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Home My WebLink About202-009MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 12 Township: 12N Range: 10E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 9453 ft MD Lease No.: ADL 380109 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: O.D. Shoe@ Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 9445 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8,903 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bottom 8967 ft 8149 ft 7.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1657 1583 1557 IA 1646 1626 1618 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jess Hall Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): A slickline tag with bailer used for tag. Returned samall pieces of hard cement in bailer. Cement was tagged high and operator clamed it was be cause of the well being deviated. Then witnessed a passing CMIT -TxIA . January 29, 2025 Bob Noble Well Bore Plug & Abandonment MPU S-21 Hilcorp Alaska LLC PTD 2020090; Sundry 324-122 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0129_Plug_Verification_MPU_S-21_bn 9 9 9 9 9 9 99 9 9 9 9 9999 999 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.10 15:28:23 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,453' 8,954' Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7" x 3-1/2" S-3 Permanent & N/A 8,857' MD/ 4,028' TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 112' 20" 7"9,445' MD N/A 7,240psi4,420'9,445' Length Size Proposed Pools: 112' 112' 9.3# / L-80 / IBT TVD Burst 8,903' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 202-009 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23065-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/1/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT S-21 MILNE POINT SCHRADER BLUFF N/A 4,426' 8,967' 4,087' 932 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:54 pm, Feb 28, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.28 10:16:47 - 09'00' Taylor Wellman (2143) * AOGCC to witness slickline tag TOC ~ 8500' MD and CMIT-TxIA to 1500 psl. * AOGCC to witness TOC in all annuli before grouting annulus voids at surface. Hilcorp to photo document. * AOGCC to witness welded marker plate and Hilcorp to photo document. SFD 2/29/2024 DSR-2/29/24 10-407 MGR25MAR24 Abandon JLC 3/26/2024 Plug and Abandon Well: MPS-21 PTD: 202-009 API: 50-029-23065-00-00 Well Name:MPS-21 API Number:50-029-23065-00-00 Current Status:SI PWI Injector Rig:Eline/Pumping Estimated Start Date:4/1/2024 Estimated Duration:60 days Reg.Approval Reqd? Yes Date Reg. Approval Recvd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:202-009 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Todd Sidoti 907-632-4113 (M) AFE Number:TBD Current Bottom Hole Pressure:1301 psi @ 3690 TVD MPH-17 - Offset well (8/7/21) Max. Anticipated Surface Pressure:932 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.75 @ 8891 MD XN Nipple Brief Well Summary MPS-21 was drilled as a PWI injector in 2002, the well injected until 2005 when it was shut in & a cement squeeze was performed on the perfs leaving TOC @ 8905, the cement was under-reamed down to 8954 CTM leaving multiple fish from the under-reamer in the well. In 2021 the well was perforated in the Schrader NB sands for possible injection, but was never brought online. On 10/1/23 SL rigged up for a subsidence drift, both a 20 and 10 fullbore drift (2.7 OD) sat down at 882, a 2.79 gauge ring made it down to 3800. A 24 arm caliper was run indicating tubing shear buckling at ~870. Notes Regarding Wellbore Condition SL tagged TOC @ 8967 on 4/12/2021. Two open sets of perfs (8927-8937 & 8946-8956) Injectivity of 1 bpm @ 1500 psi on 7/1/21 post perforating. Tubing/Casing obstruction caused by buckling @ ~ 870. 7 casing was cemented with 2 stage cement job (TAM collar @ 987) no cement to surface on either stage. A top job was pumped down to 120 bringing cement to surface. Underreamer parts left on TOC @ PBTD (8967) BHT = 74° F 7 Casing Cement Job Notes 1st stage pumped 828 bbls cement (579 bbl volume w/ 30% washout), no cement returns to surface) 2nd stage from TAM port collar @ 987 pumped 170 bbls cement (60 bbl volume w/ 30% washout) full returns, no cement to surface. Top job down 7 annulus to 120 w/ cement to surface. Objective: To perform a complete P&A of the well per 20 AAC 25.112. We will excavate and cut casings 3 below the original tundra level and install a marker plate. Procedure Fullbore 1. Establish tubing injection rate @ 2500 psi. Slickline 1. Drift and Tag TOC w/ TEL & SB to verify volume from PBTD to tubing tail. 2. Drift for TBG punch. Plug and Abandon Well: MPS-21 PTD: 202-009 API: 50-029-23065-00-00 Fullbore (Reservoir Cement Plug) 1. Establish injectivity 2. Pump 20 bbls of 12-15.8 ppg Class G cement per pump schedule below placing TOC @ ~8500. Cement volume based on PBTD @ 8967. a. 5 bbls methanol. b. 10 bbls fresh water. c. 20 bbls 12-15.8 ppg Class G cement (14 bbls excess) d. 5 bbls freshwater e. Foam ball f. 69 bbls diesel FP (Total 74 bbls displacement, TOC @ ~8500). Slickline (Wait on cement 3 days) 1. AOGCC Witnessed cement tag (est cement top @ 8500) 2. Drift for TBG Punch Fullbore 1. AOGCC Witnessed CMIT-TxIA to 1500 psi Slickline 1. Tubing punch T x IA at ~ 8450 (~50 above cement tag) Fullbore 1. Establish circulation TxI after tubing punch. Fullbore (Surface Cement Plug) 1. Rig up to the tubing. 2. Circulate 290 bbls of seawater followed by 20 bbls of surfactant wash taking returns from the IA. 3. Pump 5 bbl freshwater spacer. 4. Mix 12-15.8 ppg Class G cement. 5. Continue to pump 315 bbls of cement (20 bbls of excess), taking returns from the IA until clean cement returns are seen at surface. Operations 1. Photo document all steps 2. Cut off all casings and wellhead 3 below tundra 3. Top off tubing and annuli with cement if needed 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC b. Permit to Drill Number 202-009 c. Well Name MPS-21 d. API Number - 50-029-23065-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Proposed Schematic AOGCC to witness cement tops before grouting. # PTD# 202-009 Plug and Abandon Well: MPS-21 PTD: 202-009 API: 50-029-23065-00-00 Plug and Abandon Well: MPS-21 PTD: 202-009 API: 50-029-23065-00-00 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38070 T38071 T38072 T38073 T38074 T38075 T38076 10/20/2023 MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type MPU C-04 500292080100 182-126 2/27/2021 Wipestock MPU I-07A 500292260201 221-010 5/8/2021 Perf Record MPU L-06 500292200300 190-010 5/18/2021 Wipestock MPU S-21 500292306500 202-009 6/3/2021 Perf Record MPU F-116 500292365000 219-133 1/25/2020 Perf Record MPU I-19 500292321800 204-135 4/10/2020 CCL Please include current contact information if different from above. eceived By: 07/22/2021 37' (6HW By Abby Bell at 3:14 pm, Jul 22, 2021 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 9,453 feet N/A feet true vertical 4,426 feet 8,954 feet Effective Depth measured 8,967 feet feet true vertical 4,087 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2"9.3# / L-80 / IBT 8,903' 4,051' Packers and SSSV (type, measured and true vertical depth)N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: Hilcorp Alaska LLC measured true vertical Packer S-3 Permanent 7" 8,857' MD / 4,028' TVD WINJ WAG Water-Bbl MD 112' 4,420'9,445' TVD 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data measured 112' Oil-Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-009 50-029-23065-00-00 Plugs ADL0380109 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-234 Authorized Signature with date: David Haakinson dhaakinson@hilcorp.com MILNE PT UNIT S-21 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A Conductor Size Junk Length Production 20" Senior Engineer: Senior Res. Engineer: Collapse N/A 5,410psi Burst N/A 7,240psi N/A 8,857' 4,028' 777-8343 2. Operator Name 112' 9,445' measured Casing Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:05 am, Jun 29, 2021 Chad Helgeson (1517) 2021.06.29 05:06:34 - 08'00' SFD 6/29/2021 RBDMS HEW 6/30/2021 DSR-6/29/21MGR30JUL2021 Well Name Rig API Number Well Permit Number Start Date End Date MP S-21 Eline 50-029-23065-00-00 202-009 6/3/2021 6/3/2021 No operations to report. No operations to report. 6/5/2021 - Saturday No operations to report. 6/8/2021 - Tuesday 6/6/2021 - Sunday No operations to report. 6/7/2021 - Monday 6/4/2021 - Friday No operations to report. 6/2/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/3/2021 - Thursday Well Shut-in on Arrival. SLB E-line Perforating. Initial T/IA = 650/500 PSI. Rig up Eline, Pressure test lubricator to 200/3000 PSI. Gun 1 Perforated Interval = 8946' - 8956', CCL to Top Sho = 3.25', CCL. Stop Depth = 8942.75'. Gun 2 Perforated Interval = 8927' - 8937', CCL Stop Depth = 8923.75'. All Shots fired, pressure remained the same throughout. Rig down Eline. Job Complete, well left Shut-in on Departure. _____________________________________________________________________________________ Revised By: DH 6-18-2021 SCHEMATIC Milne Point Unit Well: MP S-21 Last Completed: 8/19/2002 PTD: 202-009 ` PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size NB 8,930’ 8,934’ 4,066’ 4,069’ 4 7/5/2004 Squeezed 2-1/2” NB 8,927’ 8,937’ 4,065’ 4,070’ 10 6/3/2021 Open 2” NB 8,946’ 8,956’ 4,076’ 4,081’ 10 6/3/2021 Open 2” NE 9,006’ 9,026’ 4,110’ 4,122’ 20 7/5/2004 Squeezed 2-1/2” OA 9,140’ 9,160’ 4,195’ 4,209’ 20 8/18/2002 Squeezed 2-1/2” GENERAL WELL INFO API: 50-029-23065-00-00 Drilled by Nabors 27E - 2/11/2002 Initial Completion by Nabors 4ES - 8/19/2002 Add Perfs - 7/5/2004 Add Perfs – 6/3/2021 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 7" Production 26 / L-80 / BTC 6.276” Surface 9,445’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.3/ L-80 / IBT 2.992” Surface 8,903’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,224’ 3.5” HES ‘X’ Nipple – ID= 2.813 2 8,834’ 3.5” HES ‘X’ Nipple – ID= 2.813 3 8,857’ Baker 7” x 3.5” “S-3” Permanent Packer 4 8,891’ 3.5” HES ‘XN’ Nipple – ID= 2.75” 5 8,902’ WLEG - Bottom @ 8,903’ WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle= 77 deg. @ 3,090’ Hole Angle thru Perfs= 45 - 57 deg. TREE & WELLHEAD Tree 4-1/16”, 5M Wellhead FMC 11” Gen 6 4-1/2” hanger w/4-1/2” TC-II T&B CIW 4” H-profile OPEN HOLE / CEMENT DETAIL 20” insulated 260 sacks Arctic set (approx.) in 42” hole 7” 1,030 sacks LITE plus 328 sacks Class “G” in a 9-7/8” hole, plus 205 sacks LITE and 108 sacks Class C top fill, plus another 96 sacks LITE top fill TD= 9,453’ (MD) / TD =4,426’(TVD) 20” Orig KB Elev.: 73’ / Orig GL Elev.: 39.0’ RKB Elev =34’ (NABORS 27E) 7” 3 5 1 2 NB SandsUnderreamer parts left in hole 1/8/2006 PBTD=9,359’ (MD) / PBTD = 4,354’(TVD) 4 TOC @ 8,967’ on 4/12/2021 Min ID = 2.75” @ 8,891’ OA Sands NE Sands NB 8,927’ 8,937’ 4,065’ 4,070’ 10 6/3/2021 Open 2” NB 8,946’ 8,956’ 4,076’ 4,081’ 10 6/3/2021 Open 2”//,,,,p 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): 9,453'8,954' Casing Collapse Conductor N/A Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:David Haakinson Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 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 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 202-009 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE POINT / SCHRADER BLUFF OIL 50-029-23065-00-00 Hilcorp Alaska LLC Length Size 4,426' 8,967' 4,087' C.O. 477.05 PRESENT WELL CONDITION SUMMARY 1,345 TVD Burst 8,903' MD N/A 9,445' Tubing Size: Tubing Grade: N/A MILNE PT UNIT S-21 112' 112' Tubing MD (ft): 112' 20" 7"9,445'7,240psi4,420' 3-1/2" Perforation Depth MD (ft): See Schematic 9.3# / L-80 / IBTSee Schematic Perforation Depth TVD (ft): 7" x 3-1/2" S-3 Permanent & 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. 8,857' MD/ 4,028' TVD and N/A Authorized Signature: 5/22/2021 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 12:39 pm, May 11, 2021 321-234 Chad Helgeson (1517) 2021.05.11 11:38:30 - 08'00' DSR-5/11/21SFD 5/11/2021MGR17MAY21 10-404 dts 5/17/2021 JLC 5/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.17 11:10:49 -08'00' RBDMS HEW 5/19/2021 Perforate NB Sands Well: MPU S-21 PTD: 202-009 API: 50-029-23065-00-00 Well Name:MPU S-21 API Number: 50-029-23065-00-00 Current Status:Shut In - Injector Pad:S-Pad Estimated Start Date:May 22, 2021 Wellwork unit:SL/EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:202-009 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:Ian Toomey (907) 903-3987 (M) AFE Number:Job Type:Perforate Current Bottom Hole Pressure: Isolated from Formation Maximum Expected BHP:1,745 psi @ 4000’ TVD Offset Well H-17 SBHP (01/2020) |8.39 PPG MPSP:1,345 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 77° @ 3,090’ MD MIN ID:2.75” XN Nipple @ 8,891’ MD Brief Well Summary MPU S-21 was drilled and completed in 2002 as a Schrader Bluff N and OA sand well. Following MBEs with offset producers, the well was squeezed with an attempt to underream and open up the NB and NE sands. During the coiled tubing job to under-ream the cement squeeze from the 7” casing, under-reamer blades were lost in the hole and no attempts to reobtain connection to formation since 2006. S-21 is in the location of planned development drilling in 2021. After perforating the formation, the reservoir pressure data will be used to assist the drilling program. The NB sand reservoir is estimated to be sub-normally pressured. Perforations are requested to measure the reservoir pressure and subsequently bring on injection if under-pressured as projected. Notes Regarding Wellbore Condition x The wellbore is currently isolated from the formation. x 10’ length by 2.7” OD drift completed to 8,967’ MD on 4/12/21 o Notable tight spot at 887’ MD. x Passing MIT-IA to 1,662 psi completed on 4/18/21 Objective x Perforate the Schrader Bluff NB Sands Perforate NB Sands Well: MPU S-21 PTD: 202-009 API: 50-029-23065-00-00 Procedure E-Line 1. MIRU EL. PT lubricator to 200 psig low and 3,000 psig high. 2. MU GR/CCL and 10’ x 2.3” OD dummy gun. a. This is for correlation run and to ensure E-line can get to bottom. 3. RIH to 8,965’ MD. 4. Perform Up-pass to 8,800’ MD for correlation pass. a. Tie into MWD Log dated 2002. 5. POOH to surface. 6. PU GR/CCL and 10’ x 2” SLB Power Jet Omega 6 SPF gun. a. Max Swell: 2.29” 7. Perform Confirmation Pass prior to perforating. a. Send log to Engineer David Haakinson (dhaakinson@hilcorp.com) and seek approval prior to perforating. 8. Perforate Schrader Bluff NB Sand from ±8,946’ MD to ±8,956’ MD. a. TVD: ±4,065’ to ±4,070’ 9. POOH to surface. a. Document condition of fired guns including any damage or un-fired charges. 10. PU GR/CCL and 10’ x 2” SLB Power Jet Omega 6 SPF gun. a. Max Swell: 2.29” 11. Perform Confirmation Pass prior to perforating. a. Send log to Engineer David Haakinson (dhaakinson@hilcorp.com) and seek approval prior to perforating. 12. Perforate Schrader Bluff NB Sand from ±8,927’ MD to ±8,937’ MD. a. TVD: ±4,076’ to ±4,081’ 13. POOH to surface. a. Document condition of fired guns including any damage or un-fired charges. 14. Assuming all shots fired, RDMO E-Line. Attachments: 1) MWD Log for Correlation. 