35 4978.39 75.210 291.980 2616.08 2687.76 1349.64 N 3300.38 W 6001233.52 N 562271.86 E 5.721 1349.64 5074.64 75.190 299.650 2640.70 2712.38 1390.12 N 3384.08 W 6001273.28 N 562187.80 E 7.704 1390.12 5170.84 75.650 302.480 2664.92 2736.60 1438.16 N 3463.82 W 6001320.61 N 562107.65 E 2.887 1438.16 5265.25 74.620 305.170 2689.15 2760.83 1488.95 N 3539.62 W 6001370.73 N 562031 .40 E 2.962 1488.95 5361.26 75.450 302.070 2713.95 2785.63 1540.29 N 3616.85 W 6001421.39 N 561953.73 E 3.237 1540.29 . 5456.75 76.090 296.970 2737.43 2809.11 1585.88 N 3697.36 W 6001466.27 N 561872.81 E 5.220 1585.88 5551.87 76.090 298.350 2760.30 2831.98 1628.74 N 3779.14 W 6001508.41 N 561790.66 E 1 .408 1628.74 5649.12 74.940 295.970 2784.63 2856.31 1671.72 N 3862.91 W 6001550.66 N 561706.52 E 2.648 1671.72 5760.08 72.630 296.450 2815.61 2887.29 1718.77 N 3958.49 W 6001596.87 N 561610.53 E 2.123 1718.77 5835.94 71.590 294.930 2838.92 2910.60 1750.07 N 4023.54 W 6001627.59 N 561545.20 E 2.348 1750.07 5931.68 73.090 295.720 2867.96 2939.64 1789.09 N 4106.00 W 6001665.89 N 561462.41 E 1.753 1789.09 6028.46 74.360 297.600 2895.08 2966.76 1830.78 N 4189.02 W 6001706.84 N 561379.03 E 2.280 1830.78 6124.79 73.480 296.650 2921.77 2993.45 1872.98 N 4271.40 W 6001748.32 N 561296.28 E 1.316 1872.98 6221.35 76.290 293.080 2946.95 3018.63 1912.15 N 4355.96 W 6001786.75 N 561211.38 E 4.605 1912.15 6318.01 77.700 294.830 2968.70 3040.38 1950.39 N 4442.02 W 6001824.23 N 561124.99 E 2.289 1950.39 6413.83 77.330 290.300 2989.43 3061.11 1986.28 N 4528.38 W 6001859.36 N 561038.31 E 4.632 1986.28 6508.44 76.180 294.410 3011.11 3082.79 2021.29 N 4613.54 W 6001893.62 N 560952.85 E 4.400 2021.29 6604.98 75.740 293.670 3034.53 3106.21 2059.44 N 4699.07 W 6001931.02 N 560866.99 E 0.872 2059.44 6701.31 75.080 295.790 3058.80 3130.48 2098.44 N 4783.74 W 6001969.27 N 560781.98 E 2.237 2098.44 7 October, 2003 . 7:30 Page 3 of 6 DriflQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 MWD Your Ref: API 500292317570 Job No. AKMW0002651972, Surveyed: 18 September, 2003 SP EXPLORA TION (ALASKA) INC. BPXA Milne Foint Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 679809 75.470 296.380 3083.40 3155.08 2139.60 N 4867.81 W 6002009.69 ~I 560697.55 E 0.714 2139.60 62.94.59 75.730 295.630 3107.40 3179.08 2180.58 N 4951.81 W 6002049.93 N 560613.19 E 0.800 2180.58 6989.78 75.610 293.590 3130.96 3202.64 2218.98 N 5035.66 W 6002087.60 N 560529.01 E 2.080 2218.98 7086.29 75.750 295.550 3154.83 3226.51 2257.86 N 5120.69 W 6002125.73 N 560443.64 E 1.973 2257.86 718268 74.970 297050 3179.20 3250.88 2299.18 N 5204.30 W 6002166.31 N 560359.67 E 1.709 22991 8 . 7280.25 74.240 297010 3205.10 3276.78 2341.93N 5288.09 W 6002208.33 N 560275.51 E 0.749 2341.93 73iS.67 72.950 296.560 3232.05 3303.73 2383.18 N 5369.80 W 6002248.86 N 560193.44 E 1.426 2383.18 7470.85 71.790 295.750 3260.88 3332.56 2423.17 N 5451.22 W 6002288.13 N 560111 .67 E 1.464 2423.17 7566.87 74.100 296.600 328904 3360.72 2463.66 N 5533.60 W 6002327.89 N 560028.94 E 2.550 2463.66 1663.38 75.390 297.960 3314.43 3386.11 2506.34 N 5616.35 W 6002369.84 N 559945.82 E 1.907 2506.34 7759.08 75.450 297.750 3338.52 3410.20 2549.61 N 5698.23 W 6002412.40 N 559863.56 E 0.221 2549.61 7855.19 75.010 297.300 3363.02 3434.70 2592.56 N 5780.65 W 6002454.62 N 559780.77 E 0.644 2592.56 7951.72 73.980 297.300 3388.83 3460.51 2635.22 N 5863.30 W 6002496.55 N 559697.74 E 1.067 2635.22 8047.53 73.720 298.500 3415.48 3487.16 2678.28 N 5944.63 W 6002538.90 N 559616.04 E 1.233 2678.28 8143.13 72.970 296.890 3442.88 3514.56 2720.85 N 6025.72 W 6002580.75 N 559534.58 E 1.794 2720.85 8239.77 74.820 295.270 3469.69 3541.37 2761.66 N 6109.11 W 6002620.83 N 559450.83 E 2.502 2761.66 8336.00 76.410 295.280 3493.59 3565.27 2801.46 N 6193.40 W 6002659.88 N 559366.20 E 1.652 2801.46 8430.71 75.550 294.070 3516.54 3588.22 2839.82 N 6276.90 W 6002697.51 N 559282.37 E 1.537 2839.82 8527.17 75.200 295.720 3540.90 3612.58 2879.11 N 6361.55 W 6002736.05 N 559197.37 E 1.694 2879.11 8623.72 75.390 295.310 3565.40 3637.08 2919.33 N 6445.83 W 6002775.54 N 559112.74 E 0.455 2919.33 8717.63 75.080 296.350 3589.34 3661.02 2958.90 N 6527.57 W 6002814.38 N 559030.66 E 1.121 2958.90 8811.95 74.690 297.660 3613.93 3685.61 3000.24 N 6608.70 W 6002855.01 N 558949.17 E 1.403 3000.24 . 8908.66 75.200 296.860 3639.05 3710.73 3043.01 N 6691.71 W 6002897.06 N 558865.78 E 0.957 3043.01 9003.59 74.820 295.000 3663.61 3735.29 3083.11 N 6774.18 W 6002936.43 N 558782.97 E 1.935 3083.11 9098.35 75.980 296.350 3687.50 3759.18 3122.84 N 6856.82 W 6002975.43 N 558699.98 E 1.844 3122.84 9195.90 76.810 300.630 3710.45 3782.13 3168.06 N 6940.12 W 6003019.92 N 558616.28 E 4.348 3168.06 9292.49 74.560 310.730 3734.39 3806.07 3222.53 N 7016.06 W 6003073.72 N 558539.88 E 10.395 3222.53 9324.53 72.900 310.190 3743.37 3815.05 3242.49 N 7039.46 W 6003093.47 N 558516.30 E 5.428 3242.49 9356.41 72.380 310.810 3752.88 3824.56 3262.25 N 7062.59 W 6003113.03 N 558492.99 E 2.471 3262.25 9388.29 72.500 312.600 3762.50 3834.18 3282.47 N 7085.28 W 6003133.05 N 558470.13 E 5.366 3282.47 9483.34 71.920 315.110 3791.54 3863.22 3345.17 N 7150.54 W 6003195.17 N 558404.32 E 2.587 3345.17 9579.17 71.530 317.270 3821.60 3893.28 3410.83 N 7213.53 W 6003260.28 N 558340.75 E 2.179 3410.83 9674.90 73.100 319.710 3850.68 3922.36 3479.13 N 7273.97 W 6003328.04 N 558279.72 E 2.930 3479.13 9771.29 75.830 325.240 3876.51 3948.19 3552.76 N 7330.48 W 6003401.17 N 558222.57 E 6.210 3552.76 9867.14 77.690 329.290 3898.47 3970.15 3631.23 N 7380.91 W 6003479.20 N 558171.45 E 4.548 3631.23 7 October, 2003 - 7:30 Page 4 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 MWD Your Ref: API 500292317570 .lcb No. AKMW00026519ï2, Surveyed: 18 SEptember, 2003 BP EXPLORA TlON (ALA5/U) INC. Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. J\z 1111. Depth Depth Northings Eastings Ncrthings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9962.86 78.880 334 720 3917.92 398960 3713.96 N 742488 IN 6003561.53 N 558126.76 E 5.692 3713.96 10058.20 82.140 338.970 3933.65 4005.33 3800.39 N 7461.82 IN 6003647.64 N 558089.05 E 5.569 3800.39 10154.30 84.430 A50 3944.89 4016.57 3890.97 N 7491.75 IN 6003737.96 N 558058.33 E 6.144 3890.97 1025088 83.130 347.920 395536 4027.04 3984.19 N 7514.68 IN 6003830.97 N 558034.59 E 3817 3984.19 10347.16 82.820 348.910 3967.13 4038.81 4077.80 N 7533.87 W 600392440 N 558014.58 E 1.070 4077.80 . 10443.32 82.700 351.520 3979.25 4050.93 417179 N 755008 W 6004018.26 N 55799754 E 2.695 4171.79 10539.32 82.630 356.330 3991.52 4063.20 426644 N 7560.15 IN 6004112.81 N 557986.64 E 4.970 426644 10633.66 83.310 359.530 4003.07 4074.75 4360.00 N 7563.53 W 6004206.34 N 557982.43 E 3.443 4360.00 10692.46 82.390 359.080 4010.39 408207 4418.34 N 7564.24 IN 600426467 N 557981.21 E 1.739 4418.34 10754.11 84.000 0.190 4017.69 4089.37 4479.55 N 7564.63 IN 6004325.87 N 557980.29 E 3.165 4479.55 10802.66 87.780 0.890 4021.17 4092.85 4527.96 N 7564.17 W 6004374.29 N 557980.32 E 7.917 4527.96 10853.03 89.570 8.540 4022.34 4094.02 4578.11 N 7560.03 W 6004424.47 N 557984.02 E 15.593 4578.11 10898.93 90.930 16.240 4022.14 4093.82 4622.91 N 7550.19 W 6004469.35 N 557993.46 E 17.035 4622.91 10945.08 88.950 21.970 4022.18 4093.86 4666.49 N 7535.10 W 6004513.07 N 558008.18 E 13.136 4666.49 10995.19 88.390 26.520 4023.35 4095.03 4712.16 N 7514.53 W 6004558.91 N 558028.34 E 9.146 4712.16 11045.76 91.670 32.120 4023.32 4095.00 4756.23 N 7489.78 W 6004603.20 N 558052.70 E 12.832 4756.23 11091.17 92.100 35.370 4021.83 4093.51 4793.96 N 7464.57 W 6004641.15 N 558077.58 E 7.216 4793.96 11142.80 90.860 40.790 4020.49 4092.17 4834.57 N 7432.75 W 6004682.04 N 558109.04 E 10.765 4834.57 11188.07 89.940 46.150 4020.18 4091.86 4867.41 N 7401.62 IN 6004715.15 N 558139.89 E 12.013 4867.41 11235.31 87.900 48.190 4021.07 4092.75 4899.52 N 7366.98 IN 6004747.56 N 558174.24 E 6.106 4899.52 11284.27 89.260 47.850 4022.28 4093.96 4932.26 N 7330.60 IN 6004780.62 N 558210.33 E 2.863 4932.26 . 11334.21 89.880 47.970 4022.65 4094.33 4965.73 N 7293.54 IN 6004814.41 N 558247.10 E 1.265 4965.73 11380.82 89.880 46.700 4022.75 4094.43 4997.32 N 7259.27 IN 6004846.30 N 558281.09 E 2.725 4997.32 11430.92 90.120 46.740 4022.75 4094.43 5031.66 N 7222.80 IN 6004880.97 N 558317.26 E 0.486 5031.66 11476.89 90.860 46.660 4022.36 4094.04 5063.19 N 7189.34 IN 6004912.79 N 558350.44 E 1.619 5063.19 11527.24 91.360 49.780 4021.38 4093.06 5096.73 N 7151.81 IN 6004946.65 N 558387.67 E 6.275 5096.73 11549.80 91.730 47.070 4020.77 4092.45 5111.69 N 7134.94 IN 6004961.76 N 558404.41 E 12.120 5111.69 11617.00 91.730 47.070 4018.75 4090.43 5157.44 N 7085.76 IN 6005007.94 N 558453.19 E 0.000 5157.44 Projected Survey 7 October, 2003 - 7:30 Page 5 of 6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB1 MWD Your Ref: API 500292317570 )ob No. AKMW00026519ì2, Sun eyed: 18 September, 2C03 SF D.PLCFß TfC.N (AL.ASKA) INC. Milne Point Unit BPXA Ail data is in Feel (US Survey) unless otherwise stated. m-ections and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) . Based upon MinirY1!.:rr Curvature type calculations, at a Me2sl.Ired Depth of 1161700fl, The Bottom Hoie Displacement is 8763.97ft., in the Direction of 306.049° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11617.00 4090.43 5157.44N 7085.76 W Projected Survey Survey tool program for MPS-35PB1 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 457.00 0.00 456.67 457.00 11617.00 456.67 Tolerable Gyro 4090.43 MWD Magnetic 7 October, 2003 - 7:30 Page 6 0'6 DrillQuest 3.03.02.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . 303--JLI3 09-0ct-03 Re: Distribution of Survey Data for Well MPS-35 PB2 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,284.27' MD 11,326.00' MD 13,550.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ( -~~~ f'i\v2) Sun rilling Services Milne Point Unit BPXA Milne Point MPS MPS-35PB2 Job No. AKZZ0002651972, Surveyed: 19 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317571 Surface Coordinates: 5999912.92 N, 565583.96 E (70024' 36.7547" N, 149027' 57.4954" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71. 68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft SpE!ïtïtv-su:r, D Ftl L... L.. INS S e R V I c: e s A Halliburton Company DEFINITIVE . . Survey Ref: svy1284 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 Your Ref: API 500292317571 Job No. AKZZ0002651972, Surveyed: 19 September, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Foint Unit L,~'e2:5 S ub~S.Cê: \/ertical Local Coordiratcs Global Coordinates Dogleg Vertical Depth incl. Azirn. Depth Depth Northings Eastings Northings Eastings Rate Section COlTlrne nt (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11284.27 89.260 47.010 4021.90 4093.58 4786.42 N 7425.27 W 6004633.95 N 558116.95 E 4786.42 Tie On Point 11326.00 89.780 46.490 4022.25 4093.93 4815.01 N 7394.88 W 6004662.81 N 558147.09 E 1.762 4815.01 Window Point 11334.1 3 88.080 46.500 4022.41 4094.09 4820.60 N 7388.98 W 6004668.46 N 558152.93 E 20.911 4820.60 11379.89 88.950 48.680 4023.59 4095.27 4851.45 N 7355.21 W 6004699.60 N 558186.43 E 5.128 4851.45 11431.08 87.720 48.860 4025.08 4096.76 4885.18 N 7316.73 W 6004733.66 N 558224.62 E 2.428 4885.18 . 11474.96 87.470 47.040 4026.92 4098.60 4914.54 N 7284.17 W 6004763.31 N 558256.91 E 4.183 4914.54 11526.57 87.530 46.470 4029.17 4100.85 4949.86 N 7246.62 W 6004798.96 N 558294.16 E 1.109 4949.86 11572.27 87.590 45.300 4031 .12 4102.80 4981.65 N 7213.84 W 6004831.03 N 558326.66 E 2.561 4981.65 11623.16 90.370 45.570 4032.02 4103.70 5017.35 N 7177.59 W 6004867.05 N 558362.59 E 5.488 5017.35 11666.89 90.430 45.820 4031.72 4103.40 5047.89 N 7146.30 W 6004897.87 N 558393.61 E 0.588 5047.89 11721.18 90.000 44.600 4031.51 4103.19 5086.14 N 7107.77 W 6004936.45 N 558431.81 E 2.383 5086.14 11764.71 89.940 44.270 4031.54 4103.22 5117.22N 7077.29 W 6004967.80 N 558462.01 E 0.771 5117.22 11812.39 90.000 43.780 4031.56 4103.24 5151.50 N 7044.16 W 6005002.37 N 558494.84 E 1.035 5151.50 11856.68 89.510 42.760 4031.75 4103.43 5183.75 N 7013.80 W 6005034.88 N 558524.91 E 2.555 5183.75 11908.30 89.810 45.200 4032.06 4103.74 5220.89 N 6977.96 W 6005072.34 N 558560.43 E 4.762 5220.89 11955.04 89.320 45.130 4032.41 4104.09 5253.85 N 6944.81 W 6005105.58 N 558593.28 E 1.059 5253.85 12008.07 90.680 47.350 4032.41 4104.09 5290.52 N 6906.52 W 6005142.59 N 558631.26 E 4.909 5290.52 12052.79 90.860 47.270 4031.81 4103.49 5320.84 N 6873.65 W 6005173.20 N 558663.86 E 0.440 5320.84 12101.66 89.810 47.130 4031.53 4103.21 5354.04 N 6837.79 W 6005206.72 N 558699.42 E 2.168 5354.04 12149.18 90.000 47.450 4031.60 4103.28 5386.28 N 6802.87 W 6005239.25 N 558734.05 E 0.783 5386.28 12195.99 89.880 47.180 4031.65 4103.33 5418.01 N 6768.46 W 6005271.29 N 558768.18 E 0.631 5418.01 12245.60 91.170 49.350 4031.20 4102.88 5451.03 N 6731.45 W 6005304.63 N 558804.91 E 5.088 5451.03 . 