2) Current Schematic 3) Proposed Schematic Perforate NB Sands Well: MPU S-21 PTD: 202-009 API: 50-029-23065-00-00 _____________________________________________________________________________________ Revised By: DH 5-6-2021 SCHEMATIC Milne Point Unit Well: MP S-21 Last Completed: 8/19/2002 PTD: 202-009 ` PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size NB 8,930’ 8,934’ 4,066’ 4,069’ 4 7/5/2004 Squeezed 2-1/2” NE 9,006’ 9,026’ 4,110’ 4,122’ 20 7/5/2004 Squeezed 2-1/2” OA 9,140’ 9,160’ 4,195’ 4,209’ 20 8/18/2002 Squeezed 2-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 7" Production 26 / L-80 / BTC 6.276” Surface 9,445’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.3/ L-80 / IBT 2.992” Surface 8,903’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,224’ 3.5” HES ‘X’ Nipple – ID= 2.813 2 8,834’ 3.5” HES ‘X’ Nipple – ID= 2.813 3 8,857’ Baker 7” x 3.5” “S-3” Permanent Packer 4 8,891’ 3.5” HES ‘XN’ Nipple – ID= 2.75” 5 8,902’ WLEG - Bottom @ 8,903’ WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle= 77 deg. @ 3,090’ Hole Angle thru Perfs= 45 - 57 deg. TREE & WELLHEAD Tree 4-1/16”, 5M Wellhead FMC 11” Gen 6 4-1/2” hanger w/4-1/2” TC-II T&B CIW 4” H-profile OPEN HOLE / CEMENT DETAIL 20” insulated 260 sacks Arctic set (approx.) in 42” hole 7” 1,030 sacks LITE plus 328 sacks Class “G” in a 9-7/8” hole, plus 205 sacks LITE and 108 sacks Class C top fill, plus another 96 sacks LITE top fill TD= 9,453’ (MD) / TD =4,426’(TVD) 20” Orig KB Elev.: 73’ / Orig GL Elev.: 39.0’ RKB Elev =34’ (NABORS 27E) 7” 3 5 1 2 NB SandsUnderreamer parts left in hole 1/8/2006 PBTD =9,359’ (MD) / PBTD = 4,354’(TVD) 4 TOC @ 8,967’ on 4/12/2021 Min ID = 2.75” @ 8,891’ OA Sands NE Sands GENERAL WELL INFO API: 50-029-23065-00-00 Drilled by Nabors 27E - 2/11/2002 Initial Completion by Nabors 4ES - 8/19/2002 Add Perfs - 7/5/2004 _____________________________________________________________________________________ Revised By: DH 5-6-2021 PROPOSED Milne Point Unit Well: MP S-21 Last Completed: 8/19/2002 PTD: 202-009 ` PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size NB 8,930’ 8,934’ 4,066’ 4,069’ 4 7/5/2004 Squeezed 2-1/2” NB ±8,927’ ±8,937’ ±4,065’ ±4,070’ 10 TBD Proposed 2” NB ±8,946’ ±8,956’ ±4,076’ ±4,081’ 10 TBD Proposed 2” NE 9,006’ 9,026’ 4,110’ 4,122’ 20 7/5/2004 Squeezed 2-1/2” OA 9,140’ 9,160’ 4,195’ 4,209’ 20 8/18/2002 Squeezed 2-1/2” GENERAL WELL INFO API: 50-029-23065-00-00 Drilled by Nabors 27E - 2/11/2002 Initial Completion by Nabors 4ES - 8/19/2002 Add Perfs - 7/5/2004 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / N/A 19.124 Surface 112' N/A 7" Production 26 / L-80 / BTC 6.276” Surface 9,445’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.3/ L-80 / IBT 2.992” Surface 8,903’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,224’ 3.5” HES ‘X’ Nipple – ID= 2.813 2 8,834’ 3.5” HES ‘X’ Nipple – ID= 2.813 3 8,857’ Baker 7” x 3.5” “S-3” Permanent Packer 4 8,891’ 3.5” HES ‘XN’ Nipple – ID= 2.75” 5 8,902’ WLEG - Bottom @ 8,903’ WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle= 77 deg. @ 3,090’ Hole Angle thru Perfs= 45 - 57 deg. TREE & WELLHEAD Tree 4-1/16”, 5M Wellhead FMC 11” Gen 6 4-1/2” hanger w/4-1/2” TC-II T&B CIW 4” H-profile OPEN HOLE / CEMENT DETAIL 20” insulated 260 sacks Arctic set (approx.) in 42” hole 7” 1,030 sacks LITE plus 328 sacks Class “G” in a 9-7/8” hole, plus 205 sacks LITE and 108 sacks Class C top fill, plus another 96 sacks LITE top fill TD= 9,453’ (MD) / TD =4,426’(TVD) 20” Orig KB Elev.: 73’ / Orig GL Elev.: 39.0’ RKB Elev =34’ (NABORS 27E) 7” 3 5 1 2 NB SandsUnderreamer parts left in hole 1/8/2006 PBTD =9,359’ (MD) / PBTD = 4,354’(TVD) 4 TOC @ 8,967’ on 4/12/2021 Min ID = 2.75” @ 8,891’ OA Sands NE Sands ( Image Project Well History File Cover 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. ~œ.- OCJCf Well History File Identifier ~o-Sided 1111111111111111111 Organizing (done) ~scan Needed 1111111111111111111 R~CAN vi Solar Items: ~reYSCale Items: 0 Poor Quality Originals: DI~AL DATA uz[Oiskettes, NO.~ 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation BY: Helen~ 4- x 30 = /~(:/ 0 Other:: Date ¡6(~ ~~lllllillll~P DateJD,~ ~ Isl m-fJ , + ~ = TOTAL PAGES I as' (Count does f.ot ¡,.Iclude cover sr7f'fJJ!) Date: I 0 ~ 00 Isl VV~fI II \ 1111111111 " 1 \ I NOTES: BY: Helen C Maria) Project Proofing BY: HelenM Production Scanning Stage 1 Page Count from Scanned File: J ~t:, (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES r , Helen ~ Date:/O [j-JOlf , , YES NO NO Isl Wl P Stage 1 BY: If NO in stage 1, page( s) discrepancies were found: BY: Helen Maria BY: Helen Maria Date: /sf IIIIII1111111111111 1111111111111111111 Date: Isl Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: 8/24/2004 Well History File Cover Page.doc • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 a Post Office Box 196612 Anchorage, Alaska 99519 -6612 SLANNEDFEB 2 4 2 0I2 December 30, 2011 Mr. Tom Maunder _ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue S ryl F Anchorage, Alaska 99501 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 10/11/2011 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 8/182011 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 NOT OPERABLE: MPS-21 (~D #2020090) Overdue UIC Testing an~dded Well to Q... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, April 16, 2009 9:45 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Holt, Ryan P(ASRC); MPU, Wells Ops Coord; MPU, Welis Ops Coord2; Smith, Paige S.; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: MPS-21 (PTD #2020090) Overdue UIC Testing and Added Well to Quarterly Report of SI Injectors Hi Jim and Tom, Milne Point well MPS-21 (PTD #2020090) was last pressure tested for UIC compliance on 04/14/07. At this time there are no plans to return the well to injection while efforts are being taken to isolate zones. The well has been reclassified as Not Operable and added to our quarterly report of shut-in injectors. _-- Please let us know if you have any questions. Thank you, Anna ~Du6e, ~P. E. Wetl Integrity Coordinator GPB Wells Group Phone: (9U7} 659-5°102 Pager: (907j 659-5100 x1154 ~ ~:.; f ' ' f ~~ C~ C'. " ,+~,.~Y:n '~` .'-t i1 ~;: - , `i.'~' sa ~w.rs~ / 7/29/2009 LVIß1VI U KAl~ U U Nt ~tate of Alaska Alaska Oil and Gas Conservation comm. DATE: Tuesday, May 01,2007 . TO: JimRegg~t11' 514(07 P.I. Supervisor L L SLBJECT: Mecha01cal Integrity Tests BP EXPLOR/,TTON (ALASKA) r;\C 5-2 ¡ FROM: Chuck Scheve Petroleum Inspector \[!l'-iF PT L0:!T 5B 5-21 Src: Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB S-21 Insp Num: mitCS070415081100 Rei Insp N urn: API Well Number: 50-029-23065-00-00 Permit Number: 202-009-0 ...ooq ~ôr Reviewed By: P.I. Suprv ,~T~ Comm Inspector Name: Chuck Scheve Inspection Date: 41l4í2007 Packer Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~----- I Depth ~ell: S-21 'Type Inj. 'N TVD __~~~2~--+-1~_~-- 220 _ i--I72;;-~ 1680 P.T.D: 2020090 ITypeTest : SPT , Test psi i _~_~__~.----L..-.__----.J..____-'--_----'-_ , T b· I 250 '50 Interval OTHER P/F P ,// __~~~=~_~____~--=- 1500 'OA ¡ I ' Notes: Test performed due to leaks encountered on other monobore completions. SCANNED MAY O· 9 2007 " . .:,.,.~",...."...-\........~-".",.-:,' Tuesday, May 01, 2007 .~-~ 1680 2503 ! -!~---+--~--~-- --~-----'--- Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT / Milne Point / S-Pad 04/14/07 Jeff Rea / Lee Hulme Chuck Scheve ~DÎ--009 Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIMPS-07 I Type Inj. N TVD 4,231' Tubing 400 500 500 500 Intervall 0 P.T.D.12020720 Type test P Test psil 1500 Casing 1,700 1,650 1,640 PtFI P Notes: 4.4 bbls diesel to 1700 psi. Bled to 0 psi OA Well is currentlv SI. Proactive testino to determine IA status due to leaks found on other monobore completions. WeIlIMPS-09 I Type Inj. W TVD I 4,368' Tubing 800 800 800 800 Intervall 0 P.T.D.12020200 I Tvpe test P I Test psil 1500 Casino 280 1,710 1,670 1,670 PtFI P Notes: 1.6 bbls diesel to 1710 psi. Bled to 300 psi OA Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-13 I Type Inj. N TVD I 4,166' Tubing 1,220 1,220 1,220 1,220 Interval I 0 P.T.D.12021140 I Tvpe testl P I T est psi! 1500 Casino 1,800 1,720 1,720 PtF P Notes: 3.4 bbls diesel to 1800 psi. Bled to 250 psi OA Well is currentlv SI. Proactive testino to determine IA status due to leaks found on other monobore completions. WeIlIMPS-21 I Type Inj. N TVD I 4,027' Tubing 200 250 250 250 Interval I 0 P.T.D.12020090 Tvpe test P I Test psil 1500 Casino 220 1,720 1,680 1,680 PtFI P Notes: 1.7 bbls diesel to 1720 psi. Bled to 200 psi OA Well is currentlv SI. Proactive testino to determine IA status due to leaks found on other monobore completions. Weill I Type InLI TVD Tubinq Interval I P.T.D.I I Tvpe testl Test psi Casing PtFI Notes: OA . . TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring SCANNED APR 1 7 2007 P = Standard Pressure Test R = Internal Radioactive Tracer 8urvey A = Temperature Anomaly 8urvey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 . ....,....,u~_·....·~·..·· MIT MPU 5-07, 8-09, 8-13, 8-21 4-14-07.xls . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc as ons. 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other L:l4nchnr;;gp Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 Exploratory 202-0090 3. Address: P.O. Box 196612 Stratigraphic 0 Service R1 6. API Number: Anchorage, AK 99519-6612 50-029-23065-00-00 7. KB Elevation (ft): 9. Well Name and Number: 73.25 KB MPS-21 8. Property Designation: 10. Field/Pool(s): ADL-380109 Milne Point Field/ Schrader Oil Pool 11. Present Well Condition Summary: Total Depth measured 9453 feet Plugs (measured) None true vertical 4425.9 feet Junk (measured) None Effective Depth measured 9359 feet true vertical 4353.81 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 33 - 112 33 - 112 1490 470 Production 9411 7" 26# L-80 32 - 9443 32 - 4418.23 7240 5410 Perforation depth: Measured depth: Squeezed 8930-9160 True Vertical depth: Squeezed 4066.01-4208.25 Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 30 - 8903 Packers and SSSV (type and measured depth) 3-1/2" Baker S-3 Packer 8857 -'çA:",\\~,~[¡;;;1 ¡ t ßt ~"r '-hi ·W'¡""_·' t'," ( .., 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft DEC 2 2 2005 8930-9160 Treatment descriptions including volumes used and final pressure: see attached Fluid Summary T/I/O=300/1250/0 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after Droposed work: Copies of Logs and Surveys Run Exploratory Oi Development 0 Service r;¡! Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 Gas Oi WAG 0 GINJ 0 WINJ R1 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal ¿ Title Data Mgmt Engr Signatu~ Phone 564-4424 Date 12/16/2005 HI::Cr::IVED _ STATE OF ALASKA _ ALA_ OIL AND GAS CONSERVATION COM~ION DEC 2 2 2005 REPORT OF SUNDRY WELL OPERATIONS Alaska 01 & Gee Form 10-404 Revised 04/2004 OR\G\NAL Submit Original Only .. e e .. MPS-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATi: I SUMMARY 11/18/2005 CTU #5, Cement Squeeze; RU. Drift new coil string with 1.25" OD ball. Perform BOP test. RIH with Baker TEL. Continue on 11-19-05 WSR ... 11/19/2005 CTU #5, Cement Squeeze; Continue from 11-18-05 WSR ... Correct depth to XN nipple using Baker TEL. Tag TD @ 9208' ctm up. Pull up 10' - Flag pipe. POOH. Fluid pack well with 140 bbls 1 % KCL. RIH with 2.25" BJN. Treat perfs with 28 bbls of DAD acid. No improvement in injectivity (1.7 bpm @ 735 psig WHP). Pump 29 bbls of LARC cement. Lay across perfs and squeeze 17 bbls behind pipe. Ramped up to 1420 psi DP at perfs. Clean out to 8952' and hit hard cement. Target depth is 9208'. Top set of perfs open. Pumped total of 140 bbls biozan and chase out at 80 % washing all jewerly. Freeze protect tubing from 3475' with 60/40 methanol. Continue on 11-20-05 WSR ... 11/20/2005 CTU #5, Cement Squeeze; Continue from 11-19-05 WSR... Freeze protect tubing to 3500'. WHP bleeding down. Establish Injectivity rate of 1.5 bpm @ 1800 psi. Top set of perfs are broke down. Discuss plan forward w/ town. Elect to re-squeeze top set of perfs. Wait on fluids. Continue on 11-21-05 WSR. 11/21/2005 CTU #5, Cement Squeeze; Continue from 11-20-05 WSR... RIH with 2.25" OD BDN for re-squeeze. Tag TD @ 8950' ctmd up. Flag pipe. Perform injectivity test 1.1 bpm @ 1750 psi. Cool sump with 116 bbls 1 % KCL. Circulate in approximately 20 bbls 15.8 ppg cement. Lay cement across perfs and squeeze est. 16 bbls behind pipe. Attained squeeze pressure of 1300 psig WHP. Contaminated and cleaned out to 8905' (5' below tailpipe), encountered hard cement. Chased out of hole at 50%. FP well to 3500' with 60/40 methanol. Trapped 300 psig WHP. Notified Pad Operator of well status. Will return at later date to mill out cement. RD DS CTU #5. *** Job Compl(3te *** FLUIDS PUMPED BBLS 369 MeOH 673 1 % KCL 52 Diesel 49 Cement 10 TEA 265 Fresh water 28 DAD acid 260 Biozan 1706 TOTAL Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;? 1/ 2- Ðd) /} /1'_';' "'- MPS-21 ~b'f) - 'e'T---MPE-25 l1 ') ó'-I - /7.;< - MPG-19 ,;?{. d ~PB-27 .blÐ I. - 2.~L MPE-25A !2 /)i./~ O'f~/ MPC-42 (;/ E-102 ÆOtf-02 (/ ~(_ I <it Well 10670013 10687675 10900120 10964102 10703992 10830797 10672379 Job# MEM CBl CBl SCMT SCMT SCMT SCMT RST log Description 05/03/04 03/30/04 11/25/04 11/30/04 04/18/04 05/01/04 05/01104 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ;/qt~ aOà-'ÙOC¡ 02/22/05 NO. 3346 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point Midnight Sun Date Color CD Bl ~. Schlumberger DCS 3940 Arctic Blvd Suite 300 :'~~/¿~ -- SCANNED ~jUN 1 ?' 2ûD5 /8 ¥'~'-\ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020090 MD 9453 Well Name/No. MILNE PT UNIT S8 S-21 Operator 8P EXPLORATION (ALASKA) INC - API No. 50-029-23065-00-00 Completion Status 1WINJ Current stat~ . (~~I~ .cc:c ND 4426 Completion Date 8/18/2002 REQUIRED INFORMATION Samples No Mud Log No "=ì Directional su~~~~u=~~--_u- ------~-----~----,---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, CCL Well Log Information: Log/ Data ~ 4:69'-- Rpt ~é Digital Med/Frmt tÆt5 c œó/ D ~CLas (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Number Naß'e ~ent Evaluation / ~ement Evaluation LIS Verification ~ See Notes Log Log Run Interval OH/ Scale Media No Start Stop CH Received 5 Col 1 34 8284 Case 4/19/2002 5 Col 8350 9325 Case 5/14/2002 135 9415 Case 1 0/15/2002 112 9453 Open 12/18/2002 Comments -------_.---------- -- Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Reisitivity L-14132 Cement Evaluation t.-14179 LIS Verification tl-2556 Temperature 8350 9325 Case 10/1/2002 135 9415 Case 1 0/15/2002 8587 8972 Case 5/412004 CGM PDF TIF Well Cores/Samples Information: ~-- Name Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION vQ) Daily History Received? MN êY IN Chips Received? ~LN-~ Analysis Received? Comments: Formation Tops --'0.N-- --~--------<--_._--- -~-------~_._------ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020090 Well Name/No. MILNE PT UNIT SB S-21 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23065-00-00 MD 9453 TVD 4426 Completion Date 8/18/2002 Completion Status 1WINJ Current Status 1WINJ UIC Y Compliance Reviewed By: iJ-u Date: ~~d==~~~""__d_~_~ .. ) cŸt;t=l~~~~- 1 - '. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ( 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate ŒJ 73.25 8. Property Designation: ADL-380109 11. Present Well Condition Summary: 4. Current Well Class: Development 0 Stratigraphic 0 9. Well Name and Number: MPS-21 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit ExploratoryD Service Œ] Stimulate D OtherD WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0090 6. API Number 50-029-23065-00-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9453 feet true vertical 4425.9 feet Effective Depth measured 9232 feet true vertical 4259.1 feet Plugs (measured) Junk (measured) None None Casing Conductor Production Length 79 9411 Size 20" 91.5# H-40 7" 29# L-80 MD TVD Burst 33 112 33.0 112.0 32 - 9443 32.0 - 4418.2 1490 8160 Collapse 470 7020 Perforation deDth: Measured depth: 8930 - 8934,9006 - 9026,9140 - 9160 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 30 8903 RECEIVED SEP 13 2004 Alaska Oil & Gas Cons Comm' . . ISSlon Anchorage True vertical depth: 4066.01 - 4068.22,4109.64 - 4121.67,4194.64 - 4208.25 Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: @ 8857 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 ReDresentative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 4~5 0 0 -2486 0 Tubing Pressure 1413 1268 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J1~~ WAG D GINJD WINJŒ) WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 304-240 Title Production Technical Assistant Signature Phone 564-4657 Date 9/8/04 ~rn 'fI!h1I v)'L,tf Jl' i':!J; Form 1 0-404 Revised 4/2004 OR\G\NAL .. (1/.", .,.. MPS-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/02/04 «WELL INJECTING 2900 BWPD ON ARRIVAL» DRIFT WELL FOR UPCOMING ADD PERF WORK @ 8930 - 89341 MD AND 9006 - 9026' MD. TAGGED TD @ 9185'WLM (9226'MD) USING 41' CORRECTION FROM TEL. 07/05/04 Perforate 8930'-8934' 2 SPF, 9006'-9026' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 ¿ Tree:Cameron 7-1/16", \,.v,. Wellhead: FMC 11' gen 6 4.5' hanger wi 4.5" TC-II T&S CIW 4" H-profile 8 20"x 34" insulated, 215 #/ft A-53 I 80' I KOP @ 300' Max. hole angle = 70 - 77 deg FI 2800' - 8500' Hole angle thru perfs = 50 deg. 