12293.54 92.350 50.860 4029.73 4101.41 5481.76 N 6694.69 W 6005335.69 N 558841.40 E 3.996 5481.76 12340.90 91.480 48.900 4028.14 4099.82 5512.26 N 6658.49 W 6005366.50 N 558877.32 E 4.526 5512.26 12383.80 90.740 48.800 4027.31 4098.99 5540.49 N 6626.20 W 6005395.01 N 558909.37 E 1.741 5540.49 12437.33 89.940 48.160 4027.00 4098.68 5575.97 N 6586.12 W 6005430.84 N 558949.13 E 1.914 5575.97 12487.35 91.050 47.010 4026.56 4098.24 5609.71 N 6549.19W 6005464.90 N 558985.76 E 3.195 5609.71 12533.60 91 .480 43.170 4025.54 4097.22 5642.35 N 6516.45 W 6005497.83 N 559018.21 E 8.353 5642.35 12584.87 91.610 42.350 4024.16 4095.84 5679.97 N 6481.66 W 6005535.76 N 559052.68 E 1.619 5679.97 12628.95 92.160 42.150 4022.71 4094.39 5712.58 N 6452.03 W 6005568.63 N 559082.01 E 1.328 5712.58 12678.72 91.730 42.140 4021.02 4092.70 5749.47 N 6418.66 W 6005605.80 N 559115.06 E 0.864 5749.47 12723.81 91.300 42.850 4019.83 4091.51 5782.70 N 6388.21 W 6005639.30 N 559145.22 E 1.840 5782.70 12771.67 90.680 44.170 4019.00 4090.68 5817.40 N 6355.26 W 6005674.29 N 559177.86 E 3.047 5817.40 12819.10 89.690 45.050 4018.85 4090.53 5851.17 N 6321.96 W 6005708.35 N 559210.87 E 2.793 5851.17 12869.48 87.960 45.320 4019.88 4091.56 5886.67 N 6286.23 W 6005744.16 N 559246.29 E 3.475 5886.67 7 October, 2003 - 7:24 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 Your Ref: API 500292317571 Job No. AKZZ0002651972, Surveyed: 19 September, 2003 BP EXPLORATION (ALASKA) INC. BPXA Miine Point Unit ;::·sui'ed ~",·):,·-SE.c Vertic2,j L ; Cc:ordinat€"s Gleba! Cc·c:cIinates Dc>;::!e!:; Depth ¡nc¡. J~zìm. ¡::l.;~th DepH'¡ ~~orth¡(ig~ Eastings Northings Eastings Rate Ssc-:.iciI Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12914.22 87.470 45.060 4021.66 4093.34 5918.17 N 6254.51 W 6005775.95 N 559277.72 E 1.240 5918.17 12965.01 87.590 45.230 4023.85 4095.53 5953.96 N 6218.54 W 6005812.05 N 559313.38 E 0.409 5953.96 13009.97 86.730 43.520 4026.08 4097.76 5986.06 N 6187.14 W 6005844.42 N 559344.50 E 4.253 5986.06 13061.45 87.160 43.390 4028.82 4100.50 6023.38 N 6151.78 W 6005882.05 N 559379.53 E 0.873 6023.38 13106.09 87.590 43.070 4030.87 4102.55 6055.87 N 6121.24W 6005914.80 N 559409.78 E 1.200 6055.87 . 13156.28 87.590 42.730 4032.98 4104.66 6092.60 N 6087.10 W 6005951.84 N 559443.59 E 0.677 6092.60 13202.54 87.160 42.660 4035.10 4106.78 6126.57 N 6055.77 W 6005986.07 N 559474.63 E 0.942 6126.57 13252.66 87.040 42.340 4037.63 4109.31 6163.47N 6021.95 W 6006023.27 N 559508.12 E 0.681 6163.47 13298.23 85.300 42.990 4040.68 4112.36 6196.90 N 5991.14 W 6006056.98 N 559538.64 E 4.075 6196.90 13348.04 85.490 42.850 4044.68 4116.36 6233.26 N 5957.33 W 6006093.63 N 559572.13 E 0.473 6233.26 13393.98 84.870 43.430 4048.54 4120.22 6266.66 N 5926.02 W 6006127.31 N 559603.14 E 1.845 6266.66 13444.29 84.190 43.220 4053.33 4125.01 6303.10 N 5891.66 W 6006164.04 N 559637.18 E 1.414 6303.10 13482.82 84.320 43.800 4057.19 4128.87 6330.90 N 5865.27 W 6006192.07 N 559663.33 E 1.535 6330.90 13550.00 84.320 43.800 4063.84 4135.52 6379.15 N 5819.00 W 6006240.73 N 559709.17 E 0.000 6379.15 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) . Based upon Minimum Curvature type calculations, at a Measured Depth of 13550.00ft., The Bottom Hole Displacement is 8634.48ft., in the Direction of 317.629° (True). 7 October, 2003· 7:24 Page 3 of 4 DrillQuest 3.03.02.005 ..... Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 Your Ref: API 500292317571 Job No. AKZZo002651972, Surveyed: 19 September, 2003 BP EXPLORA TlCN (A L/lSI<A) INC. Milne Point Unit BP;/A Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11284.27 11326.00 13550.00 4093.58 4093.93 4135.52 4786.42 N 4815.01 N 6379.15N 7425.27 W 7394.88 W 5819.00 W Tie On Point Window Point Projected Survey . Survey tool proqram for MPS-35PB2 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 457.00 0.00 457.00 456.67 13550.00 456.67 Tolerable Gyro (MPS-35PB1) 4135.52 AK-6 BP _IFR-AK (MPS-35PB1) . 7 October, 2003 - 7:24 Page 4 of 4 DrillQuest 3.03.02.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well MPS-35 PB2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,284.27' MD 11,326.00 I MD 13,550.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager AUachment( s) .~~ ~ y"{'\. ~ 803'-jL}3 09-0ct-03 Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-35PB2 MWD . Job No. AKMW0002651972, Surveyed: 19 September, 2003 Survey Report 7 October, 2003 Your Ref: API 500292317571 Surface Coordinates: 5999912.92 N, 565583.96 E (70024' 36.7547" N, 149027' 57.4954" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 999912.92 N, 65583.96 E (Grid) Surface Coordinates relative to Structure: 55.39 S, 761.56 W (True) Kelly Bushing: 71.68ft above Mean Sea Level Elevation relative to Project V Reference: 71.68ft Elevation relative to Structure: 71.68ft SpE!I"""I"""Y-SUi'! b FH L LI N GSe R V I c: e 5 A Halliburton Company Survey Ref: svy1287 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 MWD Your Ref: API 500292317571 Job No. AKMW0002651972, Surveyed: 19 September, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11284.27 89.260 47.850 4022.28 4093.96 4932.26 N 7330.60 W 6004780.62 N 558210.33 E 4932.26 Tie On Point 11326.00 89.780 46.490 4022.63 4094.31 4960.62 N 7300.00 W 6004809.25 N 558240.68 E 3.489 4960.62 Window Point 11334.13 88.080 47.330 4022.78 4094.46 4966.18 N 7294.06 W 6004814.86 N 558246.57 E 23.323 4966.18 11379.89 88.950 48.670 4023.97 4095.65 4996.79 N 7260.07 W 6004845.76 N 558280.29 E 3.491 4996.79 . 11431.08 87.720 48.690 4025.45 4097.13 5030.57 N 7221.64 W 6004879.88 N 558318.42 E 2.403 5030.57 11474.96 87.470 46.820 4027.30 4098.98 5060.04 N 7189.19 W 6004909.64 N 558350.62 E 4.296 5060.04 11526.57 87.530 46.560 4029.55 4101.23 5095.41 N 7151.67 W 6004945.34 N 558387.82 E 0.517 5095.41 11572.27 87.590 45.900 4031 .49 4103.17 5127.00 N 7118.70 W 6004977.21 N 558420.52 E 1 .449 5127.00 11623.16 90.370 45.450 4032.40 4104.08 5162.54 N 7082.30 W 6005013.08 N 558456.60 E 5.534 5162.54 11666.89 90.430 45.400 4032.09 4103.77 5193.24 N 7051.15 W 6005044.04 N 558487.48 E 0.179 5193.24 11721.18 90.000 44.730 4031.89 4103.57 5231.58 N 7012.72 W 6005082.72 N 558525.57 E 1 .466 5231.58 11764.71 89.940 45.180 4031.91 4103.59 5262.38 N 6981.96 W 6005113.79 N 558556.06 E 1.043 5262.38 11812.39 90.000 43.490 4031.94 4103.62 5296.49 N 6948.64 W 6005148.19 N 558589.08 E 3.547 5296.49 11856.68 89.510 43.140 4032.13 4103.81 5328.71 N 6918.26 W 6005180.68 N 558619.17 E 1.360 5328.71 11908.30 89.810 45.150 4032.43 4104.11 5365.75 N 6882.31 W 6005218.03 N 558654.80 E 3.937 5365.75 11955.04 89.320 45.430 4032.79 4104.47 5398.63 N 6849.10 W 6005251.20 N 558687.72 E 1.207 5398.63 12008.07 90.680 47.990 4032.79 4104.47 5434.99 N 6810.50 W 6005287.90 N 558726.00 E 5.466 5434.99 12052.79 90.860 47.790 4032.19 4103.87 5464.97 N 6777.33 W 6005318.17 N 558758.91 E 0.602 5464.97 12101.66 89.810 47.790 4031.90 4103.58 5497.81 N 6741.13 W 6005351.32 N 558794.81 E 2.149 5497.81 12149.18 90.000 48.330 4031.98 4103.66 5529.57 N 6705.78 W 6005383.39 N 558829.88 E 1.205 5529.57 12195.99 89.880 47.950 4032.03 4103.71 5560.80 N 6670.92 W 6005414.93 N 558864.47 E 0.851 5560.80 . 12245.60 91.170 50.420 4031.57 4103.25 5593.23 N 6633.38 W 6005447.68 N 558901.72 E 5.617 5593.23 12293.54 92.350 51.630 4030.10 4101.78 5623.36 N 6596.13 W 6005478.15 N 558938.71 E 3.525 5623.36 12340.90 91.480 50.300 4028.52 4100.20 5653.17 N 6559.36 W 6005508.28 N 558975.21 E 3.354 5653.17 12383.80 90.740 48.900 4027.69 4099.37 5680.97 N 6526.70 W 6005536.36 N 559007.63 E 3.691 5680.97 12437.33 89.940 48.950 4027.37 4099.05 5716.14N 6486.35 W 6005571.89 N 559047.67 E 1 .497 5716.14 12487.35 91.050 47.740 4026.94 4098.62 5749.39 N 6448.98 W 6005605.46 N 559084.75 E 3.283 5749.39 12533.60 91.480 43.840 4025.92 4097.60 5781.62 N 6415.84 W 6005637.98 N 559117.60 E 8.481 5781.62 12584.87 91.610 42.330 4024.53 4096.21 5819.05 N 6380.83 W 6005675.72 N 559152.28 E 2.955 5819.05 12628.95 92.160 42.380 4023.08 4094.76 5851.61 N 6351.15W 6005708.53 N 559181.67 E 1.253 5851.61 12678.72 91.730 42.630 4021 .40 4093.08 5888.28 N 6317.54 W 6005745.50 N 559214.96 E 0.999 5888.28 12723.81 91.300 42.680 4020.20 4091.88 5921.43 N 6287.00 W 6005778.91 N 559245.20 E 0.960 5921.43 12771.67 90.680 43.970 4019.38 4091.06 5956.24 N 6254.17 W 6005814.01 N 559277.73 E 2.990 5956.24 12819.10 89.690 45.170 4019.22 4090.90 5990.03 N 6220.89 W 6005848.09 N 559310.72 E 3.280 5990.03 12869.48 87.960 45.660 4020.26 4091.94 6025.38 N 6185.01 W 6005883.76 N 559346.28 E 3.569 6025.38 7 October, 2003 - 8:20 Page 2 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 MWD Your Ref: API 500292317571 Job No. AKMW0002651972, Surveyed: 19 September, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12914.22 87.470 45.540 4022.04 4093.72 6056.66 N 6153.07 W 6005915.32 N 559377 .94 E 1.128 6056.66 12965.01 87.590 45.240 4024.23 4095.91 6092.29 N 6116.95 W 6005951.27 N 559413.75 E 0.636 6092.29 13009.97 86.730 43.860 4026.46 4098.14 6124.29 N 6085.45 W 6005983.54 N 559444.97 E 3.613 6124.29 13061.45 87.160 44.260 4029.20 4100.88 6161.24 N 6049.70 W 6006020.80 N 559480.39 E 1.140 6161.24 . 13106.09 87.590 43.840 4031.24 4102.92 6193.29 N 6018.69 W 6006053.12 N 559511 .11 E 1.346 6193.29 13156.28 87.590 43.060 4033.36 4105.04 6229.69 N 5984.21 W 6006089.82 N 559545.28 E 1.553 6229.69 13202.54 87.160 43.020 4035.47 4107.15 6263.47 N 5952.67 W 6006123.87 N 559576.52 E 0.934 6263.4 7 13252.66 87.040 43.330 4038.01 4109.69 6299.97 N 5918.42 W 6006160.68 N 559610.45 E 0.663 6299.97 13298.23 85.300 43.420 4041.05 4112.73 6333.02 N 5887.19 W 6006194.00 N 559641.38 E 3.823 6333.02 13348.04 85.490 43.200 4045.05 4116.73 6369.15 N 5853.14 W 6006230.42 N 559675.12 E 0.583 6369.15 13393.98 84.870 44.260 4048.91 4120.59 6402.22 N 5821.49 W 6006263.78 N 559706.47 E 2.666 6402.22 13444.29 84.190 44.000 4053.71 4125.39 6438.17 N 5786.62 W 6006300.03 N 559741.03 E 1.446 6438.17 13482.82 84.320 44.400 4057.57 4129.25 6465.65 N 5759.90 W 6006327.75 N 559767.51 E 1.087 6465.65 13550.00 84.320 44.400 4064.21 4135.89 6513.42 N 5713.12 W 6006375.92 N 559813.86 E 0.000 6513.42 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Magnetic Declination at Surface is 25.385°(06-Sep-03) . Based upon Minimum Curvature type calculations, at a Measured Depth of 13550.00ft., The Bottom Hole Displacement is 8663.97ft., in the Direction of 318.745° (True). 7 October, 2003 - 8:20 Page 3 of4 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-35PB2 MWD Your Ref: API 500292317571 Job No. AKMW0002651972, Surveyed: 19 September, 2003 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11284.27 11326.00 13550.00 4093.96 4094.31 4135.89 4932.26 N 4960.62 N 6513.42N 7330.60 W 7300.00 W 5713.12 W Tie On Point Window Point Projected Survey . Survey tool program for MPS-35PB2 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 457.00 0.00 457.00 456.67 13550.00 456.67 Tolerable Gyro (MPS-35PB1 MWD) 4135.89 MWD Magnetic (MPS-35PB1 MWD) . 