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 1ST but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") Perforation Summary 21/2" HSD 2506 Powerjet HMX, 2 spf, 90 deg LSH, 180 phasing 21/2" HSD 2506 Powerjet HMX, 6 spf, 60 phasing (7/5/04) Ii Size SPF Interval (TVD) NB Sands 2.5" 2 8930' - 8934' 4066' - 4068' NF Sands 2.5" 6 9006' - 9026' 4109' - 4121' OA Sands 2.5" 4 9,140' - 9160' 4195' - 4209' Sqz. perfs 2" 6 8,935' - 8,940' 3 3/8" HSD 4 spf, Random phasing, 34B HJ II, RD~ DATE REV. BY 02/11/02 Lee Hulme 8/19/02 MDO 7/5/04 Lee Hulme MPU 5-21 i Orig. DF Elev. = 73.25' Orig. GL Elev. = 39.00' 3.5" HES X-Nipple ( 2.813" ) I 2,224' I 3.5" HES X-Nipple ( 2.813" ) I 8,834' I f""", ~% % .Iti¡¡~i' 7" x 3.5" Baker "S-3" Perm. packer! 8,857' I ~~ COMMENTS Drilled & Cased by Nabors 27-E Initial Completion Nabors 4-es / Perfs Add Perfs 3.5" HES XN-Nipple 2.813" Pkg. I 8,891' I (No-Go 2.75" id ) I I 3.5" WLEG 8,903' ELMD I 8901' I Short joints 9015'-9034' ~ 7" Halliburton Float Collar 7" Halliburton float shoe 9,359' 9,443' MILNE POINT UNIT WELL No.: 5-21 i API: 50-029-23065-00 BP EXPLORATION (AK) lr3s ~ 'II. ( WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. -, ~ct )CJ)..,-U To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage. Alaska 99501 RE: Distribution - Final Print[ s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services,lnc. P. O. Box 1389 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical DataCenter LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 Res. Eva!. CH 1 1 1 S-21i 4-22-04 Mech. CH /2 J'~)-G 1 Caliper Survey Print Name: I lj¿ ¡/ / j i ¡ua wi ¡J;Wf!V1¿ ()k~d Date: I v¡ J~ 1-<N1 Signed: PRoACTivE DiAGNOSTic SERvicES, INC., PO Box 17J69 STAffoRd IX 11411 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com (STATE OF ALASKA Ðn ( / k ALASKA OIL AND GAS CONSERVATION COMMISSION /?ttJ-/ .", G/ APPLICATION FOR SUNDRY APPROVAL ;/ ~ {)l-\ 20 MC 25.280 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Name: Suspend 0 RepairWell 0 Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate[!] WaiverD Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well D 5. Permit to Drill Number: 202-0090 BP Exploration (Alaska), Inc. Length Development D Exploratory D Stratigraphic D Service Œ] 9. Well Name and Number: MPS-21 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9359 4280.6 MD TVD 6. API Number 50-029-23065-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 73.25 KB 8. Property Designation: ADL-380109 11. Total Depth MD (ft): 9453 Casing Total Depth TVD (ft): 4425.9 Size Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom Conductor 79 20" 91.5# H-40 33 112 33.0 112.0 1490 470 Production 9411 7" 29# L-80 32 9443 32.0 4418.2 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9140 - 9160 4194.64 4208.3 3.5" 9.3 # L-80 30 8903 Packers and SSSV Type: 3-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 8857 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program Œ] BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD Service Œ] 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG D GINJD Plugged D Abandoned D WINJ ŒJ WDSPLD Prepared by Garry Catron 564-4657. June 29,2004 Contact William Mathews Printed Name (i;jJr!iII~ Mathews Signature 'fIð'/FI:H/íaf/{ Title Phone Petroleum Engineer 564-5476 6/15/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . ;;O¥.d- 'tJ Other: BOP TestD Mechanciallntegrity Test D Location Clearance D Approv ~ ~\"Ñ<\\O")"'-Ìhfè"o.~\\~\,\b BY ORDER OF 0 R , G , N A L THE COMMISSION Date: ~/øf~ BFl JUN 2 Q 2004 JUN 232004 Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE (, 0", " b",,'.~ ';" . ' .' ! 1'"." '", \ i .~~. To: From: Subject: Cost Code: ( G MPU Wellwork Programs Date: June 15, 2004 Bill Mathews Lead Schrader PE S-21i Add Perfs MSWWELS21 $15,000 400 bopd Est. Cost: lOR: Please add perforations to the NB and NE intervals of injector S-2li. Injection into these zones will support offset production from wells S-34 and S-35. A limited shot density is requested for the NB interval to help insure conformance between the three sands. Basic steps are as follows: ~C$ ~E- S E Drift and tag (Post emt sqz cleaned out to 9232' CTMD 5/3/04) Perforate a 4-foot interval at 8930-8934' md (4066-4068' tvd) Gun: 2-1/2"HSD 2506 PowerJet HMX, 2 suf" +/- 90 deS! LSH" 180 uhasinS! EHD = 0.17"(7" 26# casing), Max gun swell size = 2.66" (in water) <6 s \O~ E Perforate a 20-foot interval at 9006-9026' md (4109-4121' tvd) Gun: 2-1/2"HSD 2506 PowerJet HMX, 6 suf" 60 uhasinS! EHD = 0.17"(7" 26# casing), Max gun swell size = 2.66" (in water) \(}o ~b\-s Notes: . Plan to pump guns down due to deviation. Utilize 2-1/8" weight bars and rollers to assist. . All depths referenced to SWS Cement Bond Log dated April 23, 2002 . Tie in to 7" casing short joints at 9008' and 9028' MD Risks ~ \ c.. " "> \' \ V'-~~, '\ I'\. (, - )) -...)~~ \;:... "> ~~, ~\\ \\- The primary risk associated with perforating this well and initiating injection into the N sands is ~ç.Ó."j that there will be a loss of support to the 0 sands. Historically, commingled injection into multiple sands has not been successful without some kind of mechanical isolation. The perforation strategy is designed to help mitigate this. A secondary risk is the potential to sand up the lower zones due to cross flow during shut down periods. While there is no way to mitigate this other than to recomplete the well with some kind of downhole flow control it can be quantified through regular surveillence. Contact Bill Mathews: 564-5476,345-9878 (home) or 440-8496 (cell) with any questions or comments. cc: Anchorage MPS-21 well file MPU, Well Ops Supv. (Bixby/Spence) MPU, Well Ops Coor. (Cubbon/O'Malley) Tree:Cameron 7-1/16", !IVI Wellhead: FMC 11' gen 6 4.5' hanger wI 4.5" TC-II T&B CIW 4" H-profile A 20"x 34" insulated. 215 #/ft A-53 ~ KOP @ 300' Max. hole angle = 70 - 77 deg FI 2800' - 8500' Hole angle thru perfs = 50 deg. 7" 26#, L-80, BTRC Casing (drift ID = 6.151, cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 1ST but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") Peñoration Summary Size Spf Interval OA Sands 9,140'-9,160' 08 Sands NIA Sqz.perfs 8,935' - 8,940' (TVD) 2.5" 4 4,195'- 4'209' 2" 6 33/8" HSO 4spf, Random phasing,348 HJ II, ROX~,' MPU 8-21 i Ii ~~ DATE 02/11/02 8/19/02 REV. BY Lee Hulme COMMENTS Drilled & Cased by Nabors 27-E « Orig. DF Elev. = 73.25' Orig. GL Elev. = 39.00' 3.5" HES X-Nipple (2.813" ) I 2,224' I 3.5" HES X-Nipple (2.813" ) I 8,834' I 7" x 3.5" Baker "S-3" Perm. packer! 8,857' I 3.5" HES XN-Nipple 2.813" Pkg. I 8,891' I (No-Go 2.75" id ) I I 3.5" WELG 8,903' ELMO I I Short joints 9015'-9034' ~ 7" Halliburton Float Collar 7" Halliburton float shoe 9,359' 9,443' MOO Initial Completion Nabors 4-es 1 Perfs MILNE POINT UNIT WELL No.: S-21i API: 50-029-23065-00 BP EXPLORATION (AK) Re: MPS-21 (202-009) Future Work ) ) Subject: Re: MPS-21 (202-009) Future Work From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 14 lun 2004 16:24:50 -0800 To: "Mathews, William L" <MathewWL@BP.com> Bill, Thanks for bringing the log over for MPS-21. An improvement in the bond is indicated over the N sand intervals. You have requested approval to "shoot" Nb and Ne intervals in the well. Based on the improved bonding evident on the log, you have approval to do so. Be sure a 404 is submitted after the operation is done. When you have an additional copy of the log, please submit it f\>r our files. Call with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote: Bill, I have received your information on MPS-21. It would appear that the squeeze work has provided some isolation going up as had been planned. I will look forward to reviewing the log when you next get the copy. In the interim, you have approval to resume water injection into MPS-21. You have noted that 3 producers are "suffering" due to lack of injection support. It will be interesting to see what response you see. Please call with any questions. Tom Maunder, PE AOGCC Mathews, William L wrote: Morning Tom, MPS-21 was squeezed in April, cleaned out and logged in May. I've attached a spreadsheet with the daily operations summaries. Basically, we pumped a total of 94 bbls cement with an estimated 63 bbls behind pipe. The memory SCMT log was run and a preliminary review shows we have good cement above and below the squeeze perfs 8935-40' MD. This means we should have isolation from the overlying Ugnu. I had hoped to have the log available to show you this week, however, it needs to be depth shifted and Schlumberger does not have the ability to do it in town. It is now in Japan being depth shifted and reprinted. When I get it, I'll bring a copy over for you to review. In the meantime, I'd like to get approval to bring MPS-21 back on injection. We currently have three producers that are suffering due to it being shut in. Please let me know if I can proceed with turning the valve. Thanks, Bill Mathews 564-5476 SCANNED OCT 3 1 2005 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 24, 2004 12:35 PM To: Mathews, William L Subject: Re: MPS-21 (202-009) Future Work Hi Bill, Any update on our friend MPS-21 ?? Tom Thomas Maunder wrote: lof5 6/14/20044:25 PM r Name: BP Exploration (Alaska), Inc. ALAS~ all AND ~~~~g~S~~;A~ON CO~MISSlcß CE\VED REPORT OF SUNDRY WELL OPERATI~~$9LOG4 ',"'" (';. r- <:!s COilS, Cu¡w Îì¡S3;~:.1 Perforatel~a,:~2 (:\¡{aJv~rri OtherD A\1C!¡(ttðge Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0090 Suspend 0 Repair Well[&] Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator 73.25 8. Property Designation: ADL-380109 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: MPS-21 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit Exploratory 0 Service [&] 6. API Number 50-029-23065-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 9453 feet true vertical 4425.9 feet measured 8959 feet Plugs (measured) Junk (measured) None Effective Depth None true vertical 4082.3 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 33 112 33.0 112.0 1490 470 Production 9411 7" 29# L-80 32 - 9443 32.0 - 4418.2 8160 7020 Perforation depth: Measured depth: 9140 - 9160 True vertical depth: 4194.64 - 4208.25 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 30 8903 Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer @ 8857 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8935' - 8940' Treatment descriptions including volumes used and final pressure: 25 Bbls 12% HCL /47 Bbls 15.8 LARC Cement @ 2000 psig. Representative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0 ~~4 0 13 Well Shut-In 37 Tubing Pressure 1116 0 Prior to well operation: Subsequent to operation: Oil-Bbl 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒl Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG 0 GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 304-075 Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron JJeuy/ ~ Title Production Technical Assistant Signature Phone 564-4657 Date 6n 104 Form 10-404 Revised 12/2003 nDIc,I(fff-£p;I1Jr ¿ -/~.,,~ " ~ ~. ~,; (" MPS-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/14/04 TAGGED TO @ 9310lWLM (9338.CWLMD), USED 281 CORRECTION FROM TAG ON 12-20- 03, TOOLS FELL VERY SLOW (20FPM-70FPM) FROM 64501WLM-93101WLM AND THE TEL THAT WAS UTILIZED FAILED TO ACTIVATE. THE TAG DEPTH IS EXACTLY THE SAME AS SEEN ON 12/20103. RDMO. 03/30104 SANDBACK PERFSI ADPERFI SET RET AINERI ACIDIZE/CMT SQUEEZE. CTU #8. MIRU. FLUID PACK WELL WITH 1% KCL. RIH WITH 211 REVERSE OUT NOZZLE. TAG AT 93011 CTM, CORRECT TO 93381. LAY IN 33 BBLS OF 8PPG CARBOLlTE SLURRY TO 68001. PUH TO 65001. WAIT 1 HR TO RIH TO TAG. RIH TO 91401 NO TAG. POOH, CARBOLlTE SLOW FALLING. LET SETTLE OUT OVER NIGHT. FREEZE PROTECT WELL WITH 30 BBLS CRUDE. LD INJECTOR, SECURE WELL FOR NIGHT. 04/01/04 Sand plug set @ 89781-91601 04/04/04 CONTINUED FROM 411/04 AWGRS. MIRU CTU#8. RIH WITH 2.7211 JSN DRIFT. PULLED ERRATIC AND HEAVY ON WT CHECK AT 27001, START CLEANING OUT TUBING. SAND RETURNS AT SURFACE. CLEAN OUT TO TT WITH BIO SWEEPS. RETURNS NOT CLEANING UP AFTER TWO BIO PILLS PUMPED FROM TT AT SURFACE. POOH AT 800/0. AT SURFACE, INJECTIVITY TEST COULD NOT ESTABLISH RATE. PRESSURE UP TO 1000 PSI, LOOSE 250 PSI IN 5 MIN, 600 PSI IN 30 MIN. WELL FREEZE PROTECTED AND SHUT IN. 04/11/04 TAGGED TO @ 89651WLM. DRIFTED TUBING WITH A 10lX211 BAILER, AND 2.8011 SWAGE. OBTAINED A 201 CORRECTION OFF OF XN NIPPLE. CORRECTED TO IS 89851. 04/23/04 RIH WITH LOGGING TOOLS. TAG SAND TOP AT 8991 (DOWN) AND 8987 (UP). NOTE: THESE ARE UNCORRECTED DEPTHS. LOG UP TO 8600 AND FLAG PIPE. PRESSURE UP TUBING TO 1500 PSI. LOOSE 900 PSI IN 4 MINUTES. RET AG TOP OF SAND. POOH WITH LOGGING TOOLS. VERIFY GOOD DATA. CORRECTED TOS AT 89771 (UP). MUIRIH WISWS 51 - 21 - 6 SPF - 6011 - PERF GUN. PERF SQUEEZE INT 89351 - 89401. INJ TEST AT 8670. - 1 BPM/820 PSI - 2 BPM/1280 PSI - 2.7 BPM/1500 PSI - 3 BPM/1620 PSI. POOH -IN TEST AT SURFACE -1 BPM/700 PSI- 2.7 BPM/1155 PSI- 3 BPM/1250 PSI. BREAK OFF WELL, ALL SHOTS FIRED, RECOVER BALL. MU 211 BON STAB ONTO WELL. PT 200/4000 PSI. JOB IN PROGRESS. 04124/04 RIH WITH 211 CEMENTING NOZZLE. TAG TO AND RESET COUNTER TO 8977. PUMP 25 BBLOS 12% HCL WITH ADDITIVES (FIELD TITRATION-) PRE-ACID INJECTIVITY IS 1.3 B/M AT 839 PSI AND POST ACID INJECTIVITY IS 1.3 AT 780 PSI. OVERDISPLACE WITH 50 BBLS KCL. KILUCOOL WELL, MIXffEST CMT. PUMP TOTAL 47 BBLS 15.8 LARC CMT. UNABLE TO OBTAIN SQUEEZE PRESS. FLUSH CMT INTO PERFS. POOH, RBIH WITH 211 CEMENTING NOZZLE. JOB IN PROGRESS. 04/25/04 TAG TO AT 8982 (UP) CTMD. (LOOKS LIKE ABOUT 51 OF CEMENT ON TOP OF SAND. ) MIX AND PUMP 47 BBLS 15.8 PPG LARC CEMENT. LAY IN AND SQUEEZE WITH 2000 PSI AT SURFACE. (ESTIMATE 16 BBLS CMENT BEHIND PIPE.) HOLD FOR 1 HR. RELEASE SQUEEZE PRESSURE TO 300 AND RIH TO CONTAMINATE. WASH JEWELRY ON TRIP OUT OF HOLE. FP WELL - TRAP 640 PSI ON WELL. RDMO. 04/28/04 MIRU CTU # 9 - MU/RIH WITH WOT 2.3711 UNDEREAMER DRESSED WITH 5.7511 BLADES. TAG UP AT 8954 CTMD. MILL CEMENT TO 8959 USING ALTERNATING SWEEPS OF FLO-PRO AND KCL. JOB IN PROGRESS. Page 1 MPS-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/29/04 CONTINUED FROM WSR OF 4/28/04. CONTINUE MILLING TO 89841 15 STALLS, NO PROGRESS. POH TO INSPECT TOOLS. 1 ARM BROKEN, ALL ARMS WORN, NO TOOL PARTS LOST IN HOLE. JOB SCOPE TOOL CHANGE. WAIT ON BAKER.MU/RIH WITH BAKER UNDEREAMER AND 3 BLADE PILOT MILL. TAG AT 89861 - MILL TO 8995. GOOD RATE OF PENETRRATION AT THIS POINT. DROP BALL TO SHEAR CIRC SUB. JOB IN PROGRESS. 04/30/04 CONTINUE TO CHASE RETURNS OUT OF HOLE. OOH. MU 2" JS NOZZLE AND PRESSURE TEST SQUEEZE TO 1500 PSI. JFT AT 500 PSI. INJECTIVITY AT 1400 IS 0.25 B/M. WHEN SO PUMPING PRESSURE FALLS TO 188 IN 30 MINUTES AND HOLDS. RIH WITH 211 JS NOZZLE. CHECK OUT PIPE. FIND 3 BAD SPOTS. POH AND FREEZE PROTECT WELL TO 25001 WITH 50/50 MEOH. - BLOW DOWN COIL WITH N2 FOR PIPE SWAP. RDMO **** NOTIFY PO OF WELL STATUS, WELL SHUT IN WILL RETURN AFTER PIPE SWAP **** JOB INCOMPLETE **** 05/01/04 MIRU UNIT 9. RIH WITH 211 JS NOZZLE. TAG TO AT 8987 (UP). START JETTING FILL. JOB IN PROGRESS. 