7 October, 2003 - 8:20 Page 4 of 4 DrillQuest 3.03.02.005 · r~ LJ ,. / / I FRANK H. MURKOWSKI, GOVERNOR ¡ j l Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 AI,ASIiA. ORAND GAS CONSERVATION COMMISSION / ! ; 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Mile Point Unit MPS-35 BP Exploration (Alaska), Inc. Pennit No: 203-143 Surface Location: 3248' NSL, 427' WEL, Sec. 12, T12N, RI0E, UM Bottomhole Location: 28' NSL, 142' WEL, Sec. 34, ~RlOE, UM TIll'{ Dear Mr. Archey: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required penn its and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Randy ¿edrich Commissioner BY ORDER OF THE COMMISSION DATED this I' day of August, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section iii Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3248' NSL, 427' WEL, SEC. 12, T12N, R10E, UM ' Top of Productive Horizon: 2378' NSL, 2808' WEL, SEC. 02, T12N, R10E, UM ' Total Depth: IJI'{ 28' NSL, 142' WEL, SEC. 34,~, R10E, UM ' 4b. Location of Well (State Base Plane Coordinates): Surface: X-565584' y-5999913· Zone¡A.SP4 16. Deviated Wells: Kickoff Depth 18.Q¡:1sing . Program Size Casinç¡ 20" 10-3/4" 7-5/8" 5"x4" .. STATE OF ALASKA . ALASKA ~ AND GAS CONSERVATION COrVPllrSSION PERMIT TO DRILL 20 AAC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 14835" TVD 4097' 7. Property Designation: 3'iDld/ 1K ADL 025639__, Þ 8. Land Use Permit: ~1"1 ~qr~ iii Development Oil 0 Multiple Zone o Development Gas iii Single Zone 11. Well Name and Number: MPS-35 12. Field / Pool(s): Milne Point Unit I Schrader Bluff 13. Approximate Spud Date: 09/05/03 9. Acres in Property: 2560 14. Distance to Nearest Property: 2475' 13-112" 9-718" 6-1/8" Weiç¡ht 92# 45.5# 29.7# Lenç¡th 112' 5792' 10843' 4092' 10. KB Elevation Planned = 15. Distance to Nearest Well Within Pool (Height above GL): 72" feet 1910' away from MPS-21 17. Anticipated pressure (see 20 AAC 25.035) Max. Downhole Pressure: 1735' psig. Max. Surface Pressure: 1335' psig Setting Depth QuantitY of Cèmênt Top Bottom (c.f. or sacks) MD TVD MD TVD (íncludinç¡ staç¡e data) Surface Surface 112' 112' 260 sx Arctic Set (Approx.) Surface Surface 5792' 2892' 903 sx Class 'L', 261 sx Class 'G' Surface Surface 10843' 4077' 744 sx Class 'G' 10743' 4070' 14835' 4097' Sand Screen Liner Hole 42" 300 ft Maximum Hole Angle Specifications Grade Couplinç¡ H-40 Weld L-80 BTC-M L-80 BTC-M L-80 BTC 92° 15.5# x 9.5# WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments 181 Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 0 Drilling Fluid Program o Shallow Hazard Analysis 18120 AAC 25.050 Requirements Date: Contact Matt Green, 564-5581 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Signature f"~ A J .. J fA-r~ PhoneS'/¡' C¡-S"ØtP3 Commission Use Only Permit To Drill 1/ I API Number: I Permit Appr?~I=/ Number: ;J..l)3~(...,.3 50-DZ-lf- 2..3J7~-t::c;) Date: 8(10('63 Conditions of Approval: Samples Required 0 Yes 8No Mud Log Required Hydrogen Sulfide Measures 0 Yes ¢No Directional Survey Required Other: ~ S"CD ~..; \ ~O 'Ç> ~~ ~ Prepared By Name/Number: Date Ø¡l¡-zlo ~ Sondra Stewman, 564-4750 I See cover letter for other requirements o Yes ~No ~Yes 0 No Approved By: ~Á Form 10-401 Revised 3/2003) ~~ COMMISSIONER C)RIGlì~AI BY ORDER OF THE COMMISSION Date 8/te/D7 Submit In Duplicate e a Point MPS-35 Well Permit IWell Name: I MPS-35 Drill and Complete Plan Summary I Type of Well (service / producer / injector): 1 Single Lateral Producer ,/ Surface Location: 2032' FNL, (3247' FSL); 427' FEL: (4853' FWL), SEC. 12, T12N, R10E./ E=565584.20· N=5999912.96 (As Staked) 2901' FNL, (2378' FSL): 2808' FEL', (2472' FWL), SEC. 2, T12N, R1 DE· E=557885 N=6004260 Z=4005' TVDss 5252' FNL, (28' FSL)~142' FEL,"'(5138' FWL), SEC, 34, T13N, R10E . E=560530 N=6007210 Z=4025' TVDss Target Location: TOP "NB" Target Location: BHL "NB" Well TD I AFE Number: 1 I Estimated Start Date: 15 Sep 2003 I MD: 114,835 II I TVD: 14,097 I I Rig: 1 Doyon 14 I Operating days to complete: 120.4 I Max Inc: 192 I I KOP: 1300 í I KBE:172 I Well Design (conventional, slim hole, etc.): I Conventional Grass Roots Lateral Producer ./ I Objective: I Schrader NB Sand I Mud Program: 13-1/2" Surface Hole Mud Properties: Density (ppg) I Funnel visc I YP I HTHP 8.6 - 9.0 75 -150 25 - 60 N/A Spud - LSND Freshwater Mud pH API Filtrate I LG Solids 8.5 - 9.5 < 8 < 12 9-7/8" Intermediate Hole Mud Properties: Density (ppg) PV I YP I HTHP 9.0 - 9.3 10 - 20 22 - 28 N/A LSND Freshwater Mud pH API Filtrate I LG Solids 9.0 - 9.5 < 8 < 12 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density (ppg) PV YP I HTHP pH API Filtrate LG Solids 9.4 - 9.6; 10- 15 26 - 30 <10 9.0 - 9.5 4 - 6 < 8 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site -' Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 e Cement Program: _e Point MPS-35 Well Permit Casin~ Size 110-3/4" 45.5-lb/ft L-80 BTC Surface Casing Basis 1175% excess over gauge hole in permafrost interval 40% excess over gauge hole below permafrost Total Cement Volume: 722-bbl Wash 20-bbl water Spacer Lead Tail Temp 50-bbI10.2-lb/gal Alpha Spacer 668-bbl, 903-sx 10.7 Ib/gal Class L - 4.15 fe/sx (cement to surface) 54-bbl, 261-sx 15.8 Ib/gal Prem G - 1.15 fe/sx of tail at 5,292-ft I BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton Casin~ Size 17-5/8 29.7-lb/ft L-80 BTC-M Intermediate Casing Basis 140% excess over gauge hole. Lead 500-ft MD above top of Ugnu. Total Cement Volume: 162-bbl Wash 5-bbl water 13-1/2" Section Open Hole: MWD/GR IFRlCASANDRA Gyro as required Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES PWD IFRlCASANDRA Cased Hole: N/A 6-1/8"Section Open Hole: MWD/GRlRES ABI/PWD IFRlCASANDRA Spacer Lead Temp Evaluation Program: 30-bbl 19.2-lb/gal Alpha Spacer (Alpha) 162-bbl, 744-sx 15.6 Ib/gal Prem G - 1.22 fe/sx (top of lead at 7,892-ft MD) BHST == 80°F from SOR, BHCT 70°F estimated by Halliburton "" '" " 2 e ee Point MPS-35 Well Permit Formation Markers: Formation Tops MDrkb rvDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 2148 1822 Top Ugnu 8392 3577 1522 8.35 Middle Ugnu 9347 3827 1630 8.35 NA 10460 4044 1725 8.35 NB 10691 4067 1735 8.35 ~ CasingITubing Program: Hole Csg WtlFt Grade Conn Burst Collapse Length Top Bottom Size Diam MDrrVDrkb MDrrVDrkb 42-in 20-in* 92# H-40 Weld 1530 520 112-ft 0 112-ft / 112-ft 13-1/2" 10.75-in 45.5# L-80 BTC- 5210 2480 5792-ft 0 5792-ft / M 2892-ft 9-7/8" 7.625-in 29.7# L-80 BTC- 6890 4790 10843-ft 0 1 0843-ft / M 4077-ft 6-1/8" 4.5-in 12.7# L-80 BTC 8440 7500 4092-ft 10743-ft/ 14835- ft / NB 4070-ft 4097-ft *The 20-in casing is insulated Recommended Bit Program: BHA Hole Size 1 2 3 13-1/2" 9-7/8" 6-1/8" Depth (MD) 0-5,792' 5,792' - 10,843' 10,843' - TO Bit Type Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1-1 0 3-12 Mill tooth Mill tooth Secu rity FM2643 3 e . Point MPS-35 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals ./ · Maximum anticipated BHP: 1,735-psi @ 3,995-ft TVDss - Top of NB-sand · Maximum surface pressure: 1 ,335-psi @ surface .I (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 11 .5-lb/gal will be made on the 7-5/8" casing shoe. 90.6-bbl with 9.2-lb/gal mud and FIT of 11.5-lb/gal @ 10-3/4" casing shoe. 9.2-lb/gal NaCI I 6.8-lb/gal Diesel · Integrity test: · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on ./ other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+1- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures ./ · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). 4 e . Point MPS-35 Well Permit Pad Data Sheet · Please read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. ./ Faults · 100 - 120-ft DTW fault in SV sand at 6,500-ft MD · 20 - 40-ft DTSE fault in lower Ugnu at 9,900-ft MD · 5 -15-ft DTW fault in Upper N sand at 10,730-ft MD · 15 - 20-ft DTSW fault in NB lateral at 12,200-ft MD · 30 - 40-ft DTNE fault in NB lateral at 13,200-ft MD Hydrogen Sulfide , · MPS Pad is not designated as an H2S Pad. Anti-collision Issues · None. Distance to Nearest Property · MPS-35 is 2475-ft from the nearest Milne Point property line .r Distance to Nearest Well Within Pool · MPS-35 is 191 O-ft from the NB penetration in MPS-21 , 5 e DRILL & COMPLETION PROCEDURE . Point MPS-35 Well Permit Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 13-1/2" surface hole as per directional plan. 3. Case and cement 1 0-3/4" surface casing. 4. ND diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 9-7/8" hole to land in top of the NB-sand as per directional plan. 7. Case and cement 7-5/8" intermediate casing. Freeze protect 7-5/8" x 10-3/4" annulus. 8. Drill out shoe and 20-ft new formation and perform FIT. 9. Drill 6-1/8" NB-sand lateral as per directional plan. 10. Run 5" uncemented sand screens and hang off 100-ft inside 7-5/8" casing. 11. Displace drilling mud to brine. 12. Run 4-1/2" jet pump completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. ND BOP. 16. Install and test tree. 17. Pull BPV. 18. Test 7-5/8" x 4-1/2" annulus. 19. Freeze protect thru GLM. 20. Install BPV and secure well. 21. RD/MO. 6 TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger ~OPO~l:::lJ GOMPLI::: IIOI\ja. . MP -3~ . .~ 112' 20" 92 Ib/tt, H-40 Welded ~ Insulated Diesel Freeze protect to 500' MD 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 9.5-1~9" KCI wfth oo~"" / inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig! 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi 7.625" Casing Shoe @ 10,843' MD; 4,077' TVD Well Inclination @ Shoe = 79 Degrees DATE REV. BY COMMENTS ~~ ~ ~ III iiiiiii I KB. ELEV =72.0' I Cellar Box ELEV = 38.0' ... 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,200' MD; 1,851' TVD, 13-1/2" hole 4-112", 12.6 Ib/ft, L-BO, IBT-M Coupling aD: 5.2" DriWID: 3.833" Burst: 8,430, 80% 6,744 psi Collaose: 7.500. 80%=6.000 os; .. 10-3/4"@ 5,792' MD, 2,892' TVDrkb 'BIW 1- Wire Phoenix Pressure Gauge (3.850" 10, W/BIW 1- wire down to lower sensor) Phoenix Pressure Gauge (2.840" ID) 7-518" x 4-1/2" Premier Packer ISet @ 10,700' MD 3-1/2" HES 'XN' nipple 2.750" 10 No Go W/RHC ball & rod Wireline Entry Guide 9-7/8" Hole 5" Sand Screen Liner W/Baker HR-ZXP liner hanger -- - - -- - - - - - - -- NB Horizontal 6-1/8" hole 114,835' MD/4,097' TVDI ./ Milne Point Unit WF : MPS-35 API NO: BP : I 4IIÞ I MPS-353t'ð4 I ¡;.33 ¡... 1.32 ~ I ~31i I ~.30 I .29i I .28 I h i ~~ J I .24i I .23 I .22 I .21i I 1?8i I MPU ,.-<1 .18 1 .17 I .16 I .15i I .14 I .13i r I~i ~ I .10 I ------I I ð i I _______ . 7i L · 6 J . 5 _______ I .. ! l Stc - - - 1- --.. ~72 T72 II I · 2 StcT ? /Y, R70e- . 1 T72/y 0---:--:::"7 c. I ' '\ 7t . I r I I I I ~ ~ I I $ I ! J ~({:i< ____ _T_ _ _ _T_ _ _ _T_ _ _ _1_ ~ , ~ / .. , e~ 21 I -Z~ I S-PAD 30 SllE 29 28 )¡ 34 35 ~32 33 H-PAD T13N T12N ~ 2 5 PROJECT 3 NiEA 11 10 Ww 14 13 S';:: 18 17 16 15 "'''' PLANT L 15'00'00" GRID VICINITY MAP N.T.S. LEGEN D ~ AS-STAKED CONDUCTOR EI EXISTING CONDUCTOR MQIES;.. 1. DATE OF SURVEY: JULY 15, 2003. 2. REFERENCE FIELD BOOK: MP03-02 PAGES 1-2. 3. COORDINATES ARE ALASKA STATE PLANE. ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS MPS-35 Y= 5,999,912.96 ~ N= 2,237.00 70'24'36.755" 70.4102097' 38.0' 3,248' FSL ./ X= 565,584.20' E= 6,449.00 149'27'57.488" 149.4659689' 427' FEL " o 7/27/03 ISSUEO FOR INFORMAl1ON NO. DATE REVlSlOO 1m!1 DRAINN: Obp JJC CHECKED: RFA DATE: 6/30/03 DRAWING: MILNE POINT UNIT S-PAD SHEET: FRB03 UPS 08-00 ~ ffi~~[JJœo JOB NO: SCALE: AS-STAKE CONDUCTOR JJC RFA ENGlNEERSN«!LANOSUR'Æ:YQRS WELL MPS-35 1 OF 1 S01W£ST FIRE'IIEED L»IE 1"= 160' BY CHK ANCI+ORAŒ, AlASKA "503 bp 0- A 100 c ::§ o o o .<:: ¡¡. 2000 o " u '€ ;; ë ¡.... 3000 400 COMPANY DETAILS REFERENCE INFORMATION Co-ordinate (NÆ) Rererenœ; Well Centre: Plan MPS-35 (Goon), True North Vertical (TVD) Reference: 72' pre plan RKBE 72.00 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 72' pre plan RKBE 72.00 Calculation Metbod: Minimum Cwvature BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North ElTOr Surface: Elliptical + Casing Wamin¡¡: Method: Rules Based g" ¡'IP ,I I JP I ,!~ '# #', ##' , # ;" o.'f ~ ~O ~ , , ...., ...:"" '/'" /~ c:::> #'/~ " SURVEY PROGRAM Depth Fm Depth To Survey/Plan 34.00 750.00 Planned: MPS-35 wp07 V36 750.00 14835.18 Plarmed:MPS.JSwp01V36 Plan: MPS-35 wp07 (plan MPS-35 (Goon)/MPS-35) Tool Created By: Ken Allen Checked: Date: 7/29/2003 CB-GYRO-SS MWD+IFR+MS Date: Reviewed: Date WELL DETAILS N~ +N/..s +Ef·W Northing Basting Latitude Longitude Slot Plan MPS-35 (Goon) -58.34 ·761.42 5999912.90 565584.20 70024'36.754N 149"27'S7.488W NIA TARGET DETAILS N'''I< TVD +N/-S +E/-W Northing Hasting Sh'P' MPS-35 NBT3 4042.00 573436 -6434.71 6005590.00 559100.00 Point MPS·35 NBT2 4072.00 5199.42 -7019.49 6005050.00 558520.00 Point MPS·35 DD Poly 95% 4072.00 4606.40 -7708.79 6004451.00 557836.00 Polygon MPS-35 NBTi 4077.00 4414.96 ·7661.46 6004260.00 557885.00 Point MPS-35 NBPoly 4077.00 4466.58 -7846.03 6004310.00 557700.00 Polygon MPS-35 NBT4 4087.00 6364.13 ·5829.10 6006225.00 559700.00 Point MPS-35 NBT6 4097.00 7341.90 -4990.41 6007210.00 560530.00 Point MPS-35 NBT5 4102.00 7093.64 ·5192.61 6006960.00 560330.