05/02/04 CLEAN OUT TO 9146 USING ALTERNATING SLUGS OF FLO-PRO AND XSKCL. START TO LOOSE RETURNS. CHASE FINAL 2 BBLS OF FILL TO SURFACE AS POH. RU N2 . CLEAN OUT TO 9200. CHASE SLUG OUT OF HOLE. RBIH AND DRY TAG FILL AT 9157 CTMD. ON LINE TO CIRC OUT LAST SAND FOR RAT HOLE. JOB IN PROGRESS. 05/03/04 Sand plug removed @ 8959'-92321 FLUIDS PUMPED BBLS 882 26 33 586 5174 5200 195 25 41 75 420 300 451 94 13502 1 % KCL 1 % 30# Gel 8 ppg Slurry (8000# 20/40 Carbolite) 60/40 Methonal 1 % XSLK KCL Lbs 20/40 Carbolite 2.5# Bio 120/0 HCL with additives Diesel Fresh Water 50/50 Methonal (Beneficial reuse glycol added in) Gals N2 Flo Pro 15.8 ppg LARC cement with additives TOTAL Page 2 Tree:Cameron 7-1/16", ( Wellhead: FMC 11' gen 6 4.5' hanger wI 4.5" TC-II T&S CIW 4" H-profile AI 20"x 34" insulated, 215 #/ft A-53 ~ KOP @ 300' Max. hole angle = 70 - 77 deg F I 2800' - 8500' Hole angle thru perfs = 50 deg. 7" 26#, L-80, BTRC Casing (drift ID = 6.151 cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 1ST but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") Perforation Summary Size Spf 2" 6 Interval OA Sands 9,140'-9,160' OB Sands NIA Sqz. perfs 8,935' - 8,940' 4,195'.4'209' (TVO) 2.5" 4 33/8" HSD 4spf, Random phasing,34B HJ II, RDX~ DATE 02/11/02 8/19/02 REV. BY MPU 8-21 i I 11111"1 ~'86~~1 ::.;.E~~~J ! ..,~'f) .--~~~;~~~~~ :t;~t: :;t.~~~;¡ f:];:~W~~ ..:~:;~r~r~: ~ M'- e I Lee Hulme COMMENTS Drilled & Cased by Nabors 27-E MDO Initial Completion Nabors 4-es 1 Perfs MILNE POINT UNIT WELL No.: S-21i API: 50-029-23065-00 Orig. OF Elev. = 73.25' Orig. GL Elev. = 39.00' 3.5" HES X-Nipple ( 2.813") I 2,224' I 3.5" HES X-Nipple (2.813") I 8,834' I 7" x 3.5" Baker "S-3" Perm. packer! 8,857' I 3.5" HES XN-Nipple 2.813" Pkg. I 8,891' I (No-Go 2.75" id ) I I 3.5" WELG 8,903' ELMD I I Short joints 9015'-9034' .. 7" Halliburton Float Collar 7" Halliburton float shoe 9,359' 9,443' BP EXPLORATION (AK) ~e: MPS..21 (202-009) Future Wark ( Subject: Re: MPS-21 (202-009) Future Work From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Tue, 25 May 200409:48:52 -0800 To: "Mathews, William L" <MathewWL@BP.com> Bill, I have received your information on MPS-21. It would appear that the squeeze work has provided some isolation going up as had been planned. I will look forward to reviewing the log when you next get the copy. In the interim, you have approval to resume water injection into MPS-21. You have noted that 3 producers are "suffering" due to lack of injection support. It will be interesting to see what response you see. Please call with any questions. Tom Maunder, PE AOGCC Mathews, William L wrote: Morning Tom, MPS-21 was squeezed in April, cleaned out and logged in May. I've attached a spreadsheet with the daHy operations summaries. Basically, we pumped a total of 94 bbls cement with an estimated 63 bbls behind pipe. The memory SCMT log was run and a preliminary review shows we have good cement above and below the squeeze perfs 8935-40' MD. This means we should have isolation from the overlying Ugnu. I had hoped to have the log available to show you this week, however, it needs to be depth shifted and Schlumberger does not have the ability to do it in town. It is now in Japan being depth shifted and reprinted. When I get it, I'll bring a copy over for you to review. In the meantime, I'd like to get approval to bring MPS-21 back on injection. We currently have three producers that are suffering due to it being shut in. Please let me know if I can proceed with turning the valve. Thanks, Bill Mathews 564-5476 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 24, 2004 12:35 PM To: Mathews, William L Subject: Re: MPS-21 (202-009) Future Work Hi Bill, Any update on our mend MPS-21 ?? Tom Thomas Maunder wrote: 10f5 5/25/2004 9:52 AM Re: MPS-21 (202-009) Future Work Thanks for the update. I suspected that the work hadn't come off yet. Good luck. Tom Mathews, William L wrote: Hi Tom, We had to pull off the well for some other work and are rigging back up again tonight. Hope to have the squeeze off by the weekend. Bill -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Thursday, April 22, 20044:09 PM To: Mathews, William L Subject: Re: MPS-21 (202-009) Future Work Hi Bill, Any update on the MPS-21 work?? Thanks. Tom Thomas Maunder wrote: Thanks for the info. Mathews, William L wrote: Tom, The well was shut in early March in preparation for the coil work. Coil was delayed in getting to the well. It arrived 3/30 and is still on the well setting the sand plug in preparation for the cement squeeze. Bill -----Original Message----- From: Thomas Maunder [mailto:tom- maunder@admin.state.ak.us] Sent: Thursday, April 01, 2004 2:56 PM To: Mathews, William L Subject: Re: MPS-21 (202-009) Future Work Bill, Has there been any "action" on MPS-21?? Tom Mathews, William L wrote: Thanks Tom -----Original Message----- From: Thomas Maunder rmailto:tom- ,maunder@admin.state.ak.us] Sent: Thursday, March 11, 2004 9:22 AM To: Mathews, William L 20f5 5/25/2004 9:52 AM F--e: MPS-21 (202-009) Future Work (' Subject: Re: MPS-21 (202-009) Future Work Bill, I have completed review of the proposed work for MPS-21. The sundry number is 304-075. You have advised that the March 15 work date is "good", so by copy of this email you have approval to proceed with the work. The approved copy of the sundry may not get to you in advance of the work starting. I will place a copy of this note in the file. Please have the supervisor contact the AOGCC Inspector with an opportunity to witness the BOP test. On occasion, we do try to witness work coil BOP tests. Good luck with the operation. Tom Maunder, PE AOGCC Thomas Maunder wrote: Bill, Thanks much. I do appreciate your commitment to getting the work done. I look forward to receiving the work request. Tom Maunder, PE AOGCC Mathews, William L wrote: Tom, FYI. You should be getting a Sundry Application for this work today or tomorrow. The job is slated to take place either late this weekend or early next week. Bill -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] S eJ:ït:"';"-""'F-rIday', February"---Ö"6"';"--'2"6'6'4'"''''3-''~''jT''''' PM To: Mathews, William L Cc: Steve Davies; Jim Regg; Townsend, Monte A; Archey, Pat; Petersen, Sean D Subject: Re: MPS-21 (202-009) Future Work Bill, Monte, et al: Your proposal to accomplish the repair work by the end of first quarter is accepted. The well may remain in service pending the work. According to the rig schedule that is sent to 30f5 5/25/2004 9:52 AM ~e:MPs.-21 (202-009) Future Work (' us, 4ES is planned to De in Milne during March and appears to have an "opportunity window". A sundry application (403) must be submitted for Commission approval before beginning repairs. We take the statement in your message to be a commitment to perform the work in the time frame stated. Although the upward flow may be small, confinement of any injected material to the intended interval is required by 20 AAC 25.402(b). 20 AAC 25.412(d) requires the operator to provide a cement quality log to demonstrate isolation of the injected fluids to the approved interval and two "bond" logs were run on March 9, 2002 and April 23, 2002. There is a comment in the latter log that states "found poor cement quality throughout the logged interval." Based on the assessment of that log and an interpretation that some isolation existed, a limited perforation interval was shot and the well placed in service in early December 2002. With the isolation questions in mind, it seems to have been appropriate to have run the additional diagnostic (WFL) sooner than 1 years time. We look forward to receiving the sundry for this work. Please call with any questions. Tom Maunder, PE AOGCC Mathews, William L wrote: Tom, With regards to future work efforts on Schrader injector MPS-21, it is unlikely that further diagnostics will yield better information about fluid movement behind pipe. Therefore, additional logging is not being pursued. The plan is to perform a cement squeeze to insure isolation from the overlying Ugnu sands. Zonal isolation will be evaluated with a cement evaluation log post-cement squeeze. Since all indications are that the leak behind pipe is very small, if existant above the N sand intervals, BP requests approval to leave the well on injection until remediation efforts are ready to be executed. The intention is to complete any remediation efforts by the end of lQ2004 or shut the well in. If this meets with the AOGCC's approval 40f5 5/25/2004 9:52 AM ~e:,MPs..21 (202-009) Future Work ( please provide confl.cmation. I will be out of the office until February 10. In the meantime¡ you can contact Monte Townsend at 564-4602 or via e-mail at(towTIsema@bp.com) . Bill Mathews Lead Schrader PE 564-5476 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday¡ January 15¡ 2004 11:38 AM To: Mathews¡ William L Cc: Steve Davies¡ Jim Regg Subject: MPS-21 (202-009) Future Work Bill¡ Thanks for bringing over the water flow log. As you noted previously¡ there appears to be evidence that the injected water is moving up from the perforated interval to other sands that are present. Due the multiple pipe strings¡ it was not possible to determine if any flow was going shallower than the tubing tail. You shared our Concerns regarding potential fluid movement higher in the wellbore and agreed that it is prudent to determine if such flow may exist and if so to propose methods to eliminate it. Several diagnostic (borax or temperature logs) and remedial (different squeezes or a sidetrack) were mentioned. You indicated that you would contact Monte Townsend and/or others to discuss the well's condition and get back to us with a recommendation of what work will be performed. It was indicated that you would get back to us in the "short term" with a work proposal possible early next week. We look forward to receiving the diagnostic/remedial work plans for the well. Determining whether flow exists shallower in the wellbore and¡ if so eliminating it will be critical for the continued operation of this well. I will be out of the office for the next 2 weeks. In my absence¡ please communicate with Steve or Jim Regg. Tom Maunder¡ PE AOGCC 50f5 5/25/2004 9:52 AM MPS-21 -- 202-009 DAILY SUMMARY 5/3/2004 " Continued from WSRof 5/2104. Clean oUt to 9232jetting with 1 % XSKCL andflo-pró,' JetWhile pulling OOM at 40%;. RIH with SCMTlogging tool to 9200 CTMD.Did nöt ~gTD due to tool configuration. Log up and down passes from 92ooto , 8900 åt 30fPm. One pass with. 0 pressureànd1while injecting 'into well at 05 bfmwith850psLPOH.Field interþretëitiorlöf CBLshoWs cementquàtitÿaciosssqueezed interval has ímproved.{dowriunþn~ssurized pass). Final interpretàtion\Viffbe done in town.' RIHto 2500~nd freeze protect well withMEOR PORRDMO. " 5/2/2004 Continued from WSR of 5/1/04. Clean out to 9146 using alternating slugs offlo-pro and XSKCL. Start to loose returns. Chase final 2 bbls of fill to surface as POH. RU N2 . Clean out to 9200. Chase slug out of hole. RBIH and dry tag fill at 9157 CTMD. On line to circ out last sand for rat hole. Job in progress. 5/1/2004 MIRU unit 9. RIH with 2" JS nozzle. Tag TD at 8987 (up). Start jetting fill. Job in progress. 4/30/2004 Continued from WSR of 4/29/04. Continue to chase returns out of hole. OOH. MU 2" JS nozzle and pressure test squeeze to 1500 psi. JFT at 500 psi. Injectivity at 1400 is 0.25 b/m. When SD pumping pressure falls to 188 in 30 minutes and holds. RIH with 2" JS nozzle. Check out pipe. Find 3 bad spots. POH and freeze protect well to 2500' with 50/50 MEOH. - Blow down coil with N2 for pipe swap. RDMO **** Notify PO of well status, well shut in Will return after pipe swap **** Job incomplete **** 4/29/2004 Continued from WSR of 4/28/04. Continue milling to 8984' 15 stalls, no progress. POH to inspect tools. 1 arm broken, all arms worn, no tool parts lost in hole. Job scope tool change. Wait on Baker.MU/RIH with Baker undereamer and 3 blade pilot mill. Tag at 8986' - mill to 8995. Good rate of penetrration at this point. Drop ball to shear circ sub. Job in progress. 4/28/2004 MIRU CTU # 9 - MU/RIH with WOT 2.37" Undereamer dressed with 5.75" blades. Tag up at 8954 CTMD. Mill cement to 8959 using alternating sweeps of flo-pro and KCL. Job in progress. 4/25/2004 Continued from WSR of 4/24/04. Tag TD at 8982 (up) CTMD. ( looks like about 5' of cement on top of sand. ) Mix and pump 47 bbls 15.8 ppg LARC cement. lay in and squeeze with 2000 psi at surface. (estimate 16 bbls cement behind pipe.). Hold for 1 hr. Release squeeze pressure to 300 and RIH to contaminate. wash jewelry on trip out of hole. FP well. trap 640 psi on well. RDMO. **** Notify DSO of well status. leave well shut in - return in 2-3 days for FCO **** 4/24/2004 Continued from WSR of 4/23/04. RIH with 2" cementing nozzle. Tag TD and reset counter to 8977. Pump 25 bblos 12% HCl with additives (field titration- ) Pre,.acid injectivity is 1.3 blm at 839 psi and post acid injectivity is 1.3 at 780 psi. Overdisplace with 50 bbls KCL. KilUCool well, mix/test cmt.Pump total 47 bbls 15.8 LARC Cmt. Unable to obtain squeeze pres. Flush cmt into perfs POOH, RBIH with 2" cementing nozzle. Job in progress. 4/23/2004 Continued from WSR of 4/22/04. RIH with logging tools. Tag sand top at 8991 (down) and 8987 (up). NOTE: These are uncorrected depths. log up to 8600 and flag pipe. Pressure up tubing to 1500 psi. loose 900 psi in 4 minutes. Retag top of sand. POOH with logging toolsVerify good data. Corrected TOS at 8977'(up). MU/RIH w/SWS 5' - 2" -6spf - 60° - perf gun. Perf squeeze int 8935' - 8940' . Inj test at 8670' - 1 bpm/820psi- 2 bpm/1280 psi - 2.7 bpm/1500psi - 3 bpm/1620psi. POOH - Inj test at surface - 1 bpm/700psi - 2 bpm/965 psi - 2.7 bpm/1155psi - 3 bpm/1250psi. Break off well, all shots fired, recover ball. MU 2" BDN stab onto well. PT 200 14000psi. Job in progress. 4/22/2004 MIRU unit 9. Perform weekly BOP test. Test valves individually in squeeze skid. Job in progress. 4/11/2004 Tagged TD @ 8965'wlm. Drifted tubing with a 10'x2" bailer, and 2.80" swage. obtained a 20' correction off of XN nipple. Corrected TD is 8985'. 4/4/2004 Continued from 4/1/04 AWGRS. MIRU CTU#8. RIH with 2.72" JSN drift. Pulled erratic and heavy on wt check at 2700', start cleaning out tubing. Sand returns at surface. Clean out to IT with bio sweeps. Returns not cleaning up after two bio pills pumped from IT at surface. POOH at 80%. At surface, injectivity test could not establish rate. Pressure up to 1000 psi, loose 250 psi in 5 min, 600 psi in 30 min. Well freeze protected and shut in. Move unit to MPF-83 for IPROF, evaluate options for next step on S-21. 4/2/2004 Attempted to get down with 2", and 2.5" dump bailers full of silica sand to dump on top of frac sand laid in by CTU. Sand plug is not holding psi solid and CTU left for unit maintenance due to radiator leak. Were unable to do so due to 77+ deg. deviation and frac sand in the tubing at 2978' wlm. RDMO. 4/1/2004 Continued from 3/31/04 AWGRs. RIH with 2-1/4" sand dump nozzle. Tag sand top of 9206'. Pump 1st sand stage - 2550 Ibs 20/40 carbo lite. Wait for sand to settle, tag new sand top at 9096'. Pump 2nd sand stage - 1550 Ibs 20/40 carbolite. Wait for sand to settle, tag new sand top at 9040'. Pump 3nd sand stage - 1100 Ibs 20/40 carbolite. Wait for sand to settle, tag new sand top at 8978' Pressure up to 700 psi, slow bleed off. POOH, maintaining 300 psi on WHP. FP to 2500'. Well left shut in, unit will resume job 4/3/04. 3/31/2004 Continued from 3/30104 AWGRS. BOP test. Flush well with warm water. RIH to clean tubing of sand. Dry tag sand top @ 9216'. POOH at 80% from tubing tail. FP and lay back unit for the night, will rig back up in a.m. Well left shut in. ".. .. 3/30/2004 Sandback perfs/ Adperf/ Set retainer/ Acidize/Cmt Squeeze. CTU #8. MIRU. Fluid pack well with 1 % KCL. RIH with 2" reverse out nozzle. Tag at 9301' ctm, correct to 9338'. Lay in 33 bbls of 8ppg carbolite slurry to 6800'. PUH to 6500'. Wait 1 hr to RIH to tag. RIH to 9140' no tag. POOH, carbolite slow falling. Let settle out over night. Freeze protect well with 30bbls crude. LO injector, secure well for night. Notify pad operator. Continued on 3/31/04 WSR. 3/14/2004 Tagged TO @ 9310'wlm (9338'cwlmd), used 28' correction from tag on 12-20-03, tools fell very slow (20FPM-70FPM) from 6450'wlm-9310'wlm and the TEL that was utilized failed to activate. The tag depth is exactly the same as seen on 12/20/03. ROMO. Fluid level shot down the tubing and fA showed both were fluid packed. 3/12/2004 Freeze protect tubing with 20 bbls meoh from the divert shelter for shut down for upcoming CTU squeeze work. Re: MPS-21 (202-009) Future Work Subject: Re: MPS-21 (202-009) Future Work From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 11 Mar 200409:22:10 -0900 To: "Mathews, William L" <MathewWL@BP.com> Bill, I have completed review of the proposed work for MPS-21. The sundry number is 304-075. You have advised that the March 15 work date is "good", so by copy of this email you have approval to proceed with the work. The approved copy of the sundry may not get to you in advance of the work starting. I will place a copy of this note in the file. Please have the supervisor contact the AOGCC Inspector with an opportunity to witness the BOP test. On occasion, we do try to witness work coil BOP tests. Good luck with the operation. Tom Maunder, PE AOGCC Thomas Maunder wrote: Bill, Thanks much. I do appreciate your commitment to getting the work done. receiving the work request. Tom Maunder, PE AOGCC I look forward to Mathews, William L wrote: Tom, FYI. You should be getting a Sundry Application for this work today or tomorrow. The job is slated to take place either late this weekend or early next week. Bill -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.st:ate.ak.us] Sent: Friday, February 06, 2004 3:31 PM To: Mathews, William L Cc: Steve Davies; Jim Regg; Townsend, Monte A; Archey, Pat; Petersen, Sean D Subject: Re: MPS-21 (202-009) Future Work Bill, Monte, et al: Your proposal to accomplish the repair work by the end of first quarter is accepted. The well may remain in service pending the work. According to the rig schedule that is sent to us, 4ES is planned to be in Milne during March and appears to have an "opportunity window". A sundry application (403) must be submitted for Commission approval before beginning repairs. We take the statement in your message to be a commitment to perform the work in the time frame stated. Although the upward flow may be small, confinement of any injected 10f3 3/11/2004 9:24 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ( ( 4, 7/ í ( DfJ'-::r 3//~ ~ , 1. Type of Request: 0 Suspend 0 Operation Shutdown D PerforateD waiverD Abandon Alter CasinÇ) 0 RepairWell [&] PluÇ) Perforations D StimulateD Time Extension 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 Annular Disposal D OtherD 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 202-0090 BP Exploration (Alaska), Inc. Development D Exploratory D Stratigraphic D Service ŒI 9. Well Name and Number: M PS-21 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 4425.9 9359 4280.6 Size MD TVD 6. API Number 50-029-23065-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 73.25 KB 8. Property Designation: ADL-380109 3. Address: 11. Total Depth MD (ft): 9453 Casing Length Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom Conductor 79 20" 91.5# H-40 33 112 33.0 112.0 1490 470 Production 9411 7" 29# L-80 32 9443 32.0 4418.2 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9140 - 9160 4195 4208.3 3.5" 9.3 # L-80 30 8903 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 12. Attachments: Description Summary of Proposal ~ Packers and SSSV MD (ft): 8857 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch 0 Exploratory 0 DevelopmentD Service ŒI 14. Estimated Date for March 15, 2004 15. Well Status after proposed work: Commencing Operatiol Oil D Gas 0 Plugged 0 16. Verbal Approval: ¡.I~!e: ~o.~~\\ ,~~ WAG D GINJD WINJŒ) Commission Representative: ~~~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Abandoned 0 WDSPLn Prepared by ~ry Catron 564-4657. Contact William Mathews :~~:~:ame ¡~ Title Petroleum Engineer Phone 564-~C"~- -,ç~~\ø 2/23/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: .3ð1-ð76 Mechanciallnt~ty Tes~ D. Loca:on Clearance 0 ~,~ ~\ö...,,-~~J :;.500 y>t ~"'-\~\..)t,",~a~~~' BY ORDER OF ~ /" ðf THE COMMISSION Date: V" -.:>" '------ [)&lU~~~ ORIGINAL ~i~~ l. ?rnJ)b, MAR 1 0 200t Ala~ka Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE bp .,. ,\I,.,,,. -.....~ ~..~ ~~- ~~~ ...~ ¡t... .,.,.,.\- ". ( To: D. Cismoski/John Smart, GPB Well Ops TL NSU, ADW Well Operations Supervisor Date: March 9, 2004 From: Jennifer Julian, Design Engineer Subject: MPS-21 i Retainer Saueeze AFE MSSPDWL21-N Est. Cost: $180 M lOR: 500 BOPD Please perform the attached squeeze procedure. This procedure includes the following steps: Step Type Procedure 1 S Drift & tag for tubing punch, retainer. (Pre squeeze) 2 C Sand back. Shoot squeeze perfs. Acidize. Squeeze w/ 1 run retainer 3 C WOC 2 days. Mill retainer & cement. FCO sand. SCMT. Reperf (post sqz) Max Deviation: Deviation through perfs: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: 70-77 deg from 2800-8500' 50 deg 2.813" @ X & XN nipples @ 2224,8834,8891' tagged fill @ 9310' wlm (9338' rkb )--12/20/03 Waterflow log 12/24/03 Not in database The primary purpose of this squeeze is to repair a poor primary cement job confirmed by a waterflow log (12/24/03). Lower perfs will be protected with a sand plug and squeeze perfs will be shot prior to squeezing. CT will then set a Weatherford 1-trip squeeze retainer in the tubing for the cement squeeze. After WOC, the retainer and cement will be milled up and the sand plug will be cleaned out. A SCMT will be run to ensure that adequate cement has been placed behind pipe for zonal isolation and reperfs will be shot. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W)564-5663, (H)274-0929, (Cell)240-8037. cc: w/a: Well File W. Mathews J. Julian North Slope Distribution w/o: S. Rossberg Page 1 of 6 MPU S-21 i Squeeze 3-1/211 tubing . 3.511 XN Nipple at 88341 ~-=- packer at 8857' tEl ~ Weatherford 1 run retainer set @ 88971 ELM 3.511 XN Nipple at 88911 .~~ &&t]%t111. TT at 8903' ~- ~hoot Circ holes at 8935-8940' ~ ~ :,'.:" ~ . :~ '''.', ~i(,\ç-s .~~") c \,«'\0"-.) \\ Sandt p target @ 89501 ~ ~X1;~:N';.~;;,; (Window 8950-8985) ~ :,".:"!¡:".':.:... Ii Perfs @ 9140-91601 711 casing Last tag @ 93381 2 3 (' MPU S-21 ¡Squeeze MPU S-21 i Squeeze Squeeze Taraet Repair bad primary cement job on injector. Pre-Squeeze Slickline 1. RU SL. 2. Drift and tag PBTD. Important to obtain accurate ELM. Note that DD are on depth with ELM. 3. Drift tbg for Weatherford one run retainer and tubing punch (Retainer to be set at 8897' ELM) 4. Shoot fluid levels on IA and tubing. CTU Sand Plua. Shoot perfs. Set Retainer. Acidize. Squeeze NOTE: (Eline depths have a 0' correction to DD) 5. RU CT and squeeze equipment. Load well as necessary. \ '" i'o\.\ç.'j ~06CC'ti-~~(L,-~~ C>~ ßa ~-\fès'~ 6. PT & RIH with sand drop nozzle (no clìecks). ' 7. Fluid pack well and RIH. 8. Dry tag bottom with nozzle and correct to SL depths. 9. Lay in carbolite to tarQet depth of 8950' with a window of 8950'-8985' ELM. See attached Carbolite Plug worksheet. Carbolite is requested because it will be easier to clean out than river sand after the squeeze is complete. 10. Allow sand to settle and retag. Adjust as necessary. 11.After sand top is within window, MIT well to ensure that no fluid can get past the sandplug. If fluid is leaking past sandplug, plan on dumping CaC03 cap on top. POOH 12. RI H wI CT conveyed perf gun wI mechanical TEL, correct to tubing tally (DD is on depth with ELM), shoot deep penetrating squeeze perfs from 8935' - 8940' ELM at 4 SPF, random orientation (Reference SWS CBL 4-23-2002). POOH. 13. Pump down the tubing to confirm squeeze perfs are open and injectivity is sufficient for squeeze. 14. Pick up BHA wI Weatherford 3-1/2" FH one run retainer and setting tool and RIH. 4 MPU S-21i Squeeze 15. At about 8850', liquid pack the tubing with 80 deg (SHBT is 82 F) 1 % KCI. It is important to make sure that water is not warmer than this as it will accelerate cement set time. Tubing volume to the retainer is 77 bbls. (WHP with full column of seawater should be ~150 psi). 16. Prior to setting retainer, determine whether well is on vacuum by shutting down injection and allow WHP to stabilize for a few minutes. Pump diesel or crude freeze protect as necessary to achieve positive WHP prior to setting retainer. 17. Drop ball to set retainer at mid pup joint at 8897'. Confirm retainer is set by pressure testing tubing by CT annulus to 1000 psi. Do not stina out of retainer at any time until SQueeze completed. Note: The retainer 00 will need to be turned down to pass the no-go, but per Weatherford that is not a problem and will not effect the performance of the plug. The retainer is being placed below the nipple to reduce chance of problems during millout. 18. Come on line down CT to confirm injection through retainer. 19. RU acidizing equipment and pump the following down the coil through the retainer a) Establish injectivity b) 25 bbl 120/0 HCI-100/0 Xylene c) 50 plus bbls of overflush water HCI Acid Additives /concentrations- Acceptable acid concentrations +/-1.50/0 for HCI Corrosion Inhibitor (variable) Non-emulsifier (NOT REQUIRED) Surfactant 0.2% Dispersion Stabilizer (1.5%) I ron Reducing Agent (20 ppt) Fe +3 concentration 0.60/0 A261 , 8 ppt A 153,4 ppt A 179 W54, W35 F103 U74 L58 <300 ppm *Concentration & additives can be determined per current best practices. 20. After pumping overflush, drop to minimum rate down coil. 21. RU cementing equipment and batch mix 45 pumpable bbls LARC cement (BP liner blend) to meet the following specifications. ***Please note that this is a preliminary blend and the lab was playing with retarder concentrations to stretch out the thickening time a little more. 5 Volume to Pump Cement Type Thickening Time Fluid Loss Target Acceptable Range Rheology MPU S-21 i Squeeze 45 bbls total 15.8 ppg Liquid Latex Acid Resistant G + 3% 0174 + 0.5% 0065 + 0.16% 0800 + 1 % 020 + 1.2 gal/sk 0600G + 0.2 gal/sk M45 Yield = 1.21 cu ft/sk Mix Fluid = 5.324 gal/sk 45 bbl Neat Cement Filter Cake .8511 firm cake :f: 0.1511 in lab 5 hours to 70 Bc 70 cc/30-minutes at 80°F BHCT 50 - 90 cc/30-minutes at 80°F BHCT YP>5 with no settling or gelation in fluid loss cell. 22. Catch a sample of the cement for QC testing. Once the blend is approved, line up cementers to the coil. 23. Line out cementers to the CT. Pump the following down the coil at about 3000 psi CTP: . 10 bbls spacer water . 45 bbls neat LARC cement . One coil volume of spacer water . 1.5# biozan gel for cement clean-out SAFETY: 45 barrels of cement would extend up the tubing to 5172' ELM if no cement is placed below the retainer (if the retainer leaked). 24.lf CT pressure increases to -3000 psi while pumping into the retainer, plan to unsting from retainer, lay in remaining cement and go to clean out step 25. Note per Lyle Savage, Weatherford: There is no problem pulling the stinger out of the retainer under pressure. The valve travels fully closed before the shear pins can be effected to release the stinger. Also, in answer to my question to Weatherford about how much pressure differential the retainer could take and still remain stung in, Lyle replied: Pressure differentials while pumping are positive down on the stinger because the retainer ID is smaller than the coil OD. That plus whatever we can apply from surface by sitting down on the coil is more than enough to keep us stung in, up to any pressures we will work with through the CT. 25. With one bbl of cement left in the coil, unsting coil from retainer and lay in the remaining bbl of cement on top of the retainer. PUH to safety at 5072'. 6 MPU S-21 i Squeeze (Probably want to pull much higher than this due to the small capacity of 3-1/2" tubing. Note: Monitor IA pressure during the squeeze to ensure retainer remains set. 26. Open the choke on the backside and begin pumping biozan down the CT for clean out to maximum depth of 8875' MD. (Retainer is set at 8897' -would like to leave .....10' good cement on retainer). 27. Switch to friction reduced water. Make several passes from retainer to safety. Take barrel count to ensure 1:1 returns. Jet uphole at 80% running speed and max CT pressure, washing all jewelry thoroughly. Monitor wellhead pressure to for inflow in the remote case that the retainer valve doesn't hold. 28. Freeze protect the top 2,500' of the well bore while POOH. Post-Saueeze CT Mill Cement Pluq 29. RU CTU, N2 unit, and RIH with mill and motor and mill through the retainer and cement to carbolite top. If desired, pull out of hole to change BHA to swirl jet nozzle to clean out carbolite. After breaking through interface, pressure up against squeeze perfs to 1500 psi. If significant leak off is noted, contact Jennifer and Bill and plan on continuing clean out so an SCMT can be obtained. 30. Clean out sand to 9300'. 31. Run CT memory SCMT. Contact Bill Mathews at 564-5476 (w) 440-8496 (cell) with results prior to perforating. 32. Reperf 8934-8938' (pending results of SCMT) deep penetrating shots, 1 spf, random orientation, 90 degree phasing (Ref SWS CBL 4/23/02). NOTE: 9140- 9160' may be reshot, depending on results of SCMT. 33. Put well on injection, maximum wellhead injection pressure is 1500 psi. 7 ( ( Mathews, William L From: Sent: To: Cc: Subject: Thomas Maunder [tom_maunder@admin.state.ak.us] Friday, February 06, 2004 3:31 PM Mathews, William L Steve Davies; Jim Regg; Townsend, Monte A; Archey, Pat; Petersen, Sean D Re: MPS-21 (202-009) Future Work Bill, Monte, et al: Your proposal to accomplish the repair work by the end of first quarter is accepted. The well may remain in service pending the work. According to the rig schedule that is sent to us, 4ES is planned to be in Milne during March and appears to have an "opportunity window". A sundry application (403) must be submitted for Commission approval before beginning repairs. We take the statement in your message to be a commitment to perform the work in the time frame stated. Although the upward flow may be small, confinement of any injected material to the intended interval is required by 20 AAC 25.402(b). 