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00· 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 380.00 2.00 285.00 379.98 0.36 -1.35 2.50 285.00 1.06 e 4 1522.86. 42.00 285.00 1418.23 108.93 -406.54 3.50 0.00 318.62 5 2060.29 . 55.44 285.00 1772.00 213.22 -795.74 2.50 0.00 623.67 6 2236.55' 55.44 285.00 1872.00 250.79 -935.95 0.00 0.00 733.55 7 2767.28· 74.72 294.86 2095.02 416.86 -1384.45 4.00 27.14 1123.03 8 9042.81· 74.72 294.86 3748.42 2961.72 -6877.37 0.00 0.00 6315.56 9 10842.52- 87.00 7.00 4077.00 4414.96 -7661.46 4.00 88.18 7958.21 MPS-35 NBT! 10 10862.52. 87.00 7.00 4078.05 4434.78 -7659.03 0.00 0.00 7973.24 11 11189.79. 90.97 46.09 4084.08 4721. 78 -7515.59 12.00 84.79 8129.96 12 11842.77. 90.97 46.09 4073.05 5174.61 -7045.26 0.00 0.00 8240.08 13 11878.57. 92.40 46.09 4072.00 5199.42 -7019.49 4.00 0.18 8246.11 MPS-35 NBT2 14 11920.96 92.40 47.79 4070.22 5228.34 -6988.54 4.00 89.84 8252.63 15 12561.80. 92.40 47.79 4043.35 5658.54 -6514.32 0.00 0.00 8341.83 16 12671.77. 89.00 45.00 4042.00 5734.36 -6434.71 4.00 -140.66 8359.79 MPS-35 NBT3 17 12729.88· 86.95 43.90 4044.05 5775.81 -6394.05 4.00 -151.85 8371.21 18 13492.40· 86.95 43.90 4084.61 6324.45 -5866.04 0.00 0.00 8528.14 19 13546.67 . 88.00 42.00 4087.00 6364.13 -5829.10 4.00 -61.15 8540.19 MPS-35 NBT4 20 13580.63' 89.07 41.16 4087.87 6389.52 -5806.57 4.00 -38.23 8548.52 21 14447.30· 89.07 41.16 4101.98 7041.93 -5236.25 0.00 0.00 8767.48 22 14514.96' 90.89 39.16 4102.00 7093.64 -5192.61 4.00 -47.54 8785.72 MPS-35 NBT5 23 14835.18. 90.89 39.16 4097.00 7341.90 -4990.41 0.00 0.00 8877.36 MPS-35 NBT6 CASING DETAILS FORMA nON TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath F onnation 2892.00 5792.24 103/4" 10.750 1 1822.00 2148.42 BPRF 4077.00 10842.52 7" 7.000 2 3577.00 8392.19 TUlC 4097.00 14835.17 5 screens" 5.000 3 3782.00 9171.12 TUlC-1 4 3792.00 9209.74 TUBl 5 3827.00 9347.11 TUBL 6 3962.00 9943.53 TUBL-3 e All TVD depths are 7 4012.00 10227.60 TUBL-2 8 4044.00 10459.87 SBF2-NA 9 4061.00 10620.92 NAMF ssTVDplus 72'for RKBE. 10 4067.00 10690.96 SBF1-NB 11 4073.00 10774.16 SBFI-NBR 12 4092.00 13834.39 SBE4-NC SBF1-NBR SBFl-NB \ SBF2-NA \ TUBL-2 \ TlII~.-! . . ,^M:\~" \ - . ..... ......."....... _..._...~::::.;...:~~,~" ",:.,,_..... "j. f..,....~ .....,.~_:~.. . ~..,--~:: \1PS-35 wp07 .. ,:,. -; I h,:)\! ~ 5 screens" ItWu:, ./ 4000 Vertical Section at 325.80" [lOOOftlin] 7000 I I I 9000 I t I I t I bp COMPANY DETAILS REFERENCE INFORMA nON BP Amoco Co-ordinate (NÆ) Relèrence: Well Centre: Plan MPS-3S (Goon), True North Vertical (fVD) Reference: 72' pre plan RKBE 72.00 Section (VS) Reference: S]ot· (O.OON,O.OOE) Measured Depth Reference: 72' pre piau RKBE 72.00 Calculation Method: Minimum CuRVature Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptkal + Casing Warnin~ Method: Rules Based 5 screens" 7200 Total Depth: 14835.18' MD, 4097' TVD Dìr : 14514.96' MD, 4102' TVD Dir 41100' : 14447.3' MD,4101.98'TVD .63' MD, 4087.87' TVD 492.4' MD, 4084.61 'TVD (íIWÜ ~11·~1_·1' WI;::::'." ..,.r' :t' ' \11'~-.1< DD I·.);~ '!,"" if- . [:- ,. .... :Etid . iri:'2729:8~'*q; 40,*.05' TVD T-:~~StartDi411~0'.:..lt5~.I:~'·'r1D;4043.35'TVD ~11'~-¡; 'Ill ~ l', r ! ..\) I".: Di, . : >'/:0.1)(,' \ID, -H/ /I ~~' I VD "" "I.II~ 1)11 4 ~111! : II ,~~ ~"II ;"11.). -10"30:' I \'1) .. .~IIII '2' :â 0 0 ~ î 3600 ..<: 1:: 0 ~ J5 :; 0 <JJ 2400 ""..".,.'".", .. ........... . ... ".... ...". ...... .-. - ...-.-.- -.-.-- :'(111) 103/4" , ~~ ..... . -3600 West(-)/East(+) [l200ft/ìn] SURVEY PROORAM Plan: MPS·3S wp07 (plan MPS-35 (Goon)/MPS-35) Depth Fm Depth To SurveylP]an Tool Created By: Ken Allen Date: 7/29/2003 34.00 750.00 Planood: MPS-35 wp07 V36 CB-GYRO-SS Checked: Date:_ 750.00 ]4835.18 Planned: MPS-35 wp07 V36 MWD+IFR+MS Reviewed: Date WELL DETAILS N~ +NI-S +EI-W Northing Easting Latitude Longitude Slot Plan MPS-35 (Goon) -58.34 -761.42 5999912.90 565584.20 70024'36.754N 149°27'57.488W N/A TARGET DETAILS N~ TVD +N/-S +EI-W Northing Basting Shape MPS-35 NETJ 4042.00 5734.36 -6434.71 6005590.00 559]00.00 Point MPS-35 NBTZ 4072.00 5199.42 -70]9.49 6005050.00 558520.00 Point MPS-35 DD Poly 95% 4072.00 6116.96 -592729 6005977.00 559604.00 Polygon MPS-35 NETl 4077.00 4414.96 -7661.46 6004260.00 557885.00 Point MPS-35 NBPo]y 4077.00 4466.58 -7846.03 6004310.00 557700.00 Polygon MPS-35 NBT4 4087.00 6364.13 -5829.10 6006225.00 559700.00 Point MPS-35 NBT6 4097.00 7341.90 4990.41 6007210.00 560530.00 Point MPS-35 NET5 4102.00 7093.64 -5192.61 6006960.00 560330.00 Point SECTION DETAILS See MD Ine Azì TVD +N/-S +E/-W DLeg TFace VSee Target I 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 380.00 2.00 285.00 379.98 0.36 -1.35 2.50 285.00 1.06 e 4 1522.86 42,00 285.00 1418.23 108.93 -406.54 3.50 0.00 318.62 5 2060.29 55,44 285,00 1772. 00 213.22 - 795. 74 2.50 0.00 623.67 6 2236.55 55.44 285,00 1872.00 250,79 -935.95 0.00 0.00 733.55 7 2767.28 74.72 294.86 2095,02 416,86 -1384.45 4.00 27.14 1123.03 8 9042.81 74.72 294.86 3748.42 2961.72 -6877.37 0.00 0,00 6315.56 9 10842.52 87.00 7.00 4077.00 4414,96 -7661.46 4.00 88.18 7958.21 MPS-35 NBTl 10 10862.52 87.00 7.00 4078.05 4434,78 -7659,03 0.00 0.00 7973.24 II 11189.79 90.97 46.09 4084.08 4721.78 -7515.59 12.00 84.79 8129.96 12 11842.77 90.97 46.09 4073,05 5174,61 -7045.26 0.00 0.00 8240.08 13 11878.57 92.40 46,09 4072.00 5199.42 -7019,49 4.00 0.18 8246.11 MPS-35 NBT2 14 11920.96 92.40 47,79 4070,22 5228.34 -6988.54 4.00 89.84 8252.63 15 12561.80 92.40 47.79 4043.35 5658.54 -6514.32 0.00 0.00 8341.83 16 12671.77 89.00 45.00 4042.00 5734.36 -6434.71 4.00 -140.66 8359.79 MPS-35 NBT3 17 12729.88 86.95 43.90 4044.05 5775.81 -6394.05 4.00 -151.85 8371.21 18 13492.40 86.95 43.90 4084.61 6324.45 -5866.04 0.00 0.00 8528.14 19 13546.67 88.00 42.00 4087.00 6364.13 -5829.10 4.00 -61.15 8540.19 MPS-35 NBT4 20 13580.63 89.07 41.16 4087.87 6389.52 -5806,57 4.00 -38.23 8548.52 21 14447.30 89.07 41.16 4101.98 7041.93 -5236.25 0.00 0.00 8767.48 22 14514.96 90.89 39.16 4102.00 7093.64 -5192.61 4.00 -47.54 8785.72 MPS-35 NBT5 23 14835,18 90.89 39.16 4097.00 7341.90 -4990.41 0.00 0.00 8877.36 MPS-35 NBT6 CASING DETAILS FORMATION TOP DETAILS No. TVO MD Name Size No. TVOPath MDPath Formation 2892.00 5792.24 103/4" 10.750 I 1822.00 2148.42 BPRF 4077.00 10842.52 7" 7.000 2 3577.00 8392.19 TUZC 4097.00 14835.17 5 screens" 5.000 3 3782.00 9171.12 TUZC-I 4 3792,00 9209.74 TUBZ 5 3827,00 9347.11 TUBL 6 3962,00 9943.53 TUBL-3 e 7 4012.00 10227.60 TUBL-2 8 4044.00 10459.87 SBF2-NA 9 4061.00 10620.92 NAMF 10 4067.00 10690.96 SBFI-NB II 4073.00 10774,16 SBFI-NBR 12 4092.00 13834.39 SBE4-NC End Dir : 2767,28' MD, 2095.02' TVD Start Dìr 4/1 00' : 2236.55' MD, 1872'TVD End Dir : 2060.29' MD, 1772' TVD Start Dir 2.5/100': 1522.86' MD, 1418.23'TVD Start Dir 3.5/100': 380' MD, 379,98'TVD . Start Dìr 2.5/1 00' : 300' MD, 300'TVD I I I I I I I I -2400 o , I ' 1200 I I I I I -1200 Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M PI S Pad Plan MPS-35 (Goon) MPS-35 e Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M Pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: 0.00 ft 0.00 ft Northing: Easting: Well: Plan MPS-35 (Goon) This is a concept well ... Well Position: +N/-S -58.34 ft Northing: +E/-W -761.42 ft Easting: Position Uncertainty: 0.00 ft Wellpath: MPS-35 Current Datum: Magnetic Data: Field Strength: Vertical Section: 72' pre plan RKBE 5/15/2003 57512 nT Depth From (TVD) ft 34.00 Principal: Yes Plan: MPS-35 wp07 Casing Points MD ft 5792.24 10842.52 14835.17 Formations MD ft 2148.42 8392.19 9171.12 9209.74 9347.11 9943.53 10227.60 10459.87 10620.92 10690.96 10774.16 13834.39 Targets TVD ft 2892.00 4077.00 4097.00 TVD ft 1822.00 3577.00 3782.00 3792.00 3827.00 3962.00 4012.00 4044.00 4061.00 4067.00 4073.00 4092.00 Name I ~:=:~ Diameter in 10.750 7.000 5.000 Formations BPRF TUZC TUZC-1 TUBZ TUBL TUBL-3 TUBL-2 SBF2-NA NAMF SBF1-NB SBF1-NBR SBE4-NC __'._'_'.""". .._ø._ Description Dip. Dir. Hole Size in 12.250 9.875 6.125 TVD ft 4042.00 4072.00 BP KW A Planning Report e Date: 7/29/2003 Time: 09:45:54 Page:· I Co-ordlnate(NE) Reference: Well: Plan MPS-35 (Goon), True North Vertical (TVD) Reference:, .72' pre planRKBE 72.0 Section (VS) Reference: Well (O.OON;O.00E,325.80Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: 5999978.00 ft 566345.00 ft Latitude: 70 24 Longitude: 149 27 North Reference: Grid Convergence: Slot Name: 5999912.90 ft J Latitude: 565584.20 ft . Longitude: Height 72.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Date Composed: Version: Tied-to: Name 103/4" 7" 5 screens" Lithology . .. ..............-..-......--.--- -----...------ Alaska, Zone 4 Well Centre bggm2003 37.329 N 35.171 W True 0.51 deg 70 24 36.754 N 149 27 57.488 W Well Ref. Point 34.00 ft Mean Sea Level 25.50 deg 80.81 deg Direction deg 325.80 7/24/2003 36 From Well Ref. Point .._,,--"-_._-_._- Dip Angle deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 .........................-........-....... ....-......-- .--_.-....... Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 +N/-S ft 5734.36 +EI-W ft -6434.71 Map Map Northing Easting ft ft ø_..__·_h_......_. _...____........ ...........__.... 6005590.00 559100.00 70 2533.124 N 149 31 6.237 W <-- Longitude --> Deg Min Sec 5199.42 -7019.49 6005050.00 558520.00 <-- Latitude ---> Deg Min Sec 70 25 27.857 N 149 31 23.375 W e BP e KW A Planning Report - . Company: BP Amoco Date: 7/29/2003 Time: 09:45:54 Page: 2 . Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-35 (Goon), True North Site: M Pt S Pad Vertical (TVD) Reference: 72' pre plan RKBE 72.0. . Well: Plan MPS~35 (Goon) Section (VS) Reference: Well (0.00N,0.00E,325;80Azi) WelJpath: MPS-35 Survey Calculation Method: Minimum Curvature Db: Oracle . .----.----..-........ Targets Map Map <-- Latitude --> <- Longitude --> Name Deseription TVD .. +N/-S +EI-W Northing .. Eastlng Deg Min See Deg I\'lin See Dip. Dir. ft ft ft ft ft MPS-35 DD Poly 95% 4072.00 6116.96 -5927.29 6005977.00 559604.00 70 25 36.890 N 149 30 51.362 W -Polygon 1 4072.00 4606.40 -7708.79 6004451.00 557836.00 70 25 22.018 N 149 31 43.575 W -Polygon 2 4072.00 5710.32 -6771.97 6005563.00 558763.00 70 25 32.884 N 149 3116.129W -Polygon 3 4072.00 6310.70 -6122.61 6006169.00 559407.00 70 25 38.794 N 149 30 57.096 W -Polygon 4 4072.00 6984.37 -5391.60 6006849.00 560132.00 70 25 45.425 N 149 30 35.666 W -Polygon 5 4072.00 7393.43 -5049.96 6007261.00 560470.00 70 25 49.451 N 149 30 25.651 W -Polygon 6 4072.00 7341.90 -4990.41 6007210.00 560530.00 70 25 48.944 N 149 30 23.903 W -Polygon 7 4072.00 6851.02 -5239.75 6006717.00 560285.00 70 2544.115 N 149 30 31.208 W -Polygon 8 4072.00 6116.96 -5927.29 6005977.00 559604.00 70 25 36.890 N 149 30 51.362 W -Polygon 9 4072.00 5503.71 -6591.76 6005358.00 558945.00 70 25 30.854 N 149 31 10.838 W -Polygon 10 4072.00 4494.13 -7451.74 6004341.00 558094.00 70 25 20.917 N 149 31 36.033 W MPS-35 NBT1 4077.00 4414.96 -7661.46 6004260.00 557885.00 70 25 20.136 N 149 31 42.181 W MPS-35 NBPoly 4077.00 4466.58 -7846.03 6004310.00 557700.00 70 25 20.642 N 149 31 47.596 W -Polygon 1 4077.00 4466.58 -7846.03 6004310.00 557700.00 70 25 20.642 N 149 31 47.596 W -Polygon 2 4077.00 5731.70 -6814.79 6005584.00 558720.00 70 25 33.094 N 149 31 17.386 W -Polygon 3 4077.00 6941.26 -5493.99 6006805.00 560030.00 70 25 45.001 N 149 30 38.669 W -Polygon 4 4077.00 7446.81 -5093.50 6007314.00 560426.00 70 25 49.975 N 149 30 26.930 W -Polygon 5 4077.00 7341.89 -4990.40 6007210.00 560530.00 70 25 48.944 N 149 30 23.903 W -Polygon 6 4077.00 6734.01 -5240.77 6006600.00 560285.00 70 25 42.964 N 149 30 31.236 W -Polygon 7 4077.00 5505.09 -6521.74 6005360.00 559015.00 70 25 30.868 N 149 31 8.784 W -Polygon 8 4077.00 4304.46 -7606.42 6004150.00 557941.00 70 25 19.050 N 149 31 40.564 W MPS-35 NBT4 4087.00 6364.13 -5829.10 6006225.00 559700.00 70 25 39.322 N 149 30 48.487 W MPS-35 NBT6 4097.00 7341.90 -4990.41 6007210.00 560530.00 70 25 48.944 N 149 30 23.903 W MPS-35 NBT5 4102.00 7093.64 -5192.61 6006960.00 560330.00 70 25 46.501 N 149 30 29.830 W Plan Section Information p-.