20 AAC 25.412(d) requires the operator to provide a cement quality log to demonstrate isolation of the injected fluids to the approved interval and two "bond" logs were run on March 9, 2002 and April 23, 2002. There is a comment in the latter log that states "found poor cement quality throughout the logged interval." Based on the assessment of that log and an interpretation that some isolation existed, a limited perforation interval was shot and the well placed in service in early December 2002. With the isolation questions in mind, it seems to have been appropriate to have run the additional diagnostic (WFL) sooner than 1 years time. We look forward to receiving the sundry for this work. Please call with any questions. Tom Maunder, PE AOGCC Mathews, William L wrote: >Tom, >With regards to future work efforts on Schrader injector MPS-21, it is unlikely that further diagnostics will yield better information about fluid movement behind pipe. Therefore, additional logging is not being pursued. The plan is to perform a cement squeeze to insure isolation from the overlying Ugnu sands. Zonal isolation will be evaluated with a cement evaluation log post-cement squeeze. > >Since all indications are that the leak behind N sand intervals, BP requests approval to leave efforts are ready to be executed. The intention the end of 1Q2004 or shut the well in. > >If this meets with the AOGCC's approval please provide confirmation. I will office until February 10. In the meantime, you can contact Monte Townsend at via e-mail at(townsema@bp.com) . > >Bill Mathews >Lead Schrader PE >564-5476 pipe is very small, if existant above the the well on injection until remediation is to complete any remediation efforts by be out of the 564-4602 or > >-----Original Message----- >From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] >Sent: Thursday, January 15, 2004 11:38 AM 1 >To: Mathews, William L >Cc: Steve Davies; Jim Regg >Subject: MPS-21 (202-009) Future Work > > >Bill, >Thanks for bringing over the water flow log. As you noted previously, >there appears to be evidence that the injected water is moving up from >the perforated interval to other sands that are present. Due the >multiple pipe strings, it was not possible to determine if any flow was >going shallower than the tubing tail. You shared our concerns regarding >potential fluid movement higher in the wellbore and agreed that it is >prudent to determine if such flow may exist and if so to propose methods >to eliminate it. Several diagnostic (borax or temperature logs) and >remedial (different squeezes or a sidetrack) were mentioned. You >indicated that you would contact Monte Townsend and/or others to discuss >the well's condition and get back to us with a recommendation of what >work will be performed. It was indicated that you would get back to us >in the "short term" with a work proposal possible early next week. >We look forward to receiving the diagnostic/remedial work plans for the >well. Determining whether flow exists shallower in the wellbore and, if >so eliminating it will be critical for the continued operation of this >well. I will be out of the office for the next 2 weeks. In my absence, >please communicate with Steve or Jim Regg. >Tom Maunder, PE >AOGCC > > > 2 (' STATE OF ALASKA ( ALASKA '\"..... AND GAS CONSERVATION COMM( ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 0 GINJ a WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3300' NSL, 223' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 1678' NSL, 1194' WEL, SEC. 02, T12N, R10E, UM Total Depth: 1758' NSL, 1396' WEL, SEC. 02, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565787 y- 5999967 Zone- ASP4 TPI: x- 559505 y- 6003572 Zone- ASP4 Total Depth: x- 559302 y- 6003650 Zone- ASP4 18. Directional Survey 0 Yes a No 21. Logs Run: MWD , GR , RES, CCL 22. One Other 5. Date Comp., Susp., or Aband. 8/18/2002 6. Date Spudded 1/31/2002 7. Date T. D. Reached 2/712002 8. KB Elevation (ft): KBE = 73.25' 9. Plug Back Depth (MD+ TVD) 9359 + 4354 10. Total Depth (MD+TVD) 9453 + 4426 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL . CASING SIZE,"'" 20" 7" , W¥;,PER'¡:E. .,'. .GRÁ¡)E. 92# H-40 26# L-80 CASING, LINER AND CEMENTING RECORD . .SE1:TfN(lOEFITf~Þ , SETrINGPE~ffrJD, :' tiÇ>~e ' . ,Top' "~IBort(1jM >'.Top' ". ';BßTTOM:"::;,,S'ZE'.' 33' 111' 33' 111' 42" 33' 9444' 33' 4419' 9-7/8" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8", Gun Diameter, 4 SPF MD TVD MD 9140' - 9160' 4195' - 4209' 26. Date First Production: December 12, 2002 Date of Test Hours Tested 24. SIZE 3-1/2",9.3#, L-80 TVD Revised: 01/13/04 Peñorations 1b. Well Class: 0 Development 0 Exploratory 0 Stratigraphic Test a Service 12. Permit to Drill Number 202-009 13. API Number 50- 029-23065-00-00 14. Well Name and Number: MPS-21i 15. Field / Pool(s): Milne Point Unit 1 Schrader Bluff Ft Ft 16. Property Designation: ADL 380109 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PULLED I ' , . : " .Ce;f1ItfEtíffING.RecoRD 260 sx Arctic Set (Approx.) 1236 sx PF 'L', 327 sx 'G', 88 sx 'C', (Top Job) 96 sx PF 'L' TuåJNGRECORD DEPTH SET (MD) 8903' PACKER SET (MD) 8857' 25. ',ACtD,fRACT~RE,CEMENTSQU~~E; ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL GAs-McF WATER-BsL OIL GRAVITY-API (caRR) Press. 24-HoUR RATE 27. CORE DATA RE(':E:",\/cn Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separat~ ~Mf necessary). Submit core chips; if none, state "none". JAN 1 6 2004 None Alaska Oil & Gas Cons. Commission ¡A. L Anchorage L ~ .IAN 2 100~ l>\- Form 10-407 Revised 12/2003 W A TER-BsL CONTINUED ON REVERSE SIDE CHOKE SIZE GAS-OIL RATIO 28. ( GEOLOGIC MARKERS 29. ( ~MATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SBF2-NA 8878' 4038' None SBF1-NB 8925' 4063' SBE4-NC 8982' 4096' SBE2-NE 9006' 4110' SBE1-NF 9086' 4157' TSBD-OA 9131' 4115' TSBC 9174' 4218' TSBB-OB 9214' 4246' SBA5 9257' 4277' RECEll/t:> JAN 1 6 ?nnl1 Alaska Oil & Gas Anchorage 30. List of Attachments: 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. I " ¡ ¡ Signed sondra~tewman ~ r~e Technical Assistant Date Ö l...l::S -0",/ MPS-21 i 202-009 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No. / 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. ITEM4b: 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". Form 10-407 Revised 12/2003 OR\G\NAL Tree: Cameron 7-1/16", ( Wellhead: FMC 11' gen 6 4.5' hanger w/4.5" TC-II T&S CIW 4" H-profile 20"x 34" insulated, 215 #Ift A-53 1- A iHI KOP @ 300' Max. hole angle = 70 - 77 deg F/2800' - 8500' Hole angle thru perfs = 50 deg. 7" 26#, L-80, BTRC Casing (drift 10 = 6.151, cap.= .0383 bpf) 3.5", 9.2 ppf, L-80 1ST but. Tbg. (cap. = 0.0087 bpf, drift = 2.867") Perforation Summary Size Spf 2.5" 4 Interval OA Sands 9,140'-9,160' 4,195'-4'209' OB Sands NIA (TVO) 33/8" HSD 4spf, Random phasing,34B HJ II, RDX DATE 02/11/02 8119102 REV. BY Lee Hulme MDO MPU 5-21 i 1;181 n ~ ~ ~ COMMENTS Drilled & Cased by Nabors 27-E Orig. OF Elev. = 73.25' Orig. GL Elev. = 39.00' 3.5" HES X-Nipple (2.813" ) r 2,224' I 3.5" HES X-Nipple ( 2.813" ) I 8,834' I 7" x 3.5" Baker "S-3" Perm. packer I 8,857' I 3.5" HES XN-Nipple 2.813" Pkg. I 8,891' I (No-Go 2.75" id ) I I 3.5" WELG 8,903' ELMD I I Short joints 9015'-9034' ~ 7" Halliburton Float Collar 7" Halliburton float shoe 9,359' 9,443' Initial Completion Nabors 4-es I Perfs MILNE POINT UNIT WELL No.: 5-21 i API: 50-029-23065-00 BP EXPLORATION (AK) 1/15/2004 1:19 PM 1 of 1 Bill, Thanks for bringing over the water flow log. As you noted previously, there appears to be evidence that the injected water is moving up from the perforated interval to other sands that are present. Due the multiple pipe strings, it was not possible to determine if any flow was going shallower than the tubing tail. You shared our concerns regarding potential fluid movement higher in the wellbore and agreed that it is prudent to determine if such flow may exist and if so to propose methods to eliminate it. Several diagnostic (borax or temperature logs) and remedial (different squeezes or a sidetrack) were mentioned. You indicated that you would contact Monte Townsend and/or others to discuss the well's condition and get back to us with a recommendation of what work will be performed. It was indicated that you would get back to us in the "short term" with a work proposal possible early next week. We look forward to receiving the diagnostic/remedial work plans for the well. Determining whether flow exists shallower in the wellbore and, if so eliminating it will be critical for the continued operation of this well. I will be out of the office for the next 2 weeks. In my absence, please communicate with Steve or Jim Regg. Tom Maunder, PE AOGCC Subject: MPS-21 (202-009) Future Work From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 15 Jan 2004 11:38:16 -0900 . . - . -, . . To-:·.ßillMathe~s<µ1a~hewwl@bþ.cºm>· - . CC:-.Steve:riåvìes.<Steve~daVìè~@ådînìtt~·§tat<:~~ak~us>, JiritRegg' <j~regg@ä~iIì.state.ak~ú~>··' . ( I MPS-21 (202-009) Future Work Re: MPS-21 (202-009) ( Subject: Re: MPS-21 (202-009) From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Mon, 12 Jan 2004 15:54:01 -0900 To: "Mathews, William,L"<MathewWL@BP.coII1> Yes Bill. I would like an opportunity to review the log with you. Were you able to determine where upward flow ceased or did finally getting to the tubing tail make interpretation difficult?? Do you have any temperature logging information?? I am concerned with regard to the external isolation around the casing. The SCMT doesnt indicate that there is much (if any) and the results you have from the WFL seem contrary to what would have been assumed up front. This should make for an interesting discussion. I will be heading south for a couple of meetings next monday and be gone for 2 weeks. Will it be possible to look at the log prior to my departure?? Tom Maunder, PE AOGCC Math~ws, Williflm L wrote: Tom, You are correct, this is one of the early ones that was not reciprocated. Ama:ping what pipe movement can do for you! I will request Schlumbeiger send you a hard copy of the WFL. When you get it, I'd be happy to review it with you. Gary, Please have a copy of the 12/23/03 MPS-21 WFL to Tom Maunder at AOGCC. Thanks, Bill -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, January 12, 2004 2:20 PM To: Mathews, William L Subject: Re: MPS-21 (202-009) Bill, Thanks for the reply. I presume this is one of those wells where the casing was not reciprocated for some reason. I recall that we had talked of at least a couple of other wells done early in the program at 10f3 1/13/20048:58 AM 1/12/2004 3:01 PM 10f2 Bill Mathews Lead Schrader Bluff PE 564-5476 Please contact me with further questions regarding this well and the proposed plan forward. The cement quality is marginal. The post bond log evaluation showed possible cement isolation above our target 0 sands at 9070' - 9110' md and 8682' - 8930' md. However, collars are ringing clearly and there are indications that a channel may exist. The well was perforated in the OA sands only from 9140' - 9160' md (ref SCMT 4/23/02) and injection was initiated. Perforations were planned in the NB, NE, and OB intervals in MPS-21 to provide injection support to newly drilled producers MPS-34 and MPS-35 and previously drilled producer H-07B, but were deferred pending further cement isolation evaluation. On December 23, 2003, a Water FLow Log was run to see if there was any fluid movement behind pipe during injection. The results were interesting. From the bond log that was run, it appears more likely that fluid movement would be down into the OB if isolation were poor. However, the WFL clearly shows fluid movement, albeit slight, up from the OA to the I1.5L.ªnd possible NA sands (8878' - 8958' md) and no fluid movement down to the OB sands. Due to the location of the tubing tail, there was no way to absolutely confirm isolation above the NA sands with the WFL. A borax/PNL log might give a more definitive answer with regards to uphole isolation if it is deemed necessary. A cement squeeze or sidetrack are possible remediations to allow for effective injection management. While these options are being evaluated, the plan is to leave the well on injection. Tom, Mathews, William L wrote: Bill, Thanks for the reply. I presume this is one of those wells where the casing was not reciprocated for some reason. I recall that we had talked of at least a couple of other wells done early in the program at MPS. Do you have an electronic copy of the WFL?? I can open .pds files. If you don't I'd appreciate a hard copy. Thanks in advance. Tom Maunder, PE AOGCC Subject: Re: MPS-21 (202-009) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 12 Jan 2004 14:20:29 -0900 To::nM,', åthews,William,L" <MathewWL@BP.com>. . . . ' , , ( Re: MPS-21 (202-009) 1/12/2004 2:55 PM 20f2 Bill, I was catching up on some injection well "auditing" and have looked at MPS-21. The bond log from April 23/ 2002 doesn't show that the cement has much quality. It appears that "something" is there, but it doesn't look too good. Would you please have a look at the log and give me your assessment? I will be out of the office from Christmas to January 5. Tom Maunder, PE AOGCC ( RE: MPS-21 (202-009) MECHANICAL INTEGRITY REPORT' '--. :.~ G RELE:J..S ~: . \ I?> ,- a d-:° çc~~'ct\<t) <ðl\~-o";) OPER & FIELD -~? \-\\\~~ v~,~~ MY ~- ~ \ ~ d()d--(JG<ì) ~?UD DA!E: ~LL NUMBER Cë..siTIg: \ :....:':ïe"!:": ~ ~ Shoe: HD :woi::g: ~l(é)- P acke:!:" ~S'\ till ,::ole Size <;'~I~ ana ~)~ TD: ~4S~ .HD.. 44~<O TVD; ?ETD: ,,~S~ HI? ~~~ TVD Shoe: ~4'-\'1 HD TVD j DV:' N h.r HD \J ~ .TVu :~~LL DATA TVD j :CP: I-m :".rD Perfs ~~ 'i () ~:}.\' -\ ,&~t) ~ '-\ \<00 to C:\d-~ \ .'. TVD i Set. ê. t: ~C?.ÞJ~IC;'~ INTEGRITY - PART /1 Annulus Press Test: ::? ; 15 min 30 min Cotril:D.ents: ,- MECHÞ~ICÞ~ INTEGRITY ) ~~<o 'D '0 \~ . \ \~O~\G~~\~~ Cement: Volumes :'. þ...mt. Liner ~~ i Csg j DV ~~.\(.)... .\" , . CÜlt -"°1 to cove:!:" per£s .~~. 'n'n \~ c~ (g:~~~ ~\<:"\<è.~-\ ..\0 c..c..::.eë, ~ \' \ ~ '/ $bò l Q ~ð ~ '6- So Theor e ti cal Toe <:"'1£.<-4 f'\.. \- \to.JC- S \L.\3 CU'-~ ' \ 'i Ò\1:..--.:J ~ 4;:) no n:.\.0"'-S~0~t---~ ~\\~ Jì" Cement Bond Log (Yes or No) 'XL~ ; ~n AOGCC File '(~~ CBL E:valua.tion, z.one above perfs C:{J~ -'CJð\ C-. \S '- "\ ~,' ~'" '\ t-\, \('~':)'.~'~ Produ~tion Log: Typ~ PART /2 .) .- Evaluation t .1 CONCLUSIONS: ? art f 1 : ?a.rt: ;2: , . { ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 01/05/03, Start Injection 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3301' NSL, 224' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 1678' NSL, 11941 WEL, SEC. 02, T12N, R10E, UM At total depth 17581 NSL, 1396' WEL, SEC. 02, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73.25' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 01/31/2002 2/712002 8/18/2002 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 9453 4426 FT 9359 4354 FT 0 Yes 181 No 22. Type Electric or Other Logs Run MWD , GR , RES, CCL 23. CASING SIZE 20" 7" Classification of Service Well Water Injection 7. Permit Number 202-009 302-246 8. API Number 50- 029-23065-00 Ft~,." 9. Unit or Lease Name f" , ,Milne Point Unit f Su "~po, 1 ¡' ' , ":"";f'. 1 O. Well Number MPS-21i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MO 1800' (Approx.) WT. PER FT. 92# 26# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 33' 111' 42" 33' 9444' 9-7/8" AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8", Gun Diameter, 4 SPF MD TVD MD TVD 9140' - 9160' 9214' - 9234' 4195' - 4209' 4247' - 4261' 27. Date First Production December 12, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BsL TEST PERIOD GAs-McF Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BSL GAs-McF CEMENTING RECORD 260 sx Arctic Set (Approx.) 1236 sx PF 'LI, 327 sx 'G', 88 sx IC', (Top Job) 96 sx PF 'L' 25. TUSING RECORD DEPTH SET (MD) 89031 PACKER SET (MD) 8857' SIZE 3-1/2", 9.3#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel WATER-BsL CHOKE SIZE GAS-OIL RATIO WATER-BsL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUb~ tLt'TV E No core samples were taken. r' 6 (ZOO ,.~ Lf -' "'..1 Alaska on & Form 10-407 Rev. 07-01-80 RBDMS BFt Co ¡.:: Submit In Duplicate g0nrì'J l~.',)1J,) ( 29. Geologic Markers Marker Name Measured Depth SBF2_NA 8878' SBF1_NB 8925' SBE4_NC 8982' SBE2_NE 9006' SBE1_NF 9086' TSBD_OA 9131' TSBC 9174' TSBB_OB 9214' SBA5 9257' 31. List of Attachments: 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4038' 4063' 4096' 4110' 4157' 4115' 4218' 4246' 4277' E Ei E .1 ÞN 0 Ó 2003 OH& 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed son~'4-~Ä Title Technical Assistant Date (~.. oS',O"~ MPS-21 i 202-009 302-246 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Steve Campbell, 564-4401 Permit No. / 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL LOG TRANSMITfAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: RE: MWD Formation Evaluation Logs: MPS-21: Digital Log Images: 50-029-23065-00 MPS-21, December 17, 2002 AK-MW-22018 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~ ¿JJo~ Cl:lv~, DtC¡ D Ala8ka{i'f " 8 2í!1J11 vii &.