-. ---~_......-~.- MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/1000 deg/1000 deg 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 380.00 2.00 285.00 379.98 0.36 -1.35 2.50 2.50 0.00 285.00 1522.86 42.00 285.00 1418.23 108.93 -406.54 3.50 3.50 0.00 0.00 2060.29 55.44 285.00 1772.00 213.22 -795.74 2.50 2.50 0.00 0.00 2236.55 55.44 285.00 1872.00 250.79 -935.95 0.00 0.00 0.00 0.00 2767.28 74.72 294.86 2095.02 416.86 -1384.45 4.00 3.63 1.86 27.14 9042.81 74.72 294.86 3748.42 2961.72 -6877.37 0.00 0.00 0.00 0.00 10842.52 87.00 7.00 4077.00 4414.96 -7661.46 4.00 0.68 4.01 88.18 MPS-35 NBT1 10862.52 87.00 7.00 4078.05 4434.78 -7659.03 0.00 0.00 0.00 0.00 11189.79 90.97 46.09 4084.08 4721.78 -7515.59 12.00 1.21 11.94 84.79 11842.77 90.97 46.09 4073.05 5174.61 -7045.26 0.00 0.00 0.00 0.00 11878.57 92.40 46.09 4072.00 5199.42 -7019.49 4.00 4.00 0.01 0.18 MPS-35 NBT2 11920.96 92.40 47.79 4070.22 5228.34 -6988.54 4.00 0.01 4.00 89.84 12561.80 92.40 47.79 4043.35 5658.54 -6514.32 0.00 0.00 0.00 0.00 12671.77 89.00 45.00 4042.00 5734.36 -6434.71 4.00 -3.10 -2.53 -140.66 MPS-35 NBT3 12729.88 86.95 43.90 4044.05 5775.81 -6394.05 4.00 -3.53 -1.89 -151.85 13492.40 86.95 43.90 4084.61 6324.45 -5866.04 0.00 0.00 0.00 0.00 13546.67 88.00 42.00 4087.00 6364.13 -5829.10 4.00 1.93 -3.51 -61.15 MPS-35 NBT4 13580.63 89.07 41.16 4087.87 6389.52 -5806.57 4.00 3.14 -2.48 -38.23 14447.30 89.07 41.16 4101.98 7041.93 -5236.25 0.00 0.00 0.00 0.00 14514.96 90.89 39.16 4102.00 7093.64 -5192.61 4.00 2.70 -2.95 -47.54 MPS-35 NBT5 14835.18 90.89 39.16 4097.00 7341.90 -4990.41 0.00 0.00 0.00 0.00 MPS-35 NBT6 e BP e KW A Planning Report --..----------...- . . Company: BP Amoco Date: 7/29/2003 Time: 09:45:54 Page: 3 Field: Milne Point Co-ordlnate(NJt:) Reference: ..... Well:. Plan MPS-35 (Goon), True North Site: ... M PtS Pad Vertical (TVO) Reference: 72' pre plan RKBE 72.0 Well: Plan MPS-35 (Goon) Section (VS) Reference: Well (0.00N,O.00E,325.80Azi) Wellpath: MPS-35 Survey Calculation Method: Minimum Curvature Db: Oracle .....---...-.....-..........-.--........ ..-.--........-.....-........ ...............................--..----..-.---.--... Survey MD Incl Azlm TVO Sys TVO MapN MapE VS otS· TFO Too ft deg deg ft ft ft ft ft deg/100ft deg .--- .-.......... ." ~ - _._-~_..~_....~. ._~,,~ . .._~. 34.00 0.00 0.00 34.00 -38.00 5999912.90 565584.20 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 5999912.90 565584.20 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 5999912.90 565584.20 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 5999912.90 565584.20 0.00 0.00 0.00 CB-GYRO-SS 380.00 2.00 285.00 379.98 307.98 5999913.25 565582.85 1.06 2.50 0.00 CB-GYRO-SS 400.00 2.70 285.00 399.97 327.97 5999913.45 565582.05 1.68 3.50 0.00 CB-GYRO-SS 500.00 6.20 285.00 499.65 427.65 5999915.40 565574.54 7.55 3.50 0.00 CB-GYRO-SS 600.00 9.70 285.00 598.67 526.67 5999918.86 565561.16 18.02 3.50 0.00 CB-GYRO-SS 700.00 13.20 285.00 696.67 624.67 5999923.83 565541.94 33.05 3.50 0.00 CB-GYRO-SS 800.00 16.70 285.00 793.27 721.27 5999930.28 565516.97 52.57 3.50 0.00 MWD+IFR+MS 900.00 20.20 285.00 888.11 816.11 5999938.20 565486.34 76.53 3.50 0.00 MWD+IFR+MS 1000.00 23.70 285.00 980.85 908.85 5999947.56 565450.16 104.82 3.50 0.00 MWD+IFR+MS 1100.00 27.20 285.00 1071.13 999.13 5999958.31 565408.57 137.35 3.50 0.00 MWD+IFR+MS 1200.00 30.70 285.00 1158.62 1086.62 5999970.43 565361.71 173.99 3.50 0.00 MWD+IFR+MS 1300.00 34.20 285.00 1243.00 1171.00 5999983.85 565309.78 214.60 3.50 0.00 MWD+IFR+MS 1400.00 37.70 285.00 1323.94 1251.94 5999998.55 565252.96 259.04 3.50 0.00 MWD+IFR+MS 1500.00 41.20 285.00 1401.14 1329.14 6000014.45 565191.45 307.13 3.50 0.00 MWD+IFR+MS 1522.86 42.00 285.00 1418.23 1346.23 6000018.25 565176.76 318.62 3.50 0.00 MWD+IFR+MS 1600.00 43.93 285.00 1474.68 1402.68 6000031.41 565125.87 358.42 2.50 0.00 MWD+IFR+MS 1700.00 46.43 285.00 1545.17 1473.17 6000049.16 565057.21 412.12 2.50 0.00 MWD+IFR+MS 1800.00 48.93 285.00 1612.49 1540.49 6000067.66 564985.64 468.09 2.50 0.00 MWD+IFR+MS 1900.00 51.43 285.00 1676.53 1604.53 6000086.89 564911.29 526.23 2.50 0.00 MWD+IFR+MS 2000.00 53.93 285.00 1737.15 1665.15 6000106.79 564834.31 586.43 2.50 0.00 MWD+IFR+MS 2060.29 55.44 285.00 1772.00 1700.00 6000119.10 564786.69 623.67 2.50 0.00 MWD+IFR+MS 2100.00 55.44 285.00 1794.53 1722.53 6000127.29 564755.03 648.42 0.00 0.00 MWD+IFR+MS 2148.42 55.44 285.00 1822.00 1750.00 6000137.27 564716.43 678.61 0.00 0.00 BPRF 2200.00 55.44 285.00 1851.26 1779.26 6000147.90 564675.31 710.77 0.00 0.00 MWD+IFR+MS 2236.55 55.44 285.00 1872.00 1800.00 6000155.43 564646.18 733.55 0.00 0.00 MWD+IFR+MS 2300.00 57.70 286.37 1906.96 1834.96 6000169.31 564595.08 774.05 4.00 27.14 MWD+IFR+MS 2400.00 61.30 288.39 1957.70 1885.70 6000194.34 564512.67 841.57 4.00 26.38 MWD+IFR+MS 2500.00 64.93 290.28 2002.92 1930.92 6000223.15 564428.29 913.30 4.00 25.35 MWD+IFR+MS 2600.00 68.58 292.06 2042.38 1970.38 6000255.60 564342.35 988.91 4.00 24.50 MWD+IFR+MS 2700.00 72.25 293.76 2075.90 2003.90 6000291.51 564255.29 1068.02 4.00 23.80 MWD+IFR+MS 2767.28 74.72 294.86 2095.02 2023.02 6000317.55 564196.28 1123.03 4.00 23.23 MWD+IFR+MS 2800.00 74.72 294.86 2103.64 2031.64 6000330.56 564167.53 1150.10 0.00 0.00 MWD+IFR+MS 2900.00 74.72 294.86 2129.99 2057.99 6000370.34 564079.66 1232.84 0.00 0.00 MWD+IFR+MS 3000.00 74.72 294.86 2156.34 2084.34 6000410.12 563991.78 1315.58 0.00 0.00 MWD+IFR+MS 3100.00 74.72 294.86 2182.68 2110.68 6000449.90 563903.91 1398.32 0.00 0.00 MWD+IFR+MS 3200.00 74.72 294.86 2209.03 2137.03 6000489.68 563816.04 1481.07 0.00 0.00 MWD+IFR+MS 3300.00 74.72 294.86 2235.38 2163.38 6000529.45 563728.16 1563.81 0.00 0.00 MWD+IFR+MS 3400.00 74.72 294.86 2261.72 2189.72 6000569.23 563640.29 1646.55 0.00 0.00 MWD+IFR+MS 3500.00 74.72 294.86 2288.07 2216.07 6000609.01 563552.41 1729.29 0.00 0.00 MWD+IFR+MS 3600.00 74.72 294.86 2314.42 2242.42 6000648.79 563464.54 1812.04 0.00 0.00 MWD+IFR+MS 3700.00 74.72 294.86 2340.76 2268.76 6000688.57 563376.67 1894.78 0.00 0.00 MWD+IFR+MS 3800.00 74.72 294.86 2367.11 2295.11 6000728.35 563288.79 1977.52 0.00 0.00 MWD+IFR+MS 3900.00 74.72 294.86 2393.46 2321.46 6000768.12 563200.92 2060.26 0.00 0.00 MWD+IFR+MS 4000.00 74.72 294.86 2419.80 2347.80 6000807.90 563113.05 2143.01 0.00 0.00 MWD+IFR+MS 4100.00 74.72 294.86 2446.15 2374.15 6000847.68 563025.17 2225.75 0.00 0.00 MWD+IFR+MS 4200.00 74.72 294.86 2472.50 2400.50 6000887.46 562937.30 2308.49 0.00 0.00 MWD+IFR+MS 4300.00 74.72 294.86 2498.84 2426.84 6000927.24 562849.43 2391.23 0.00 0.00 MWD+IFR+MS 4400.00 74.72 294.86 2525.19 2453.19 6000967.01 562761.55 2473.98 0.00 0.00 MWD+IFR+MS 4500.00 74.72 294.86 2551.54 2479.54 6001006.79 562673.68 2556.72 0.00 0.00 MWD+IFR+MS 4600.00 74.72 294.86 2577.88 2505.88 6001046.57 562585.80 2639.46 0.00 0.00 MWD+IFR+MS e BP e KW A Planning Report , Company: BP Amoco Date: 7/29/2003 Time: 09:45:54 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-35 (Goon), True North Site: MPtSPad Vertical (TVD) Reference: 72' pre plan RKBE 72.0 Well: Plan MPS-35 (Goon) Section (VS) Reference: Well (0.OON,O.00E,325.80Azi) Wellpath: MPS-35 Survey Calculation Method: . Miriimum Curvature Db: Oracle' .... --.. --- .---...-.. _.n..______._..._......___.._ .................................-.-........-..- Survey MD Incl. Azlm TVD Sys TVD MapN MapE VS .. DLS TFO Too ft deg deg ft It ft ft ft deg/10OO deg _....._..... '_n_._.'_ -.._-- . -...-_.... - ~.~ .., . .._- - .-- ..-- 4700.00 74.72 294.86 2604.23 2532.23 6001086.35 562497.93 2722.20 0.00 0.00 MWD+IFR+MS 4800.00 74.72 294.86 2630.58 2558.58 6001126.13 562410.06 2804.95 0.00 0.00 MWD+IFR+MS 4900.00 74.72 294.86 2656.92 2584.92 6001165.91 562322.18 2887.69 0.00 0.00 MWD+IFR+MS 5000.00 74.72 294.86 2683.27 2611.27 6001205.68 562234.31 2970.43 0.00 0.00 MWD+IFR+MS 5100.00 74.72 294.86 2709.62 2637.62 6001245.46 562146.44 3053.18 0.00 0.00 MWD+IFR+MS 5200.00 74.72 294.86 2735.96 2663.96 6001285.24 562058.56 3135.92 0.00 0.00 MWD+IFR+MS 5300.00 74.72 294.86 2762.31 2690.31 6001325.02 561970.69 3218.66 0.00 0.00 MWD+IFR+MS 5400.00 74.72 294.86 2788.66 2716.66 6001364.80 561882.81 3301.40 0.00 0.00 MWD+IFR+MS 5500.00 74.72 294.86 2815.00 2743.00 6001404.57 561794.94 3384.15 0.00 0.00 MWD+IFR+MS 5600.00 74.72 294.86 2841.35 2769.35 6001444.35 561707.07 3466.89 0.00 0.00 MWD+IFR+MS 5700.00 74.72 294.86 2867.70 2795.70 6001484.13 561619.19 3549.63 0.00 0.00 MWD+IFR+MS 5800.00 74.72 294.86 2894.04 2822.04 6001523.91 561531.32 3632.37 0.00 0.00 MWD+IFR+MS 5900.00 74.72 294.86 2920.39 2848.39 6001563.69 561443.45 3715.12 0.00 0.00 MWD+IFR+MS 6000.00 74.72 294.86 2946.74 2874.74 6001603.47 561355.57 3797.86 0.00 0.00 MWD+IFR+MS 6100.00 74.72 294.86 2973.08 2901.08 6001643.24 561267.70 3880.60 0.00 0.00 MWD+IFR+MS 6200.00 74.72 294.86 2999.43 2927.43 6001683.02 561179.83 3963.34 0.00 0.00 MWD+IFR+MS 6300.00 74.72 294.86 3025.78 2953.78 6001722.80 561091.95 4046.09 0.00 0.00 MWD+IFR+MS 6400.00 74.72 294.86 3052.12 2980.12 6001762.58 561004.08 4128.83 0.00 0.00 MWD+IFR+MS 6500.00 74.72 294.86 3078.47 3006.47 6001802.36 560916.20 4211.57 0.00 0.00 MWD+IFR+MS 6600.00 74.72 294.86 3104.82 3032.82 6001842.13 560828.33 4294.31 0.00 0.00 MWD+IFR+MS 6700.00 74.72 294.86 3131.16 3059.16 6001881.91 560740.46 4377.06 0.00 0.00 MWD+IFR+MS 6800.00 74.72 294.86 3157.51 3085.51 6001921.69 560652.58 4459.80 0.00 0.00 MWD+IFR+MS 6900.00 74.72 294.86 3183.86 3111.86 6001961.47 560564.71 4542.54 0.00 0.00 MWD+IFR+MS 7000.00 74.72 294.86 3210.20 3138.20 6002001.25 560476.84 4625.28 0.00 0.00 MWD+IFR+MS 7100.00 74.72 294.86 3236.55 3164.55 6002041.02 560388.96 4708.03 0.00 0.00 MWD+IFR+MS 7200.00 74.72 294.86 3262.90 3190.90 6002080.80 560301.09 4790.77 0.00 0.00 MWD+IFR+MS 7300.00 74.72 294.86 3289.24 3217.24 6002120.58 560213.22 4873.51 0.00 0.00 MWD+IFR+MS 7400.00 74.72 294.86 3315.59 3243.59 6002160.36 560125.34 4956.26 0.00 0.00 MWD+IFR+MS 7500.00 74.72 294.86 3341.94 3269.94 6002200.14 560037.47 5039.00 0.00 0.00 MWD+IFR+MS 7600.00 74.72 294.86 3368.28 3296.28 6002239.92 559949.59 5121.74 0.00 0.00 MWD+IFR+MS 7700.00 74.72 294.86 3394.63 3322.63 6002279.69 559861.72 5204.48 0.00 0.00 MWD+IFR+MS 7800.00 74.72 294.86 3420.98 3348.98 6002319.47 559773.85 5287.23 0.00 0.00 MWD+IFR+MS 7900.00 74.72 294.86 3447.32 3375.32 6002359.25 559685.97 5369.97 0.00 0.00 MWD+IFR+MS 8000.00 74.72 294.86 3473.67 3401.67 6002399.03 559598.10 5452.71 0.00 0.00 MWD+IFR+MS 8100.00 74.72 294.86 3500.02 3428.02 6002438.81 559510.23 5535.45 0.00 0.00 MWD+IFR+MS 8200.00 74.72 294.86 3526.36 3454.36 6002478.58 559422.35 5618.20 0.00 0.00 MWD+IFR+MS 8300.00 74.72 294.86 3552.71 3480.71 6002518.36 559334.48 5700.94 0.00 0.00 MWD+IFR+MS 8392.19 74.72 294.86 3577.00 3505.00 6002555.04 559253.47 5777.22 0.00 0.00 TUZC 8400.00 74.72 294.86 3579.06 3507.06 6002558.14 559246.60 5783.68 0.00 0.00 MWD+IFR+MS 8500.00 74.72 294.86 3605.40 3533.40 6002597.92 559158.73 5866.42 0.00 0.00 MWD+IFR+MS 8600.00 74.72 294.86 3631.75 3559.75 6002637.70 559070.86 5949.17 0.00 0.00 MWD+IFR+MS 8700.00 74.72 294.86 3658.10 3586.10 6002677 .48 558982.98 6031.91 0.00 0.00 MWD+IFR+MS 8800.00 74.72 294.86 3684.44 3612.44 6002717.25 558895.11 6114.65 0.00 0.00 MWD+IFR+MS 8900.00 74.72 294.86 3710.79 3638.79 6002757.03 558807.24 6197.39 0.00 0.00 MWD+IFR+MS 9000.00 74.72 294.86 3737.14 3665.14 6002796.81 558719.36 6280.14 0.00 0.00 MWD+IFR+MS 9042.81 74.72 294.86 3748.42 3676.42 6002813.84 558681.74 6315.56 0.00 0.00 MWD+IFR+MS 9100.00 74.81 297.23 3763.44 3691.44 6002837.63 558631.96 6363.46 4.00 88.18 MWD+IFR+MS 9171.12 74.95 300.17 3782.00 3710.00 6002870.06 558571.47 6424.58 4.00 87.56 TUZC-1 9200.00 75.02 301.36 3789.48 3717.48 6002884.12 558547.38 6449.85 4.00 86.79 MWD+IFR+MS 9209.74 75.04 301.77 3792.00 3720.00 6002888.97 558539.32 6458.43 4.00 86.48 TUBZ 9300.00 75.30 305.49 3815.11 3743.11 6002936.64 558466.27 6539.22 4.00 86.38 MWD+IFR+MS 9347.11 75.46 307.43 3827.00 3755.00 6002963.40 558429.38 6582.23 4.00 85.42 TUBL e BP e KW A Planning Report Company: BP Amoco Date: 7/29/2003 Time: 09:45:54 .Page: S Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-35 (Goon), True North Site: M PtS Pad Vertical (TVD) Reference: 72' pre planRKBE 72.0 Well: . Plan MPS-35 (Goon) Sel;tion (VS) Reference: Well (O.OON,O.OOE,325.80Azi) Wellpath: MPS-35 Survey Calculation Method: Minimum Curvature Db: Oracle _.