~. . VV.( AI¡, Cons. Co ~f'.n 'IlJ111/p.' ~f;! ~/()11 c5ioa-009 I , 391 a 0;>- {)û 9 I ] 17C¡ WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 October 09, 2002 RE: MWD FOffilation Evaluation Logs MPS-21, AK-MW-22018 1 LIS fOffilatted Disc with verification listing. API#: 50-029-23065-00 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. i\nchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. i\nchorage, Alaska 99649-6612 Date: Sign~L..- WOfL/ RECEIVED OCT 15 Ai.,,,,;,,oÎ!. J--~.... .,f\ \lit .... ~~ ~"'n ë", .', An~~~ wmmitlion "" Sc_lulB~epgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well D.S. 14-24 I )Jf!1..(J ~ 1 D.S. 14-31 J >?~ J 1 J MPS-21 ~~... COq BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 22403 RST -SIGMA 22406 RST-SIGMA 22415 CH EDIT SCMT (PDC) Log Description Date 07/10/02 07/11/02 04/23/02 RECEIVED OCT 0 1 2002 AII8ka Qf " Gal Coos. CommIU:Jn AndJcnge Blueline NO. 2437 Company: 09/24/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Re~ CD 1 1 1 .....-..,- ú OQJJr--,,) ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned IBI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ....'~---""~,..._--~. ~' .)~-;.;:~-~ , 3301' NSL, 224' ".^IE~, SEC. 12, T12N, R10E, UM ""I GOf'/';i',~T;(¡,!\',I"" '1,1,,'..','... "" ~~,v." ,,", Þ,'~ ~"~:):,':'; ;,,' At top of productive Interval ,OATS ~\ " YEtk-¡~.¡,.' . 1678' NSL, 1194' WEL, SEC. 02, T12N, R10E, UM1... $: 1$. '0:7-1 ' ~ijtrt. .Jj2 At total depth J ~R~\' r.ß ~~ ~]~1~~1 1758' NSL, 1396' WEL, SEC. 02, T12N, R10E, U~r " ~'~ ;:1: ,J~::,';~=._",,,.'-:::j 5. Elevation in feet (indicate KB, OF, etc.) 6. Lea~~ ~ ,'nd'Serial No. KBE = 73.25'". ADL 380109 . , .., .. '"''-''''''''''''''''''''' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 01/31/2002 '2/7/2002 8118/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9453 4426 FT 9359 4354 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD , GR , RES, CCL 23. CASING SIZE 2011 711 Classification of Service Well Water Injection 7. Permit Number 202-009 302-246 8. API Number 50- 029-23065-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-21i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 92# 26# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 33' 111' 4211 ,260 sx Arctic Set (Approx.) 33' 9444' 9-7/811 1236 sx PF 'L', 327 sx 'G', 88 sx 'C', (Top Job) 96 sx PF 'L' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/811, Gun Diameter, 4 SPF MD TVD 25. SIZE 3-1/211,9.3#, L-80 MD TVD 9140' - 9160' 9214' - 9234' 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 8903' PACKER SET (MD) 8857' 4195' - 4209' 4247' - 4261' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Diesel 27. Date First Production Not On Injection Date of Test HoursTested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submitcore"chips, No core samples were taken. "90MS 8Ft Form 10-407 Rev. 07-01-80 I AL SEP 2 3 2002 Submit In Duplicate 29. Geologic Markers Marker Name Measured Depth SBF2_NA 8878' SBF1_NB 8925' SBE4_NC 8982' SBE2_NE 9006' SBE1_NF 9086' TSBD_OA 9131' TSBC 9174' TSBB_OB 9214' SBA5 9257' 31. List of Attachments: (' 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. 4038' 4063' 4096' 4110' 4157' 4115' 4218' 4246' 4277' Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge f) Signed . Title Technical Assistant Date DB-28-'O'A- MPS-21 i Well Number 202-009 302-246 Permit No. / Approval No. Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( ( BP . EXPLORATION Operations Summary Report Page 1of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-21 MPS-21 DRILL +COMPLETE NABORS NABORS 27ES Start: 1/30/2002 Rig Release: 2/11/2002 Rig Number: 27E Spud Date: 1/31/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/29/2002 08:00 - 00:00 16.00 RIGU P PRE MOVE RIG MP S-15i TO MP S-21 i-WELL TO WELL IN LINE MOVE - TURNKEY MOVE 1/30/2002 00:00 - 00:30 0.50 RIGU P PRE SET PUMP MODULE 00:30 - 02:00 1.50 RIGU P PRE SET 2 ND SECTION OF PIPE SHED 02:00 - 07:30 5.50 RIGU P PRE SET CUTTING TANK - BUILD BERMS FOR CUTTING TANK - RADIATOR - SUB - MUD MODULE - LAY DOWN MACHINE- 07:30 - 14:00 6.50 RIGU P PRE ACCEPT RIG @ 07:30 - 01/30102 - NU DIVERTOR SYSTEM 14:00 - 16:00 2.00 RIGU N MISC PRE UNABLE TO ADJUST DIVERTER EXTENSION TO RIG FLOOR. RIGGED DOWN EXTENSION AND FOUND CEMENT BEHIND EXTENSION. REMOVED CEMENT AND INSTALLED RISER. 16:00 - 18:00 2.00 DRILL P SURF SERVICE RIG - TOP DRIVE 18:00 - 00:00 6.00 DRILL P SURF PU 5" DRILL PIPE - PROTECTOR'S FROZEN ON THE PINS OF EACH JOINT - STEAM EACH JOINT - DRIFT EACH JOINT 1/31/2002 00:00 - 01 :00 1.00 DRILL P SURF PU 5" DRILL PIPE FROM PIPE SHED - STAND IN DERRICK 01 :00 - 01 :30 0.50 DRILL P SURF FUNCTION TEST DIVERTOR SYSTEM - RUN ACCUMULATOR TEST WITH CO MAN - JOHN SPAULDING WITH AOGCC WAIVED WITNESS OF THE TEST 01 :30 - 08:00 6.50 DRILL P SURF CON'T PU 5" DRILL PIPE FROM PIPE SHED - STANDING BACK IN DERRICK 08:00 - 10:30 2.50 DRILL P SURF MAKE UP BIT - MTR - MWD - RIH TAG UP 111'- HELD PRE- SPUD MEETING 10:30 - 12:30 2.00 DRILL N SFAL SURF SURFACE TEST CIRC SYSTEM - RETRUNS TO SHAKERS - ENCOUNTERED PLUG IN FLOWLINE - SHUT DOWN TO FIND PLUG - BLOW DOWN TOP DRIVE - UNPLUG FLOWLINE - FOUND ICE PLUG BY SHAKER BOX 12:30 - 00:00 11.50 DRILL N SURF SPUD WELL AT 12:30 HRS @ 112' - DRILLlING FROM 112' TO 995' - WOB 20K TO 30K - RPM 70 to 80 - TO 2 TO 3 - GPM 433 - PP 1050 2/1/2002 00:00 - 07:00 7.00 DRILL P SURF DIRECTIONAL DRILL FROM 995' TO 1554' - WOB 20K TO 40K - RPM 65 - TO 4K TO 5K - GPM 430 - PP 1150 - PU 95 - SO 90 - ROT 95 07:00 - 08:00 1.00 DRILL P SURF REAM DOG LEG FROM 1554' TO 1369' - NO SUCCESS IN KNOCKING DOG LEG DOWN 08:00 - 16:00 8.00 DRILL P SURF DIRECTIONAL DRILL FROM 1554' TO 2560' - WOB 25K TO 30K - RPM 80 - TO 5K TO 6K - GPM 450 - PP 1300 - PU 100- SO 95 - ROT 100 16:00 - 16:30 0.50 DRILL P SURF CBU FOR SHORT TRIP 16:30 - 18:30 2.00 DRILL P SURF PUMP OUT 2560' TO 2032' - POOH FROM 2032' TO 1811' - TIGHT 25K OVER - PUMP OUT FROM 1811' TO 807' 18:30 - 19:30 1.00 DRILL P SURF RIG SERVICE - TOP DRIVE SERVICE - REPLACE DIE BLOCK - SERVICE GRIPPER PISTON 19:30 - 21:00 1.50 DRILL P SURF RIH - TAKING WEIGHT AT 1810' - WASH THROUGH 5'- CON'T RIH - HOLE IN GOOD SHAPE 21 :00 - 00:00 3.00 DRILL P SURF DIRECTIONAL DRILL FROM 2560' TO 3061' - WOB 20K- Printed: 2/20/2002 11 :22:45 AM BP EXPLORATION Page 2 of7 Operations Summary Report Legal Well Name: MPS-21 Common Well Name: MPS-21 Spud Date: 1/31/2002 Event Name: DRILL +COMPLETE Start: 1/30/2002 End: Contractor Name: NABORS Rig Release: 2/11/2002 Rig Name: NABORS 27ES Rig Number: 27E From - To Hours Activity Code NPT Phase Description of Operations 2/1/2002 21 :00 - 00:00 3.00 DRILL P SURF RPM 80 - TO 5K TO 6K - GPM 450 - PP 1300 - PU 115 - SO 90 - ROT 100 2/2/2002 00:00 - 15:30 15.50 DRILL P SURF DIRECTIONAL DRILL FROM 3061' TO 4849' - WOB 10K TO 30K - RPM 90 TO 100 - TO 7K TO 8K - GPM 500 - PP 1650- PU 125K - SO 90K - ROT 110K 15:30 - 16:30 1.00 DRILL P SURF CBU FOR BIT TRIP - RACK BACK ONE STAND EVERY 30 MIN 16:30 - 21 :00 4.50 DRILL P SURF POOH FROM 4849' TO 4000' - PUMP OUT FROM 4000' TO 3717' - POOH FROM 3717' TO 3518' - TIGHT AT 3517' 50K OVER - REAM FROM 3515' TO 3589' - PUMP OUT FROM 3589' TO 1743'- HOLE SWABBING - POOH TO BHA FROM 1743' 21 :00 - 00:00 3.00 DRILL P SURF PULL BHA STAND BACK - CHANGE BIT - ADJUST MOTOR FROM 1.5 TO 1.22 - DOWN LOAD MWD - UP LOAD MWD 2/3/2002 00:00 - 01 :00 1.00 DRILL P SURF RIG SERVICE - TOP DRIVE SERVICE 01 :00 - 02:30 1.50 DRILL P SURF RIH WITH BHA - HEVI-WEIGHT - TEST MWD - CON'T RIH TO 1850' TIGHT SPOT 02:30 - 07:00 4.50 DRILL P SURF WASH I REAM THROUGH RATTY HOLE FROM 1850' TO 3440' - RIH TO 3720' - WASH / REAM TO 3810' - RIH TO 4756' - PRECAUTIONARY WASH I REAM TO BTM 4861' 07:00 - 22:00 15.00 DRILL P SURF DIRECTIONAL DRILL FROM 4851' TO 7061' - WOB 10K TO 40K - RPM 60 TO 100 - TO 13K - GPM 550 - PP 2400 - PU 165 - SO 85 - ROT 125 22:00 - 23:30 1.50 DRILL P SURF CIRCULATE HOLE - 550 GPM -100 RPM - STAND BACK STAND EVERY 30 MINS -10,000 STKS - SHAKERS CLEAN 23:30 - 00:00 0.50 DRILL P SURF SHORT TRIP - PULL FROM 6922' TO 6800' TIGHT 40K OVER - PUMP FROM 6800' TO 6732' - PULL FROM 6732' TO 6642' - TIGHT @ 6642 50K OVER - REAM I BACK REAM FROM 6638' TO 6650' - STALL OUT AT 6642' PACK OFF- WORK THROUGH AREA 2/4/2002 00:00 - 01 :00 1.00 DRILL P SURF CONTINUED PUMPING OUT OF THE HOLE TO 6264'. 01 :00 - 03:30 2.50 DRILL P SURF CIRCULATE AT 530 GPM, ROTATE AT 100 RPM STANDING BACK ONE STAND EVERY 30 MINUTES. PUMPED OUT WHILE CIRCULATING FROM 6264' TO 5982'. CUTTINGS INCREASED ACROSS SHAKER. SHAKER CLEANED UP. 03:30 - 11 :30 8.00 DRILL N WAIT SURF CONTINUED PUMPING OUT OF HOLE TO 4522'. PULLED OUT OF HOLE FROM 4522'-2687'. HOLE PULLED TIGHT AND BEGAN SWABBING. MADE UP TOPDRIVE AND PUMPED OUT OF HOLE TO 2405'. PUMPED AND ROTATED OUT OF THE HOLE FROM 2405' TO 1837'. PULLED OUT OF HOLE AND STOOD BACK BHA. 11 :30 - 13:00 1.50 DRILL N WAIT SURF THAW AND CLEAN RIG FLOOR. 13:00 - 14:30 1.50 DRILL N WAIT SURF PERFORMED ANNUAL PM WORKORDERS ON DRAWWORKS WHILE WAITING ON PHASE 3 WEATHER CONDITIONS. 14:30 -15:30 1.00 DRILL N WAIT SURF SERVICE TOP DRIVE AND BLOCKS WHILE WAITING ON PHASE 3 WEATHER CONDITIONS. Printed: 2/20/2002 11 :22:45 AM ( ( BP EXPLORATION Operations'SummaryReport Page 30f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-21 MPS-21 DRILL +COMPLETE NABORS NABORS 27ES Start: 1/30/2002 Rig Release: 2/11/2002 Rig Number: 27E Spud Date: 1/31/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 2/4/2002 15:30 - 17:30 2.00 DRILL N WAIT SURF CUT AND SLIP DRILL LINE WHILE WAITING ON PHASE 3 WEATHER CONDITIONS. 17:30 - 18:30 1.00 DRILL N WAIT SURF CHANGED OUT ALL DIES IN GRIPPER WHILE WAITING ON PHASE 3 WEATHER CONDTIONS. 18:30 - 00:00 5.50 DRILL N WAIT SURF GENERAL MAINTENANCE AND CLEANING ON RIG WHILE WAITING ON PHASE 3 WEATHER CONDITIONS. 2/5/2002 00:00 - 10:00 10.00 DRILL N WAIT SURF WAITING OF PHASE 3 WEATHER. 10:00 - 12:00 2.00 DRILL N WAIT SURF UPLOADED MWD. RAN IN HOLE WITH DRILLING ASSEMBLY TO 2873'. WORKED THROUGH TIGHT SPOTS FROM 2499'-2873'. PUMPED 50 SPM AND 50 RPM TO REAM OUT TIGHT SPOTS. 12:00 - 12:30 0.50 DRILL N DPRB SURF CIRCULATE AND CONDITIONED HOLE. PUMPING 550 GPM AND ROTATING 120 RPM. 12:30 - 14:30 2.00 DRILL N DPRB SURF RAN IN HOLE WITH DRILLING ASSEMBLY FROM 2873'-4230'. STRING SAT DOWN. UNABLE TO WORK THROUGH WITHOUT PUMPS. 14:30 - 18:00 3.50 DRILL N DPRB SURF REAMING FROM 4230'-7017'. REAMING WITH 550 GPM AND 100 RPM. 18:00 - 20:30 2.50 DRILL N DPRB SURF CIRC. AND ROTATE TO CLEAN UP HOLE WITH 580 GLM PER MIN. AND 105 RPMS, LOTS OF BIG CHUNKS OF COAL COMING BACK 20:30 - 21 :00 0.50 DRILL N DPRB SURF WASH TO BOTTOM @ 7061 30 FT OF FILL 21 :00 - 00:00 3.00 DRILL P SURF DIRECTIONAL DRILLING FROM 7069 TO 7579 WITH 105 RPM 20K BIT WT. 2600 PSI 580 GALS MIN. RIT 2.5 HRS. 2/6/2002 00:00 - 08:30 8.50 DRILL P SURF DIRECTIONAL DRILLING FROM 7579' TO 8420' WITH 105 RPM 20K BIT WT. 2700 PSI 600 GALS MIN. 08:30 - 10:00 1.50 DRILL P SURF CIRCULATE HOLE CLEAN FOR SHORT TRIP. CIRCULATED 3 BOTTOMS UP. 100 RPM 600 GPM AT 2850 PSI. SHAKERS CLEAN. 10:00 - 11:30 1.50 DRILL P SURF OBSERVE WELL. BLOW DOWN TOP DRIVE. PULLED OUT OF HOLE WET FROM 8240'-7017'. MAXIMUM OVERPULL 25/35K. UP WT 21 OK. 11:30 - 12:00 0.50 DRILL P SURF RAN BACK IN HOLE TO BOTTOM AT 8420'. GOOD SHORT TRIP. 12:00 - 00:00 12.00 DRILL P SURF DIRECTIONAL DRILLING FROM 8420' TO 9265 WITH 105 RPM 20K BIT WT. 2700 PSI 600 GALS MIN. TOTAL 24 HR SLIDING TIME 8.25 TOTAL 24 HR ROT. TIME 4.75 2/7/2002 00:00 - 02:00 2.00 DRILL P SURF DIRECTIONAL DRILLING FROM 9265 TO 9453 WITH 105 RPM 20K BIT WT. 2900 PSI 600 GALS MIN. .75 HRS SLIDING 1 HR ROTATING. Printed: 2/20/2002 11 :22:45 AM (' ( BP EXPLORATION Operations 'Summary Report Page 4 of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-21 MPS-21 DRILL +COMPLETE NABORS NABORS 27ES Start: 1/30/2002 Rig Release: 2/11/2002 Rig Number: 27E Spud Date: 1/31/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 2/7/2002 02:00 - 05:30 3.50 DRILL P SURF CIRCULATE, ROTATE AND RECIPROCATE TO CLEAN HOLE FOR SHORT TRIP. STANDING BACK ONE STAND EVERY 30 MINUTES. 600 GPM AT 2900 PSI, 105 RPM @ 17K-19K TORQUE. 05:30 - 11 :00 5.50 DRILL P SURF PULLED OUT OF HOLE FROM 9453' TO HWDP AT 801'. MAXIMUM PULL 25K-30K. NO PROBLEMS. 11 :00 -15:30 4.50 DRILL P SURF RAN BACK IN HOLE TO 9453'. NO PROBLEMS. HOLE IN GOOD SHAPE. 15:30 - 19:00 3.50 DRILL P SURF CIRCULATE, ROTATE AND RECIPROCATE TO CLEAN HOLE FOR CASING JOB. STANDING BACK ONE STAND EVERY 30 MINUTES. 600 GPM AT 2900 PSI, 105 RPM @ 17K-19K TORQUE. 19:00 - 00:00 5.00 DRILL P SURF TRIPPING OUT FOR l' CSG, NO PROBLEMS 2/8/2002 00:00 - 02:00 2.00 DRILL P SURF LAID DOWN BHA, ADJUST MOTOR TO 0 DEGREES. CLEAN AND CLEAN FLOOR. 02:00 - 04:00 2.00 DRILL P SURF PICKED UP AND STAND BACK 36 JTS OF 3-1/2" DRILL PIPE. 04:00 - 06:30 2.50 CASE P SURF CLEAR RIG FLOOR. RIGGED UP 7" CASING TOOLS AND FRANK'S FILLUP TOOL. HELD PJSM FOR RUNNING CASING. 06:30 - 10:30 4.00 CASE P SURF RAN IN HOLE WITH 72 JTS OF 7" 26# L80 BTC MOD CASING WITH 29 STAIGHT BLADED TURBOLATORS. STRING SAT DOWN AT 2960'. 10:30 - 15:00 4.50 CASE N SURF ATTEMPTED TO WORK THROUGH BRIDGE AT 2960'. BROKE CIRCULATION AT 380 GPM AT 350 PSI. SLOWLY BEGAN TO MAKE PROGRESS. AFTER MAKING APPROXIMATELY 16" CASING FELL THROUGH. RAN IN HOLE ONE JOINT TO 3000' AND STRING SAT DOWN AGAIN. CONTINUED CIRCULATING AND DROVE CASING THROUGH BRIDGE. EVERY 40' STRING WOULD TAKE WEIGHT. APPEARS TURBOLATORS WERE HANGING UP AT 2811'. RAN IN HOLE WITH 100 JOINTS OF 7" CASING AND WORKED ALL TURBOLA TORS THROUGH TIGHT SPOT AT 2811'. 15:00 - 15:30 0.50 CASE P SURF BROKE CIRCULATION AND CIRCULATED 2 BOTTOMS UP AFTER WORKING THROUGH TIGHT SPOTS. PUMPING 380 GPM AT 400 PSI. RECOVERED SAND ACROSS SHAKER. 15:30 - 17:30 2.00 CASE P SURF CONTINUED RUNNING 7" CASING TO 5899'. LOST 15k OF DOWN WEIGHT IN LAST 800' OF CASING RUN. 17:30 - 18:00 0.50 CASE P SURF CIRCULATE TO FILL PIPE AND ATTEMPT TO RE-ESTABLISH DOWN WEIGHT 385 GPM AT 600 PSI. Printed: 2/20/2002 11 :22:45 AM (' ( BP EXPLORATION Operations Summary Report Page 5 of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-21 MPS-21 DRILL +COMPLETE NABORS NABORS 27ES Start: 1/30/2002 Rig Release: 2/11/2002 Rig Number: 27E Spud Date: 1/31/2002 End: 2/8/2002 17:30 - 18:00 0.50 CASE P SURF 18:00 - 00:00 6.00 CASE P SURF CONTINUED RUNNING 7" CASING TO '. 7,800 WITH NO MORE THAN 60,000 WT. CIRC EVERY 10 TO 12 JTS. 2/9/2002 00:00 - 03:00 3.00 CASE P SURF CONTINUED RUNNING 7" 26# L80 BTC MOD CASING. STOPPED AND CIRCULATED AS NEEDED. RAN A TOTAL OF 230 JTS OF CASING AND 1 PUP JOINT. 03:00 - 03:30 0.50 CASE P SURF PICK UP AND MAKE UP LANDING JOINT AND CASING HANGER. LANDED CASING. 03:30 - 04:30 1.00 CASE P SURF LAID DOWN FRANKS FILL-UP TOOL. MADE UP HALLIBURTON CEMENTING HEAD. 04:30 - 08:30 4.00 CEMT P SURF CIRCULATE AND CONDITION HOLE FOR CEMENTING JOB. STAGE PUMPS UP TO 380 GPM. RIGGED UP HALLIBURTON. HOLD PJSM. PUMPED 25 BBL PILL WITH NUTPLUG. 08:30 - 15:00 6.50 CEMT P SURF PUMP 5 BBLS WATER-TEST LINES TO 3000 PSI-PUMP 15 BBLS WATER. MIXED AND PUMPED 50 BBLS OF 10.3 PPG ALPHA SPACER WITH 2 GALLONS OF RED DYE. DROP BOTTOM PLUG. MIXED AND PUMPED 1130 SXS (761 BBLS) OF PERMAFROST "L" CEMENT AT 10.6 PPG AT 3 BPM. MIXED AND PUMPED 328 SXS (67 BBLS) CLASS "G" CEMENT WITH 1 % CALCIUM CHLORIDE, .3% HALAD 344 AND .2% CFR-3 MIXED AT 15.8 PPG. HAD FULL RETURNS. SHUT DOWN AND FLUSHED LINES AND KICKED OUT TOP PLUG. NO INDICATION OF PLUG LEAVING HEAD. PULLED CEMENTING HEAD CAP AND VERIFIED PLUG LEFT HEAD. STARTED DISPLACING CEMENT WITH 250 BBLS OF 11.0 PPG BRINE AND 108.7 BBLS OF FRESH WATER. NO RETURNS DURING CEMENT DISPLACEMENT. BUMPED PLUG WITH 2200 PSI AT 1455 HRS. BLED OFF PRESSURE AND FLOATS HELD. NO CEMENT TO SURFACE. 