__._n_m_n._ Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft. ft ft ft ft .. deg/1000 d_~."_ n_ ...._..~---_. -...-. ....-.--.---...-.--.---..-- 9400.00 75.66 309.61 3840.19 3768.19 6002994.95 558389.03 6631.14 4.00 84.93 MWD+IFR+MS 9500.00 76.08 313.71 3864.62 3792.62 6003058.75 558316.05 6725.15 4.00 84.39 MWD+IFR+MS 9600.00 76.58 317.79 3888.26 3816.26 6003127.73 558247.66 6820.81 4.00 83.39 MWD+IFR+MS 9700.00 77.14 321.86 3911.02 3839.02 6003201.56 558184.22 6917.64 4.00 82.42 MWD+IFR+MS 9800.00 77.76 325.91 3932.76 3860.76 6003279.89 558126.02 7015.17 4.00 81.50 MWD+IFR+MS 9900.00 78.44 329.94 3953.39 3881.39 6003362.32 558073.35 7112.93 4.00 80.62 MWD+IFR+MS 9943.53 78.75 331.69 3962.00 3890.00 6003399.38 558052.22 7155.44 4.00 79.79 TUBL-3 10000.00 79.17 333.95 3972.81 3900.81 6003448.45 558026.47 7210.44 4.00 79.44 MWD+IFR+MS 10100.00 79.96 337.93 3990.92 3918.92 6003537.87 557985.61 7307.23 4.00 79.01 MWD+IFR+MS 10200.00 80.80 341.90 4007.64 3935.64 6003630.14 557950.96 7402.82 4.00 78.29 MWD+IFR+MS 10227.60 81.04 342.99 4012.00 3940.00 6003656.05 557942.51 7428.93 4.00 77.62 TUBL-2 10300.00 81.68 345.85 4022.88 3950.88 6003724.81 557922.69 7496.75 4.00 77.45 MWD+IFR+MS 10400.00 82.59 349.78 4036.57 3964.57 6003821.42 557900.94 7588.56 4.00 77.02 MWD+IFR+MS 10459.87 83.16 352.13 4044.00 3972.00 6003880.00 557891.09 7642.33 4.00 76.48 SBF2-NA 10500.00 83.54 353.69 4048.65 3976.65 6003919.51 557885.83 7677.81 4.00 76.19 MWD+IFR+MS 10600.00 84.53 357.59 4059.04 3987.04 6004018.58 557877.41 7764.05 4.00 76.01 MWD+IFR+MS 10620.92 84.73 358.41 4061.00 3989.00 6004039.38 557876.50 7781.67 4.00 75.60 NAMF 10690.96 85.44 1.13 4067.00 3995.00 6004109.15 557875.60 7839.54 4.00 75.53 SBF1-NB 10700.00 85.53 1.48 4067.71 3995.71 6004118.16 557875.73 7846.88 4.00 75.29 MWD+IFR+MS 10774.16 86.29 4.35 4073.00 4001.00 6004192.05 557878.85 7905.85 4.00 75.27 SBF1-NBR 10800.00 86.56 5.35 4074.61 4002.61 6004217.76 557880.80 7925.88 4.00 75.06 MWD+IFR+MS 10842.52 87.00 7.00 4077.00 4005.00 6004260.00 557885.00 7958.21 4.00 75.00 MPS-35 NBT1 10862.52 87.00 7.00 4078.05 4006.05 6004279.84 557887.26 7973.24 0.00 0.00 MWD+IFR+MS 10875.00 87.14 8.49 4078.69 4006.69 6004292.20 557888.83 7982.51 12.00 84.79 MWD+IFR+MS 10900.00 87.42 11.48 4079.87 4007.87 6004316.83 557892.94 8000.41 12.00 84.71 MWD+IFR+MS 10925.00 87.70 14.47 4080.94 4008.94 6004341.21 557898.34 8017.39 12.00 84.57 MWD+IFR+MS 10950.00 88.00 17.46 4081..87 4009.87 6004365.28 557905.00 8033.39 12.00 84.44 MWD+IFR+MS 10975.00 88.30 20.45 4082.68 4010.68 6004388.98 557912.90 8048.37 12.00 84.33 MWD+IFR+MS 11000.00 88.60 23.43 4083.36 4011.36 6004412.24 557922.04 8062.29 12.00 84.23 MWD+IFR+MS 11025.00 88.91 26.42 4083.90 4011.90 6004434.99 557932.37 8075.11 12.00 84.15 MWD+IFR+MS 11050.00 89.22 29.40 4084.31 4012.31 6004457.18 557943.87 8086.80 12.00 84.09 MWD+IFR+MS 11075.00 89.53 32.39 4084.59 4012.59 6004478.74 557956.52 8097.32 12.00 84.04 MWD+IFR+MS 11100.00 89.84 35.37 4084.72 4012.72 6004499.61 557970.27 8106.65 12.00 84.01 MWD+IFR+MS 11125.00 90.16 38.35 4084.72 4012.72 6004519.74 557985.08 8114.77 12.00 83.99 MWD+IFR+MS 11150.00 90.47 41.34 4084.58 4012.58 6004539.07 558000.93 8121.64 12.00 83.99 MWD+IFR+MS 11175.00 90.78 44.32 4084.31 4012.31 6004557.55 558017.76 8127.24 12.00 84.01 MWD+IFR+MS 11189.79 90.97 46.09 4084.08 4012.08 6004568.05 558028.16 8129.96 12.00 84.04 MWD+IFR+MS 11200.00 90.97 46.09 4083.91 4011.91 6004575.20 558035.45 8131.68 0.00 0.00 MWD+IFR+MS 11300.00 90.97 46.09 4082.22 4010.22 6004645.17 558106.86 8148.55 0.00 0.00 MWD+IFR+MS 11400.00 90.97 46.09 4080.53 4008.53 6004715.14 558178.27 8165.41 0.00 0.00 MWD+IFR+MS 11500.00 90.97 46.09 4078.84 4006.84 6004785.12 558249.68 8182.27 0.00 0.00 MWD+IFR+MS 11600.00 90.97 46.09 4077.15 4005.15 6004855.09 558321.08 8199.14 0.00 0.00 MWD+IFR+MS 11700.00 90.97 46.09 4075.46 4003.46 6004925.06 558392.49 8216.00 0.00 0.00 MWD+IFR+MS 11800.00 90.97 46.09 4073.77 4001.77 6004995.03 558463.90 8232.86 0.00 0.00 MWD+IFR+MS 11842.77 90.97 46.09 4073.05 4001.05 6005024.96 558494.44 8240.08 0.00 0.00 MWD+IFR+MS 11878.57 92.40 46.09 4072.00 4000.00 6005050.00 558520.00 8246.11 4.00 0.18 MPS-35 NBT2 11900.00 92.40 46.95 4071.10 3999.10 6005064.87 558535.40 8249.56 4.00 89.84 MWD+IFR+MS 11920.96 92.40 47.79 4070.22 3998.22 6005079.18 558550.69 8252.63 4.00 89.88 MWD+IFR+MS 12000.00 92.40 47.79 4066.91 3994.91 6005132.75 558608.70 8263.63 0.00 0.00 MWD+IFR+MS 12100.00 92.40 47.79 4062.71 3990.71 6005200.52 558682.10 8277.55 0.00 0.00 MWD+IFR+MS 12200.00 92.40 47.79 4058.52 3986.52 6005268.29 558755.50 8291.47 0.00 0.00 MWD+IFR+MS 12300.00 92.40 47.79 4054.33 3982.33 6005336.06 558828.90 8305.39 0.00 0.00 MWD+IFR+MS 12400.00 92.40 47.79 4050.13 3978.13 6005403.83 558902.31 8319.31 0.00 0.00 MWD+IFR+MS e BP - KW A Planning Report - ._..0..._...--.....--....-..... ___ Company: BP Amoco Date: 7/29/2003 Time: 09:45:54 Page: 6 Field: Milne Point Co-ordinate(NE) Reference.: Well: Plan MPS-35 (Goon), True North Site: M Pt S Pad Vertical (TVD) Reference: 72' pre plan RKBE 72.0 Well: Plan MPS-35 (Goon) Section (VS) Reference: Well (0.00N,O.00E,325.80Azi) Wellpath: MPS-35 Survey Calculation Method: Minimum Curvature Db: Oracle ........................-.......-..-..--.. Survey MD Incl Azim TVD SysTVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/1000 deg -.... -.... .~..... ..- 12500.00 92.40 47.79 4045.94 3973.94 6005471.60 558975.71 8333.23 0.00 0.00 MWD+IFR+MS 12561.80 92.40 47.79 4043.35 3971.35 6005513.48 559021.07 8341.83 0.00 0.00 MWD+IFR+MS 12600.00 91.22 46.82 4042.14 3970.14 6005539.61 559048.90 8347.47 4.00 219.34 MWD+IFR+MS 12671.77 89.00 45.00 4042.00 3970.00 6005590.00 559100.00 8359.79 4.00 219.31 MPS-35 NBT3 12700.00 88.00 44.47 4042.74 3970.74 6005610.21 559119.68 8365.21 4.00 208.15 MWD+IFR+MS 12729.88 86.95 43.90 4044.05 3972.05 6005631.79 559140.29 8371.21 4.00 208.16 MWD+IFR+MS 12800.00 86.95 43.90 4047.78 3975.78 6005682.67 559188.40 8385.64 0.00 180.00 MWD+IFR+MS 12900.00 86.95 43.90 4053.10 3981.10 6005755.22 559257.00 8406.22 0.00 180.00 MWD+IFR+MS 13000.00 86.95 43.90 4058.42 3986.42 6005827.77 559325.60 8426.80 0.00 180.00 MWD+IFR+MS 13100.00 86.95 43.90 4063.74 3991.74 6005900.31 559394.21 8447.38 0.00 180.00 MWD+IFR+MS 13200.00 86.95 43.90 4069.06 3997.06 6005972.86 559462.81 8467.96 0.00 180.00 MWD+IFR+MS 13300.00 86.95 43.90 4074.38 4002.38 6006045.41 559531.42 8488.54 0.00 180.00 MWD+IFR+MS 13400.00 86.95 43.90 4079.69 4007.69 6006117.96 559600.02 8509.12 0.00 180.00 MWD+IFR+MS 13492.40 86.95 43.90 4084.61 4012.61 6006185.00 559663.41 8528.14 0.00 180.00 MWD+IFR+MS 13500.00 87.10 43.64 4085.00 4013.00 6006190.52 559668.61 8529.72 4.00 298.85 MWD+IFR+MS 13546.67 88.00 42.00 4087.00 4015.00 6006225.00 559700.00 8540.19 4.00 298.86 MPS-35 NBT4 13580.63 89.07 41.16 4087.87 4015.87 6006250.58 559722.30 8548.52 4.00 321.77 MWD+IFR+MS 13600.00 89.07 41.16 4088.18 4016.18 6006265.28 559734.92 8553.42 0.00 0.00 MWD+IFR+MS 13700.00 89.07 41.16 4089.81 4017.81 6006341.12 559800.06 8578.68 0.00 0.00 MWD+IFR+MS 13800.00 89.07 41.16 4091.44 4019.44 6006416.97 559865.19 8603.95 0.00 0.00 MWD+IFR+MS 13834.39 89.07 41.16 4092.00 4020.00 6006443.05 559887.59 8612.64 0.00 0.00 SBE4-NC 13900.00 89.07 41.16 4093.07 4021.07 6006492.81 559930.33 8629.21 0.00 0.00 MWD+IFR+MS 14000.00 89.07 41.16 4094.70 4022.70 6006568.66 559995.47 8654.48 0.00 0.00 MWD+IFR+MS 14100.00 89.07 41.16 4096.32 4024.32 6006644.51 560060.60 8679.74 0.00 0.00 MWD+IFR+MS 14200.00 89.07 41.16 4097.95 4025.95 6006720.35 560125.74 8705.00 0.00 0.00 MWD+IFR+MS 14300.00 89.07 41.16 4099.58 4027.58 6006796.20 560190.88 8730.27 0.00 0.00 MWD+IFR+MS 14400.00 89.07 41.16 4101.21 4029.21 6006872.04 560256.02 8755.53 0.00 0.00 MWD+IFR+MS 14447.30 89.07 41.16 4101.98 4029.98 6006907.92 560286.82 8767.48 0.00 0.00 MWD+IFR+MS 14500.00 90.49 39.60 4102.18 4030.18 6006948.35 560320.61 8781.49 4.00 312.46 MWD+IFR+MS 14514.96 90.89 39.16 4102.00 4030.00 6006960.00 560330.00 8785.72 4.00 312.47 MPS-35 NBT5 14600.00 90.89 39.16 4100.67 4028.67 6007026.39 560383.11 8810.05 0.00 0.00 MWD+IFR+MS 14700.00 90.89 39.16 4099.11 4027.11 6007104.46 560445.57 8838.67 0.00 0.00 MWD+IFR+MS j 14800.00 90.89 39.16 4097.55 4025.55 6007182.53 560508.02 8867.29 0.00 0.00 MWD+IFR+MS 14835.18 90.89 39.16 4097.00 4025.00 6007210.00 560530.00 8877.36 0.00 0.00 MPS-35 NBT6 p055114 DATE 7/14/2003 INV# PR071003D INVOICE I CREDIT MEMO fY1 p;S - ) rs THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: TO THE ORDER OF: e DESCRIPTION PERMIT TO DRill FEE ~ ",.",,~ TOTAL"~' 8.··P. t:.~ '3~ t~) t")() f::::11 . . . .. .:J .JL. 'lU' \itl· _1.11< n ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUIT~ 100 ANCHORAGE, AK 99501-3539 GROSS NATIONAL CITY BANK Ashland, Ohio. e DATE I I 7/14/2003 CHECK NO. 055114 VENDOR DISCOUNT NET 56-389 412 No. P 0 5 5114 CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT July14, 2003 1..1 ***1'***$100.00*******1 'OT ,^UD ¡.'Y~ :~.~~':.,".,,,,....:.'0""i"""''''';;:': ~ ,;ii?·:';i.':é:~;":\1t~j~~:i::~ II' 0 5 5 ~ . ~ II' I: 0 ~ ¡. 20 j 8 Ii 51: 0 ¡, 2 ? 8 Ii b tI' e e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡11 ¡; a 5" -- 3~ PTD# 2-0:3 - /y3 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new weUbore segment of existing weD Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~ Public Commissioner Date 4,""--'f~-n ~ ~~Vì Geologic Commissioner: Date: Engineering Commissioner: Date Appr SFD Date 8/13/2003 35 36 37 38 39 Conta_ct namelphQneJQrweßlsly progress reports [e¡<pIQrç¡tory _only] Pem)it _D_ata_ presßlJted Qn_ pote_ntial oyeJRres_surß _zone:> Seismic_analysJs_ of :>haJIQW gas_zolJes_ _Seç¡bed JX>I1ditioo survey (if Qff-shore) Yes Yes NA NA NA EXPßcted_ reservoir pre,SSUJe i,S8,35 ppg EMW; wiJl be drJIIßd with 9.4 - 9.6 ppg_rlJUd~ Geology Appr Date ~412003 ~\\'-\ 21 22 23 24 25 26 27 28 29 30 31 32 33 34 cao be issued wlo_ hydmgen_s_ulfide measure:> Js presence_ of MechaniealcolJdJtion o{ to _(puJ psig in _comments) _ChokerlJanjfQld compJies W/APIRF'-53 (May 84) Worls will Occur withoutoperç¡tion _sbutdown _ROPEs, _ dO they meet reguJation BOPEpress raJiog appropriate; Jest Itdiver:ter required, doe:> itmeet reguJations_ DrillilJg fluid. PJogram sc.hematic_&_ equip Jistadequate C, re_serye pit Ita_ re-drilt bas a 10-403 for abandQnment Adequate well bore_ separation proposed beelJ approved Mequate Janj<ç¡ge OJ _Casiog de_sigos adequaJe for T~ B _&_ perrlJafmst _Coodu_ctor string_providßd _S_urface _easing pJotects allknQwn USDWs _CMT vol adequate_ to çirc_ulate_on _cond_uctor_ CMT vol adequ_ate_ to tie-in _CMT will coyer aJl known productive bori;zQn,S 18 19 20 long _string to_surf çsg_ & SUJtq¡g H2S gas prQb_able wells wiJhin';Og verified (For_s_ervice wßIJ QnJy) Yes NA Yes No No Yes Yes NA Yes Yes Yes Yes Yes _Yes Yes No_ NA CalcuJaJedMASP_ 1335 psi. Plç¡nned BOP test press_ure_3_500 psJ Expßcted BHF' 8.35 EMW~ PJanoed_rlJud_weJghts_9A - 9.6 within tbe sa_nd. Proximity_ analysis performe_d No ~Iose approach_ issues identified. GyrosaYailable {or mç¡gnetic. ioterferance gig ise_quippe_dwitb :>teelpits. No reserve. pjt planne_d, All wç¡ste toClas:> welJ(s). Sc.ree_ned ÇQmpJeJiQn p1an_nßd. .;It aquifeJs exempted 40 em H 7_.102(b )(3), Engineering -- 8/13/2003 12 13 14 15 16 17 All wßlJs within 114 rlJileareaof review idelJtifißd (For service well only) Pre-produ_ced iojectQr; duratio_n_of prß-proJ:!uc.tion less_ tban_ 3 months (FQr ACMP findjngof Con_si,SteocyhJ3S bee_n Jssued_ for_ tbis proiect service well only) C_ao permit WellJoeated within area and_stratç¡ autborized bYlojectiolJ Ordßr # (put 10# in3x>mmeots) (For Appr Date Hjk...n.. r'. 't/'\. ~-;..'.{".'.".'. :'.. ~.... ... .!'""'~-trt:;,·J;:>, PTD#: 2031430 Administration -t!ttti1;¿'~^" Field Company BP EXPLOI ..ASKA) Permit fee atta _Lßase_number _u.."'.......JI~'u_ _ _ n_ame _and oumb_er 2 3 4 5 6 7 8 9 10 11 be apPJoved before 15-day waJt administrati\.'e _approyaJ is_ weJ I bore plç¡tincJuJ:!ed _Oper_ator Only affectßd party _ _ _Oper_ator bas_appropriate_ b.ond in Jorce conserva_tiQn order Well Well Wen _Sufficient Itdßyiated, acrßageayailable in_drilJiog unit oeated ina defineJ:!pool Joeated proper _distaoœ from driJliog unit oeated proper _distance from otheJ wells _Unique well ""nn"nn~p"'o. MILNE POINT, SCHRADER BLFF OIL - 525140 Permit cao be issued wjtbout Pe01Jit cao be issued wjtbout NC b_oundary Initial ClasslType Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA Surface locaJiQn andJop_ prQct iotervalJn ';DL 380109; TD hADLO_25639 Well Name: MILNE PT UNIT SB DEV I PEND GeoArea 890 S-35 Unit 11328 Program DEV On/Off Shore On Wen Annular Disposal bore seg o o e e 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 fìnding 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. Sperry-Sun DJlllkng Services LIS Scan Utility 2903 ·~·I 43 . $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 03 16:04:54 2003 1~'3~ Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-35 500292317500 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 03-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002651972 J. STRAHAN E. VAUGHN MWD RUN 2 MW0002651972 R. FRENCH C. DIXON MWD RUN 3 MW0002651972 C.A. DEMOSKI C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002651972 R. FRENCH C. DIXON MWD RUN 5 MW0002651972 R. FRENCH C. DIXON MWD RUN 6 MW0002651972 R. FRENCH C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3248 427 RECEIVED MSL 0) DEC 082003 71.68 37.90 Alaska Of & Gas Cons. Commi8øion AnCftOl'!ge # WELL CASING RECORD OPEN HOLE CASING DRILLERS ~~~\\\~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 5816.0 10758.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SECTION IS AN OPENHOLE SIDETRACK, EXITING FROM THE MPS-35 PB2 WELLBORE AT 12602'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 - 6 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND AT-BIT-INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER A 10/14/2003 E-MAIL FROM K. COONEY (SIS) , QUOTING AUTHORIZATION FROM MICAELA SMITH (BP EXPLORATION). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 6 REPRESENT WELL MPS-35 WITH API#: 50-029-23175-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14804'MD/4111'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY 1 and clipped curves¡ all bit runs merged. .5000 PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START eTH 68.5 113.0 5806.0 5806.0 5806.0 5806.0 5806.0 STOP DEPTH 14749.5 14804.5 14756.5 14756.5 14756.5 14756.5 14756.5 e # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 6 MERGED MAIN PASS. $ MERGE TOP 68.5 5824.0 8758.0 10760.0 11326.5 12603.0 MERGE BASE 5824.0 8758.0 10760.0 11326.0 12602.5 14804.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 68.5 0.37 9.64 0.26 0.25 0.24 0.09 0.07 Max 14804.5 1859.56 122.18 2000 2000 2000 2000 76.01 Nsam 29473 29384 29363 17902 17902 17902 17902 17902 Mean 7436.5 243.497 64.2385 18.9834 26.905 42.0621 56.4153 1.24169 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .14804.5 First Reading 68.5 113 68.5 5806 5806 5806 5806 5806 Last Reading 14804.5 14804.5 14749.5 14756.5 14756.5 14756.5 14756.5 14756.5 . File Trailer Service name..... ....... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name.......... ...STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 68.5 113.0 STOP DEPTH 5779.0 5824.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 10-SEP-03 Insite 66.37 Memory 5824.0 112.0 5824.0 1.3 77.7 TOOL NUMBER 155790 13.500 112.0 SPUD MUD 9.40 102.0 8.8 400 9.8 MUD MUD MUD MUD AT MEASURED T4IIÞRATURE (MT): AT MAX CIRCULATING TERMPERATURE: FILTRATE AT MT: CAKE AT MT: .000 .000 .000 .000 .~ .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 5824 2946.25 11512 68.5 5824 ROP MWD010 FT/H 4.4 1256.68 264.768 11423 113 5824 GR MWD010 API 9.64 117.85 61.2005 11422 68.5 5779 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .5824 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type........ . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ . 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 5779.5 5806.0 5806.0 5806.0 5806.0 5806.0 5824.5 STOP DEPTH 8721.0 8713.5 8713 .5 8713.5 8713.5 8713.5 8758.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 12-SEP-03 Insite 66.37 Memory 8758.0 5824.0 8758.0 71. 6 77.7 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.20 55.0 9.0 300 6.6 7.500 5.820 8.000 5.000 68.0 89.6 68.0 68.0 Data Record Type....... .4IÞ.......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4IÞ Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5779.5 8758 7268.75 5958 5779.5 8758 ROP MWD020 FT/H 9.42 1859.56 330.627 5868 5824.5 8758 GR MWD020 API 29.66 116.36 72.4065 5884 5779.5 8721 RPX MWD020 OHMM 0.78 2000 9.07774 5816 5806 8713 .5 RPS MWD020 OHMM 0.25 2000 9.54126 5816 5806 8713 .5 RPM MWD020 OHMM 0.88 2000 10.6564 5816 5806 8713.5 RPD MWD020 OHMM 0.09 2000 18.1838 5816 5806 8713.5 FET MWD020 HOUR 0.07 55.27 0.709347 5816 5806 8713.5 First Reading For Entire File......... .5779.5 Last Reading For Entire File.......... .8758 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name......... ... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 3 .5000 # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ . START DEPTH 8714.0 8714.0 8714.0 8714.0 8714.0 8721.5 8758.5 STOP DEPTH 10715.0 10715.0 10715.0 10715.0 10715.0 10722.5 10760.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBjG): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined . 14-SEP-03 Insite 66.37 Memory 10760.0 8758.0 10760.0 71. 5 84.4 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.30 52.0 8.6 300 5.8 6.000 4.160 5.500 4.500 65.0 96.8 65.0 65.0 ~sent value........... 411Þ...... .-999 4IIÞ Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8714 10760 9737 4093 8714 10760 ROP MWD030 FT/H 2.09 1400.27 240.178 4004 8758.5 10760 GR MWD030 API 19.44 116.78 65.0968 4003 8721.5 10722.5 RPX MWD030 OHMM 2.33 78.74 10.0522 4003 8714 10715 RPS MWD030 OHMM 2.3 64.09 10.3266 4003 8714 10715 RPM MWD030 OHMM 2.28 73.72 10.6621 4003 8714 10715 RPD MWD030 OHMM 2.3 1002.83 11.3018 4003 8714 10715 FET MWD030 HOUR 0.08 16.2 0.88336 4003 8714 10715 First Reading For Entire File......... .8714 Last Reading For Entire File.......... .10760 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name.. .... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10715.5 10715.5 10715.5 10715.5 STOP DEPTH 11326.0 11326.0 11326.0 11326.0 RPX GR ROP $ 10715 , 10723. 10760.5 11326.0 11326.0 11326.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 . 18-SEP-03 Insite 66.37 Memory 11326.0 10760.0 11326.0 84.0 92.1 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.20 60.0 9.5 35000 4.8 .080 .050 .200 .140 58.0 96 .6 59.0 59.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD040 API ~ 1 68 8 ~. RPX MWD040 OHMM 1 68 12 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10715.5 11326 11020.8 1222 10715.5 11326 ROP MWD040 FT/H 1. 04 458.2 156.058 1132 10760.5 11326 GR MWD040 API 13.82 118.83 51.2464 1207 10723 11326 RPX MWD040 OHMM 0.26 1757.06 42.752 1222 10715.5 11326 RPS MWD040 OHMM 0.31 2000 91.1561 1222 10715.5 11326 RPM MWD040 OHMM 0.24 2000 304.991 1222 10715.5 11326 RPD MWD040 OHMM 0.16 2000 427.921 1222 10715.5 11326 FET MWD040 HOUR 0.19 76.01 6.51046 1222 10715.5 11326 First Reading For Entire File......... .10715.5 Last Reading For Entire File.......... .11326 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM ROP GR RPS RPD FET RPX $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 11326.5 11326.5 11326.5 11326.5 11326.5 11326.5 11326.5 STOP DEPTH 12602.5 12602.5 12602.5 12602.5 12602.5 12602.5 12602.5 # LOG HEADER DATA DATE LOGGED: 19-5EP-03 SOFTWARE I SURFACE SOFTWARE VERS N: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value............. ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 66.37 Memory 12602.0 11326.0 12602.0 . 84.2 92.4 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.50 55.0 8.5 68000 3.5 .060 .040 .100 .140 60.0 96.6 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11326.5 12602.5 11964.5 2553 11326.5 12602.5 ROP MWD050 FT/H 0.37 488.65 165.936 2553 11326.5 12602.5 GR MWD050 API 26.21 122.18 58.1224 2553 11326.5 12602.5 RPX MWD050 OHMM 6.71 2000 43.2942 2553 11326.5 12602.5 RPS MWD050 OHMM 8.8 2000 65.6564 2553 11326.5 12602.5 RPM MWD050 OHMM 11.91 1751.04 63.3131 2553 11326.5 12602.5 RPD MWD050 OHMM 16.75 2000 85.1506 2553 11326.5 12602.5 FET MWD050 HOUR 0.18 6.73 0.89262 2553 11326.5 12602.5 First Reading For Entire File......... .11326.5 Last Reading For Entire File.......... .12602.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 12603.0 12603.0 12603.0 12603.0 12603.0 12603.0 12603.0 STOP DEPTH 14756.5 14756.5 14756.5 14756.5 14749.5 14804.5 14756.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 22-SEP-03 Insite 66.37 Memory 14804.0 12602.0 14804.0 BIT ROTATING SPEED (RPMAIIÞ HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 85.7 92.7 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.50 54.0 8.5 59000 3.9 .100 .060 .150 .280 59.0 96.6 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12603 14804.5 13703.8 4404 12603 14804.5 ROP MWD060 FT/H 0.79 1437.86 142.683 4404 12603 14804.5 GR MWD060 API 36.27 105.99 67.6155 4294 12603 14749.5 RPX MWD060 OHMM 4.. 1426.28 19.5061 4308 . 12603 14756.5 RPS MWD060 OHMM 4.31 1251.62 24.5613 4308 12603 14756.5 RPM MWD060 OHMM 4.84 153.72 26.4627 4308 12603 14756.5 RPD MWD060 OHMM 5.07 96 .49 27.5391 4308 12603 14756.5 FET MWD060 HOUR 0.22 20.62 1.00569 4308 12603 14756.5 First Reading For Entire File......... .12603 Last Reading For Entire File.......... .14804.5 File Trailer Service name............ .STSLIB.007 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.. ........ .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dr~"'ng Services LIS sca~ility . C)03rJLf3 $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 03 08:09:06 2003 ~þ\ Reel Header Service name............ .LISTPE Date.................... .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. f) .'\ ~ )~f" Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-35 PB1 500292317570 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 03-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002651972 J. STRAHAN E. VAUGHN MWD RUN 2 MW0002651972 R. FRENCH C. DIXON MWD RUN 3 MW0002651972 C.A. DEMOSKI C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002651972 R. FRENCH C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3248 427 RECEIVED 71.68 37.90 DEe 082003 # WELL CASING RECORD OPEN HOLE CASING DRILLERS ,Alaska 011 & Gas Cons. Commiaeion Anchorage ~~~-""'~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 5816.0 10758.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND AT-BIT-INCLINATION (ABI) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER A 10/14/2003 E-MAIL FROM K. COONEY (SIS) , QUOTING AUTHORIZATION FROM MICAELA SMITH (BP EXPLORATION). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL MPS-35 PB1 WITH API#: 50-029-23175-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11617'MD/4090'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 68.5 113.0 5772.0 STOP DEPTH 11562.0 11617 . 5 11569.5 FET RPM RPS RPX $ 5819.. 5819.5 5819.5 5819.5 11326.5 11569.5 11569.5 11569.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 68.5 5824.0 8758.0 10760.0 MERGE BASE 5824.0 8758.0 10760.0 11617.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..... ................ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 11617.5 5843 23099 68.5 11617.5 ROP MWD FT/H 1. 04 1859.56 269.499 23010 113 11617.5 GR MWD API 9.64 118.83 64.3278 22988 68.5 11562 RPX MWD OHMM 0.26 2000 13 .1825 11501 5819.5 11569.5 RPS MWD OHMM 0.25 2000 19.0045 11501 5819.5 11569.5 RPM MWD OHMM 0.24 2000 43.9998 11501 5819.5 11569.5 RPD MWD OHMM 0.09 2000 75.386 11596 5772 11569.5 FET MWD HOUR 0.07 76.01 1. 28296 11015 5819.5 11326.5 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .11617.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 ~aximum Physical Record. .A35 File Type. . . . . . . . . . . . . . . .~ Next File Name......... ..STSLIB.002 Physical EOF File Header Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 68.5 113.0 STOP DEPTH 5779.0 5824.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 10-SEP-03 Insite 66.37 Memory 5824.0 112.0 5824.0 1.3 77.7 TOOL NUMBER 155790 13 .500 112.0 SPUD MUD 9.40 102.0 8.8 400 9.8 .000 .000 .000 .000 .0 78.8 .0 .0 MATRIX: 4IIÞ MATRIX DENSITY: HOLE CORRECTION (IN): 4IIÞ # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 5824 2946.25 11512 68.5 5824 ROP MWD010 FT/H 4.4 1256.68 264.768 11423 113 5824 GR MWD010 API 9.64 117.85 61.2005 11422 68.5 5779 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .5824 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type........ . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 3 header data for each bit run in separate files. 2 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX FET GR ROP $ .5000. START DEPTH 5772.0 5772.0 5772.0 5772.0 5772.0 5779.5 5824.5 STOP DEPTH 8713.5 8713.5 8713.5 8713.5 8713.5 8721.0 8758.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN); # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN . 12-SEP-03 Insite 66.37 Memory 8758.0 5824.0 8758.0 71.6 77.7 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.20 55.0 9.0 300 6.6 7.500 5.820 8.000 5.000 68.0 89.6 68.0 68.0 ~ax frames per record... .4IÞ.... ..Undefined 4IÞ Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5772 8758 7265 5973 5772 8758 ROP MWD020 FT/H 9.42 1859.56 330.627 5868 5824.5 8758 GR MWD020 API 29.66 116.36 72.4065 5884 5779.5 8721 RPX MWD020 OHMM 0.78 2000 9.06455 5884 5772 8713.5 RPS MWD020 OHMM 0.25 2000 9.57851 5884 5772 8713.5 RPM MWD020 OHMM 0.88 2000 13.4095 5884 5772 8713.5 RPD MWD020 OHMM 0.09 2000 29.9165 5884 5772 8713.5 FET MWD020 HOUR 0.07 55.27 1.31248 5884 5772 8713.5 First Reading For Entire File......... .5772 Last Reading For Entire File.......... .8758 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type........ . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type......... . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM 4 header data for each bit run in separate files. 3 .5000 START DEPTH 8714.0 8714.0 8714.0 STOP DEPTH 10715.0 10715.0 10715.0 RPS RPX GR ROP $ 8714.. 8714.0 8721. 5 8758.5 10715.0 10715.0 10722.5 10760.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ........... ..0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 14-SEP-03 Insite 66.37 Memory 10760.0 8758.0 10760.0 71. 5 84.4 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.30 52.0 8.6 300 5.8 6.000 4.160 5.500 4.500 65.0 96.8 65.0 65.0 Name Service Order Units Size Npam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H . 1 68 4 2 . GR MWD030 API 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8714 10760 9737 4093 8714 10760 ROP MWD030 FT/H 2.09 1400.27 240.178 4004 8758.5 10760 GR MWD030 API 19.44 116.78 65.0968 4003 8721.5 10722.5 RPX MWD030 OHMM 2.33 78.74 10.0522 4003 8714 10715 RPS MWD030 OHMM 2.3 64.09 10.3266 4003 8714 10715 RPM MWD030 OHMM 2.28 73.72 10.6621 4003 8714 10715 RPD MWD030 OHMM 2.3 1002.83 11.3018 4003 8714 10715 FET MWD030 HOUR 0.08 16.2 0.88336 4003 8714 10715 First Reading For Entire File......... .8714 Last Reading For Entire File.......... .10760 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header 'Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10715.5 10715.5 10715.5 10715.5 10715.5 10723.0 10760.5 STOP DEPTH 11569.5 11569.5 11569.5 11569.5 11326.5 11562.0 11617.5 # LOG HEADER DATA · DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 18-SEP-03 . Insite 66.37 Memory 11617.0 10760.0 11617.0 84.0 92.1 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.20 60.0 9.5 35000 4.8 .080 .000 .200 .140 58.0 .0 59.0 59.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10715.5 11617.5 11166.5 1805 10715.5 11617.5 ROP MWD040 FT/H 1. 04 719.14 160.313 1715 10760.5 11617.5 GR MWD040 API 13.82 118.83 55.4578 1679 10723 11562 RPX MWD040 OHMM 0.26 1757.06 35.8409 1709 10715.5 11569.5 RPS MWD040 OHMM 0.31 2000 74.1211 1709 10715.5 11569.5 RPM MWD040 OHMM 0.24 2000 241.623 1709 10715.5 11569.5 RPD MWD040 OHMM 0.16 2000 382.04 1709 10715.5 11569.5 FET MWD040 HOUR 0.19 76.01 6.50572 1223 10715.5 11326.5 First Reading For Entire File...... ... .10715.5 Last Reading For Entire File.......... .11617.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name..... . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun DrAIIÞng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 03 13:57:56 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Tape Header Service name.......... . . .LISTPE Date.................... .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA . g)03 ~ J 4..3 ~p~ \ ~ },?-q Scientific Technical Services Scientific Technical Services MPS-35 PB2 500292317571 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 03-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002651972 J. STRAHAN E. VAUGHN MWD RUN 2 MW0002651972 R. FRENCH C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002651972 R. FRENCH C. DIXON MWD RUN 5 MW0002651972 R. FRENCH C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3248 427 71.68 37.90 # WELL CASING RECORD OPEN HOLE CASING DRILLERS R~~ \"{" ~ MWD RUN 3 MW0002651972 C.A. DEMOSKI C. DIXON RECEIVED DEC 08 2003 AJaska on & Gas Coos. Comø'tiMíon Anchorage 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 5816.0 10758.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SECTION IS AN OPENHOLE SIDETRACK, EXITING FROM THE MPS-35 PB1 WELLBORE AT 11326'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2 - 5 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND AT-BIT-INCLINATION (ABI) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER A 10/14/2003 E-MAIL FROM K. COONEY (SIS) , QUOTING AUTHORIZATION FROM MICAELA SMITH (BP EXPLORATION). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 5 REPRESENT WELL MPS-35 PB2 WITH API#: 50-029-23175-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13550'MD/4136'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY 1 and clipped curves¡ all bit runs merged. .5000 PBU TOOL CODE GR ROP RPD FET RPM RPS RPX $ START .H 68.5 113.0 5772.0 5819.5 5819.5 5819.5 5819.5 STOP DEPTH 13495.5 13550.0 13502.5 13502.5 13502.5 13502.5 13502.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 68.5 5824.0 8758.0 10760.0 11326.5 MERGE BASE 5824.0 8758.0 10760.0 11326.0 13550.0 # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value........ ............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 68.5 0.37 9.64 0.26 0.25 0.24 0.09 0.07 Max 13550 1859.56 122.18 2000 2000 2000 2000 76.01 Mean 6809.25 256.115 63.9037 19.0489 27.0328 43.8946 65.4904 1.16639 Nsam 26964 26875 26855 15367 15367 15367 15462 15367 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .13550 First Reading 68.5 113 68.5 5819.5 5819.5 5819.5 5772 5819.5 Last Reading 13550 13550 13495.5 13502.5 13502.5 13502.5 13502.5 13502.5 File Trailer I Service name............. SLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 68.5 113.0 STOP DEPTH 5779.0 5824.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 10-SEP-03 Insite 66.37 Memory 5824.0 112.0 5824.0 1.3 77.7 TOOL NUMBER 155790 13.500 112.0 SPUD MUD 9.40 102.0 8.8 400 9.8 .000 .0 MUD AT MAX CIRCULA~ TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 . .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record,............. Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68.5 5824 2946.25 11512 68.5 5824 ROP MWD010 FT/H 4.4 1256.68 264.768 11423 113 5824 GR MWD010 API 9.64 117.85 61.2005 11422 68.5 5779 First Reading For Entire File......... .68.5 Last Reading For Entire File.......... .5824 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ . 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 5772.0 5772.0 5772.0 5772.0 5772.0 5779.5 5824.5 STOP DEPTH 8713.5 8713.5 8713.5 8713.5 8713.5 8721.0 8758.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 12-SEP-03 Insite 66.37 Memory 8758.0 5824.0 8758.0 71. 6 77.7 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.20 55.0 9.0 300 6.6 7.500 5.820 8.000 5.000 68.0 89.6 68.0 68.0 Data Specification Block~e.....o Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5772 8758 7265 5973 5772 8758 ROP MWD020 FT/H 9.42 1859.56 330.627 5868 5824.5 8758 GR MWD020 API 29.66 116.36 72.4065 5884 5779.5 8721 RPX MWD020 OHMM 0.78 2000 9.06455 5884 5772 8713.5 RPS MWD020 OHMM 0.25 2000 9.57851 5884 5772 8713.5 RPM MWD020 OHMM 0.88 2000 13.4095 5884 5772 8713.5 RPD MWD020 OHMM 0.09 2000 29.9165 5884 5772 8713 .5 FET MWD020 HOUR 0.07 55.27 1.31248 5884 5772 8713.5 First Reading For Entire File......... .5772 Last Reading For Entire File.......... .8758 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/12/03 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 4 header data for each bit run in separate files. 3 .5000 FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPM RPS GR ROP $ START AH 8714.0 8714.0 8714.0 8714.0 8714.0 8721.5 8758.5 STOP DEPTH 10715.0 10715.0 10715.0 10715.0 10715.0 10722.5 10760~0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 . 14-SEP-03 Insite 66.37 Memory 10760.0 8758.0 10760.0 71. 5 84.4 TOOL NUMBER 124724 151812 9.875 5816.0 LSND 9.30 52.0 8.6 300 5.8 6.000 4.160 5.500 4.500 65.0 96.8 65.0 65.0 Depth Units............ .4IIÞ...... 4IIÞ Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8714 10760 9737 4093 8714 10760 ROP MWD030 FT/H 2.09 1400.27 240.178 4004 8758.5 10760 GR MWD030 API 19.44 116.78 65.0968 4003 8721.5 10722.5 RPX MWD030 OHMM 2.33 78.74 10.0522 4003 8714 10715 RPS MWD030 OHMM 2.3 64.09 10.3266 4003 8714 10715 RPM MWD030 OHMM 2.28 73.72 10.6621 4003 8714 10715 RPD MWD030 OHMM 2.3 1002.83 11.3018 4003 8714 10715 FET MWD030 HOUR 0.08 16.2 0.88336 4003 8714 10715 First Reading For Entire File......... .8714 Last Reading For Entire File.......... .10760 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPX RPM FET RPS 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10715.5 10715.5 10715.5 10715.5 10715.5 STOP DEPTH 11326.0 11326.0 11326.0 11326.0 11326.0 GR ROP $ 10723.. 10760.5 11326.0 11326.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 18-SEP-03 Insite 66.37 Memory 11326.0 10760.0 11326.0 84.0 92.1 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.20 60.0 9.5 35000 4.8 .080 .000 .200 .140 58.0 .0 59.0 59.0 Offset o 4 8 Channel 1 2 3 RPX MWD040 OHMM . 1 68 12 4 . RPS MWD040 OHMM 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10715.5 11326 11020.8 1222 10715.5 11326 ROP MWD040 FT/H 1. 04 458.2 156.058 1132 10760.5 11326 GR MWD040 API 13.82 118.83 51.2464 1207 10723 11326 RPX MWD040 OHMM 0.26 1757.06 42.752 1222 10715.5 11326 RPS MWD040 OHMM 0.31 2000 91.1561 1222 10715.5 11326 RPM MWD040 OHMM 0.24 2000 304.991 1222 10715.5 11326 RPD MWD040 OHMM 0.16 2000 427.921 1222 10715.5 11326 FET MWD040 HOUR 0.19 76.01 6.51046 1222 10715.5 11326 First Reading For Entire File......... .10715.5 Last Reading For Entire File.......... .11326 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name... ... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 11326.5 11326.5 11326.5 11326.5 11326.5 11326.5 11326.5 STOP DEPTH 13502.5 13502.5 13502.5 13502.5 13495.5 13550.0 13502.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE 19-5EP-03 SURFACE SOFTWARE VERSAIIÞ DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units....,..... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 66.37 Memory 13550.0 11326.0 13550.0 . 84.2 92.4 TOOL NUMBER 184054 159436 6.125 10758.0 FLO-PRO 9.50 55.0 8.5 68000 3.5 .060 .000 .100 .140 60.0 .0 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 · .st Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11326.5 13550 12438.3 4448 11326.5 13550 ROP MWD050 FT/H 0.37 721.84 175.403 4448 11326.5 13550 GR MWD050 API 26.21 122.18 61.9096 4339 11326.5 13495.5 RPX MWD050 OHMM 4.15 2000 34.4867 4353 11326.5 13502.5 RPS MWD050 OHMM 4.98 2000 48.73 4353 11326.5 13502.5 RPM MWD050 OHMM 5.51 1751.04 47.9492 4353 11326.5 13502.5 RPD MWD050 OHMM 5.99 2000 61.6637 4353 11326.5 13502.5 FET MWD050 HOUR 0.18 6.73 0.871293 4353 11326.5 13502.5 First Reading For Entire File......... .11326.5 Last Reading For Entire File.......... .13550 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ............. . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File