15:00 - 15:30 0.50 CEMT P SURF TIED CASING INTO RECORDER AND MONITORED PRESSURE FOR 30 MINUTES. NO PRESSURE INCREASE. 15:30 - 18:00 2.50 CEMT P SURF RIGGED DOWN CEMENTING HEAD AND CHANGED OUT BAILS ON TOPDRIVE. PULLED MASTER BUSHINGS AND CUT LANDING JOINTS BELOW ROTARY TABLE. 18:00 - 19:30 1.50 CEMT P SURF MADE UP TAM SETTING TOOL ON 3-1/2" DRILLPIPE AND RAN IN HOLE TO TAM COLLAR AT 987'. 19:30 - 20:00 0.50 CEMT P SURF ATTEMPT TO TEST TAM TOOL WOULD NOT HOLD 20:00 - 21 :30 1.50 CEMT N DFAL SURF TRIP OUT TAM TOOL FULL OF SCALE, LAY DOWN AND REDRESS TOOL 21 :30 - 22:30 1.00 CEMT N DPRB SURF TRIP IN WITH 3.5 OPEN ENDED AND PUMPED TWO PIPE VOL. , PULLED OUT OF HOLE 22:30 - 23:30 1.00 CEMT N DPRB SURF PICK UP TAM TOOL AND TRIP IN TO 988 AND TEST TOOL WITH 1000 PSI 23:30 - 00:00 0.50 CEMT P SURF OPEN TAM COLLAR AND CIRC WITH 4.5 BBLS MIN. 350 Printed: 2/20/2002 11 :22:45 AM ( BPEXPlORATION Operations Summary Report Page 60f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-21 MPS-21 DRILL +COMPLETE NABORS NABORS 27ES Start: 1/30/2002 Rig Release: 2/11/2002 Rig Number: 27E Spud Date: 1/31/2002 End: Dafe Frorn - To Hours Activity Code NPT Phase Description of Operations 2/912002 23:30 - 00:00 0.50 CEMT P SURF WITH WATER, FULL RETURNS 2/10/2002 00:00 - 02:30 2.50 CEMT P SURF HELD PJSM WITH HALLIBURTON. PUMPED 5 BBLS WATER-TEST LINES TO 2000 PSI-PUMP 15 BBLS WATER. MIXED AND PUMPED 204 SXS (151 BBLS) OF CLASS "L" CEMENT MIXED IN 10.7 PPG SLURRY. FOLLOWED LEAD WITH 108 SXS ( 18 BBLS) OF CLASS "C" CEMENT MIXED IN AT 15.6 PPG SLURRY. DISPLACED CEMENT OUT OF PORT COLLAR WITH 7.5 BBLS OF WATER. LEFT 1/2 BBL OF CEMENT IN CASING. 02:30 - 03:30 1.00 CEMT P SURF RELEASED TOOL FROM TAM PORT COLLAR AT 987' RUPTURED DISC WITH 1800 PSI AND CIRCULATED HOLE CLEAN. 03:30 - 04:00 0.50 CEMT P SURF PULLED OUT OF HOLE WITH TAM TOOL. 04:00 - 05:30 1.50 REMCM-P SURF BEGAN RIGGING UP FOR 1" TOP JOB. UNABLE TO WORK l' TUBING DOWN FLUTES INSIDE THE DIVERTER. CALL CHUCK SHEVE, AOGCC INSPECTOR. HE APPROVED TOPPING OUT WITH 1" DOWN THE ANNULUS. 05:30 - 06:30 1.00 CASE P SURF BACKED OUT LANDING JOINT AND LAID DOWN SAME. 06:30 - 08:30 2.00 CASE P SURF PICKED UP MULESHOE ON 3-1/2" DRILL PIPE. RAN IN 10 STANDS OUT OF THE DERRICK. PICKED UP ENOUGH 3-1/2" DRILL PIPE FROM PIPE SHED FOR FREEZE PROTECTION TO 3063'. 08:30 - 10:30 2.00 CASE P SURF RIGGED UP HB&R. HELD PJSM WITH RIG CREW, HB&R AND PEAK TRUCK DRIVERS. PUMPED 97 BBLS OF DIESEL DOWN THE 3-1/2" DRILL PIPE AT 4 BPM. DIESEL AT SURFACE. MONITOR WELL FOR 30 MINUTES. WELL DEAD. 10:30 - 14:00 3.50 CASE P SURF PULLED OUT OF THE HOLE LAYING DOWN 3-1/2" DRILL PIPE. FILLED HOLE WITH 13 BBLS OF DIESEL AFTER PULLING OUT OF HOLE. 14:00 - 16:00 2.00 BOPSUR P SURF NIPPLE DOWN RISER AND SECURED ON RIG FLOOR. NIPPLE DOWN DIVERTER. 16:00 - 18:30 2.50 WHSUR P SURF CLEANED UP WELLHEAD. INSTALLED 11" 5M MONOBORE G-6 FMC TUBING HEAD. INSTALLED FALSE BOWL WITH STAND OF HWDP AND PUT 25K DOWN TO ENERGIZE PACKING. RUN IN LOCK DOWN SCREWS. NIPPLE UP 11" x 7-1/16" FMC HOLD DOWN FLANGE AND 7-1/16" 5M GATE VALVE WITH TREE CAP. 18:30 - 19:30 1.00 WHSUR P SURF TESTED SEAL ON TUBING HEAD TO 1000 PSI AND TESTED TUBING HEAD X HOLD DOWN FLANGE CONNECTION TO 5000 PSI. 19:30 - 20:30 1.00 CASE P SURF RIGGED UP HB&R. PJSM ON TESTING CASING. TESTED Printed: 2/20/2002 11 :22:45 AM ( ( BP EXPLORATION Operations""SummaryReport Page 70t7 Legal Well Name: MPS-21 Common Well Name: MPS-21 Spud Date: 1/31/2002 Event Name: DRILL +COMPLETE Start: 1/30/2002 End: Contractor Name: NABORS Rig Release: 2/11/2002 Rig Name: NABORS 27ES Rig Number: 27E From - To Hours Activity Code NPT Phase Description of Operations 2/10/2002 19:30 - 20:30 1.00 CASE P SURF WELLHEAD AND CASING TO 4500 PSI FOR 30 MINUTES. RECORDED TEST ON CHART. BLED OFF PRESSURE. 20:30 - 21 :30 1.00 CASE P SURF INSTALLED BPV IN FALSE BOWL. PRESSURE TESTED TO 1000 PSI FROM BELOW FOR 10-MIN; RECORDED TEST ON CHART. BLED OFF PRESSURE. RIGGED DOWN HB&R. PULL VALVES OFF WELLHEAD AND INSTALLED BULL PLUGS. 21 :30 - 22:30 1.00 CASE P SURF RAN 7 JOINTS OF 1.0-IN TUBING DOWN ANNULUS TO TAG AT 124-FT. LAID DOWN 1 JT TO RUN CEMENT AT 120-FT. 22:30 - 23:30 1.00 CASE P SURF RIGGED UP HALLIBURTON. PJSM. PUMPED 71-BBL WATER AT 2.0-BBUMIN, 225-PSI. DISPLACED ANNULUS WITH WATER. 23:30 - 00:00 0.50 CASE P SURF PUMPED 70-BBL 10.7 -LB/GAL PERMAFROST "L" CEMENT AT 2.0-BBUMIN. GOOD CEMENT TO SURFACE. 2/11/2002 00:00 - 01 :30 1.50 CASE P SURF PICK UP AND CLEAN UP CELLAR AFTER TOP JOB. 01 :30 - 02:30 1.00 CASE P SURF LAID OUT CASING TOOLS AND CEMENTING EQUIPMENT FROM RIG FLOOR. 02:30 - 11 :00 8.50 DRILL P SURF LAY DOWN 5" DRILL PIPE FROM DERRICK. 11:00 -12:00 1.00 DRILL P SURF CLEAN FLOOR AND UNLOAD 5" DRILL PIPE FROM PIPE SHED. RELEASED RIG AT 1200 HRS 2-11-02 Printed: 2/20/2002 11 :22:45 AM ( (' Page 1, of1 BP,EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/16/2002 8/17/2002 8/18/2002 8/19/2002 MPS-21 MPS-21 COMPLETION NABORS DRILLING CO. NABORS 4 From -To Hours, Task Code NPT Phase 12:00 - 18:00 6.00 RIGU P PRE 18:00 - 19:30 1.50 WHSUR P COMP 19:30 - 00:00 4.50 BOPSUR P COMP 00:00 - 06:00 6.00 BOPSURP COMP 06:00 - 10:30 4.50 BOPSUR P COMP 10:30 - 19:00 8.50 CLEAN P COMP 19:00 - 20:30 1.50 CLEAN P COMP 20:30 - 23:30 3.00 CLEAN P COMP 23:30 - 00:00 0.50 PERF P COMP 00:00 - 03:00 3.00 PERF P COMP 03:00 - 08:00 5.00 PERF P COMP 08:00 - 08:30 0.50 PERF P COMP 08:30 - 09:00 0.50 PERF P COMP 09:00 - 15:00 6.00 PERF P COMP 15:00 - 00:00 9.00 RUNCOrvP COMP 00:00 - 01 :30 1.50 RUNCOrvP COMP 01 :30 - 03:00 1.50 BOPSUR P COMP 03:00 - 05:00 2.00 WHSUR P COMP 05:00 - 06:00 1.00 WHSUR P COMP 06:00 - 08:00 2.00 CHEM P COMP 08:00 - 10:30 2.50 RUNCOrvP COMP 10:30 -12:00 1.50 RUNCOrvP COMP Start: 8/16/2002 Rig Release: 8/19/2002 Rig Number: 4ES Spud Date: End: 8/19/2002 Description of Qperations INSTALL BOP;S & MOVE RIG OVER WELL & RIG UP. CHECK FOR PRESSURE & NIPPLE ON TREE INSTALL TEST PLUG. NIPPLE UP BOP (REASSAMBLE BOP STACK AFTER DOING ANNUAL CHECK. NIPPLE UP BOP TEST BOP TO 3500 PSI. & RETRIEVE TEST PLUG & SET WEAR RING (TEST WAIVED BY CHUCK SHEVE WITH AOGC) RIH WITH 3.5" DP & SCRAPER TO PBTD @ 9340' 4ES KB CIRC WELL BORE WITH 9.1 PPG. POOH WITH CLN-OUT ASSY. @ 1 MAKE UP 20' HES PERF. GUN RIH WITH PERF GUNS ON 3.5" DP TO 9264' 4ES KB RIG SWS & RIH WITH GR/CCL & LOG GUNS INTO POSITION. PULL GUNS UP HOLE 102' TO POSITION FOR CORRECT PERF. INTERVAL 9140-9160' "OA" SAND REVERSE CIRC 1.5 VOLUMES DP. LAY ON 3.5" DP & PERF GUNS (ALL SHOTS FIRED) MU PKR & RIH TO SETTING DEPTH @ 8903'& MU HANGER MU & LAND HANGER & RILDS & TEST SAME. SET TWC & TEST & NO BOP'S NIPPLE UP & TEST TREE TO 5000 PSI. RIG LUB & PULL TWC REVERSE CIRC. 178 BBL. TREATED 9.1 PPG. BRINE FOLLOWED WITH 80- BBL. DIESEL DROP SETTING BALL & HOOK ANNULUS TO TBG & U-TUBE DIESEL. WHEN BALL ON SEAT SET PKR TO 4000 PSI. FOR 30- MIN. OK. BLEED TBG. TO 1500 & PRESSURE ANNULUS TO 3000 PSI. AND MONITOR 30- MINUTES GOOD TEST. RIG LUBRICATOR & SET BPV. & RIG DOWN TEST EQUIPMENT & SECURE CELLAR AREA. RIG RELEASED @ 1200 HRS. 8/19/2002 Printed: 8/26/2002 10:33:04 AM a Od~O()cr 27 -Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well MPS-21 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 9,453.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ECEIVED t.~ .~, p n ! r; L'102 . .. \:, ..... ',' '-- ,Alaska Oil & Gas Cons. CommissiQtì Anchorage ,~ BP EXPLORA TION ,'ALASKA) INC. Milrle Point Unit BPXA, MPS-Pad, Slot MPS-21 MPS-21 Job No. AKZZ2201ÌJ, Surveyed: 7 February, 2002 SU R VEY R EPO R T 23 February, 2002 --;"1 Your Ref: 500292306500 Surface Coordinates: 5999967.17 N, 565787.21 E (70024' 37.2707" N, 149027' 51.5237" W) Surface Coordinates relatIve to Project H Reference: 999967.17 N, 65787.21 E (Grid) Surface Coordinates relative to Structure: 2.92 S, 557.84 W (True) Kelly Bushing: 73.25ft above Mean Sea Level !!ipE!'-''-'\I~SU'' DFULL.INUt SEiRVIt:Ei5 A Halliburton Company DEF NITIVE - -~ Survey Ref; 5vy10070 ". . Sperry-Sun Drilling Services Survey Report for MPS-21 Your Ref: 500292306500 Job No. AKZZ22018, Surveyed: 7 February, 2002 .BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Commcnt (ft) (ft) (ft) (ft) (ft) (It) (ft) (o/100ft) 0.00 0.000 0.000 -73.25 0.00 O.OON 0.00 E 5999967.17 N 565787.21 E 0.00 AK-G BP IFR.AK 204.00 0.250 312.040 130.75 204.00 0.30N 0.33W 5999967.47 N 565786.88 E 0.123 0.44 289.35 1.640 316.040 216.09 289.34 1.30 N 1.32W 5999968.46 N 565785.88 E 1.629 1.79 .- 379.06 3.640 328.030 305.70 378.95 4.64N 3.72W 5999971.78 N 565783.45 E 2.301 5.5:i 467.25 4.700 327.080 393.65 466.90 10.05 N 7.16W 5999977.16 N 565779.96 E 1 .204 11 .22 559.72 6.700 331.940 485.66 558.91 17.99 N 11. 76 W 5999985.06 N 565775.29 E 2.223 19.16 651 .73 9.600 338.610 576.73 649.98 29.87 N 17.08 W 5999996.89 N 565769.86 E 3.310 29.70 742.25 12.640 337.430 665.54 738.79 46.05 N 23.64 W 6000013.01 N 565763.17 E 3.368 4:i.44 834.76 14.520 333.950 755.46 828. 71 65.82 N 32.62 W 6000032.70 N 565754.01 E 2.215 61.08 929.20 16.340 331.250 846.50 919.75 88.10 N 44.21 W 6000054.88 N 565742.23 E 2.071 82.23 1021.54 18.360 327.350 934.64 1007.89 111.74N 58.30 W 6000078.39 N 565727.93 E 2.523 106.23 1118.71 20.580 323.410 1026.25 1099.50 138.34 N 76.74 W 6000104.83 N 565709.25 E 2.653 135.48 1210.11 22.950 321. 980 1111.13 1184.38 165.28 N 97.30 W 6000131.59 N 565688.46 E 2.657 166.72 1304.77 27.200 319.870 1196.85 1270.10 196.38 N 122.62 W 6000162.46 N 565662.86 E 4.587 204. 17 1396.80 34.710 317.600 1275.72 1348.97 231.86 N 153.89 W 6000197.67 N 565631.28 E 8.257 248.97 1490.03 36.920 318.550 1351.31 1424.56 272.46 N 190.33 W 6000237.94 N 565594.49 E 2.444 300.79 1584.38 36.040 318.720 1427.17 1500.42 314.56 N 227.40 W 6000279.71 N 565557.05 E 0.939 353.91 1678.38 39. 180 319.500 1501.63 1574.88 357.93 N 264.94 W 6000322.75 N 565519.13 E 3.379 408.06 1773.41 38.680 318.560 1575.56 1648.81 403.01 N 304.09 W 6000367.49 N 565479.58 E 0.814 464.48 1867.72 39.030 318.760 1649.00 1722.25 447.44 N 343.17 W 6000411.57 N 565440.12 E 0.394 520.49 1960.61 44.790 319.980 1718.10 1791.35 494.53 N 383.52 W 6000458.30 N 565399.35 E 6.262 578.95 2055.56 44.420 319.570 1785.70 1858.95 545.44 N 426.58 W 6000508.83 N 565355.84 E 0.494 641 .65 2150.32 46.940 319.270 1851.90 1925.15 596.92 N 470.68 W 6000559.92 N 565311.29 E 2.669 705.54 2245.03 50.140 317.100 1914.60 1987.85 649.78 N 518.02 W 6000612.37 N 565263.49 E 3.790 772.92 2339.93 50.860 314.680 1974.97 2048.22 702.35 N 568.99 W 6000664.48 N 565212.06 E 2.109 843.31 2433.86 54.040 311.030 2032.22 2105.47 752.94 N 623.59 W 6000714.59 N 565157.01 E 4.577 915.86 2527.22 59.360 307.230 2083.48 2156.73 802.09 N 684.13 W 6000763.20 N 565096.04 E 6.635 992.84 2621.50 64.740 303.250 2127.66 2200.91 850.05 N 752.15 W 6000810.57 N 565027.60 E 6.815 1075.71 2715.27 69.750 300.090 2163.93 2237.18 895.40 N 825.73 W 6000855.26 N 564953.63 E 6.180 1162.10 2808.40 74.730 296.900 2192.33 2265.58 937.66 N 903.66 W 6000896.83 N 564875.33 E 6.263 1250.72 ~ ----_.,..~---.. _.--_.~- ^ -.---- - -_.--~~_....~_._-~---- --- ----"---.._-- 23 February, 2002 - 22:02 Page 2 of6 ÐrillQI/('sf 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS-21 Your Ref: 500292306500 Job No. AKZZ22018, Surveyed: 7 February, 2002 ,BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2902.16 75.830 297.150 2216.16 2289.41 978.86 N 984.44 W 6000937.32 N 564794.19 E 1.201 1341.29 2995.51 76.920 296.680 2238.15 2311.40 1019.93 N 1065.33 W 6000977.68 N 564712.94 E 1.266 1431.89 3090.39 77. 11 0 296.690 2259.47 2332.72 1061.45 N 1147.94 W 6001018.47 N 564629.97 E 0.201 1524.20 ~. 3183.96 76.120 296.670 2281.13 2354.38 1102.32 N 1229.27 W 6001058.62 N 564548.28 E 1.058 1615.09 3278.69 74.960 296.050 2304.78 2378.03 1143.05 N 1311.46 W 6001 098~62 N 564465.73 E 1.379 1706.64 3372.88 74.330 296.640 2329.72 2402.97 1183.36 N 1392.85 W 6001138.21 N 564383.99 E 0.901 1797.29 3465.77 73.940 295.930 2355.12 2428.37 1222.92 N 1472.97 W 6001177.07 N 564303.53 E 0.847 1886.47 3558.42 73.600 296.720 2381.01 2454.26 1262.37 N 1552.70 W 6001215.82 N 564223.45 E 0.897 1975.25 3654.63 73.860 295.510 2407.97 2481 .22 1303.02 N 1635.63 W 6001255.74 N 564140.17 E 1.237 2067.40 3748.01 74.010 295.490 2433.81 2507.06 1341 .65 N 1716.62 W 6001293.65 N 564058.84 E 0.162 2156.87 3842.73 73.690 295.790 2460.15 2533.40 1381.02 N 17-98.64 W 6001332.30 N 563976.48 E 0.455 2247.61 3938.32 73.230 295.780 2487.37 2560.62 1420.88 N 1881.15 W 6001371.43 N 563893.62 E 0.481 2339.01 4033.28 73.260 295.490 2514.74 2587.99 1460.22 N 1963.13 W 6001410.04 N 563811.30 E 0.294 2429.68 4127.99 73.500 295.380 2541.83 2615.08 1499.20 N 2045.09 W 6001448.30 N 563729.00 E 0.277 2520.16 4222.35 73.750 295.860 2568.43 2641 .68 1538.35 N 2126.72 W 6001486.72 N 563647.03 E 0.555 2610.44 4315.61 73.780 295.840 2594.51 2667.76 1577.39 N 2207.30 W 6001525.05 N 563566.10 E 0.038 2699.76 4409.48 71.990 294.320 2622.13 2695.38 1615.42 N 2288.54 W 6001562.37 N 563484.53 E 2.456 2789.15 4502.58 70.710 297.280 2651.91 2725.16 1653.80 N 2367.95 W 6001600.05 N 563404.78 E 3.311 2877.12 4597.87 70.890 296.890 2683.25 2756.50 1694.77 N 2448.07 W 6001640.31 N 563324.30 E 0.430 2967.01 4690.66 72.21 0 297.880 2712.61 2785.86 1735.26 N 2526.23 W 6001680.11 N 563245.80 E 1.746 3054.94 4784.21 73.570 297.580 2740.14 2813.39 1776.86 N 2605.37 W 6001721.01 N 563166.29 E 1 .486 3144.28 4880.55 72.450 295.770 2768.29 2841.54 1818.22 N 2687.69 W 6001761.65 N 563083.61 E 2.140 3236.27 4972.59 72.1 00 295.520 2796.31 2869.56 1856.17 N 2766.72 W 6001798.89 N 563004.25 E 0.460 3323.70 5066.78 72.240 295.440 2825.15 2898.40 1894.74 N 2847.67 W 6001836.75 N 562922.96 E 0.169 3413.10 5161.03 72.250 295.400 2853.89 2927.14 1933.27 N 2928.74 W 6001874.57 N 562841.56 E 0.042 3502.59 5255.49 72 .190 295.270 2882.74 2955.99 1971.76 N 3010.03 W 6001912.34 N 562759.92 E 0.146 3592.25 5349.70 72.040 296.150 2911.67 2984.92 2010.65 N 3090.82 W 6001950.52 N 562678.80 E 0.903 3681.67 5444.22 72.160 295.240 2940.72 3013.97 2049.65 N 3171.86W 6001988.80 N 562597.41 E 0.925 3771.37 5539.65 72.350 295.280 2969.81 3043.06 2088.44 N 3254.06 W 6002026.86 N 562514.88 E 0.203 3861. 96 5634.12 73.000 294.770 2997.94 3071 .19 2126.58 N 3335.78W 6002064.29 N 562432.83 E 0.860 3951.82 ----~-----'~--~--'--'--------.'- -~- -- , ~ -'-_._-~~--"'--'-------'-" ,-----~- -----------_._------ 23 February, 2002 - 22:02 Page 3 of6 Oril/Quest 2.00.09.008 Sperry-Sun Drilling Serviêes . Survey Report for MPS-21 Your Ref: 500292306500 Job No. AKZZ22018, Surveyed: 7 February, 2002 "BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5729.37 72.290 295.040 3026.35 3099.60 2164.87 N 3418.24 W 6002101.85 N 562350.03 E 0.793 4042.39 5822.70 72.490 295.220 3054.59 3127.84 2202.65 N 3498.78 W 6002138.91 N 562269.17 E 0.282 4131 .04 5917.23 72.560 294.540 3082.97 3156.22 2240.58 N 3580.57 W 6002176.13 N 562187.04 E 0.690 4220.86 6010.48 72.660 295.080 3110.84 3184.09 2277.92 N 3661.35 W 6002212.75 N 562105.94 E 0.563 4309.50 6103.94 74. 130 295.390 3137.55 3210.80 2316.10N 3742.36 W 6002250.22 N 562024.59 E 1.605 4398.7"7 6198.24 75.110 294.720 3162.56 3235.81 2354.61 N 3824.73 W 6002288.00 N 561941.89E 1.245 4489.36 6291.68 74.860 296.230 3186.77 3260.02 2393.42 N 3906.20 W 6002326.09 N 561860.08 E 1.584 4579.34 6385.57 74.500 296.270 3211.58 3284.83 2433.4 7 N 3987.42 W 6002365.43 N 561778.51 E 0.386 4669.71 6479.89 74.620 297.180 3236.69 3309.94 2474.36 N 4068.62 W 6002405.60 N 561696.96 E 0.939 4760.49 6572.86 74.590 297.750 3261.37 3334.62 2515.70 N 4148.15 W 6002446.23 N 561617.06 E 0.592 4850.04 6667.23 73.940 296.780 3286.96 3360.21 2557.31 N 4228.89 W 6002487.13 N 561535.96 E 1.205 4940.78 6762.04 76.000 297.010 3311.55 3384.80 2598.73 N 4310.55 W 6002527.83 N 561453.94 E 2.185 5032.22 ô855.36 76.830 296.740 3333.47 3406.72 2639.73 N 4391.46 W 6002568.12 N 561372.67 E 0.933 5122.80 6950.77 75.840 296.660 3356.01 3429.26 2681.39 N 4474.28 W 6002609.04 N 561289.48 E 1.041 5215.36 7045.89 75.430 297.170 3379.61 3452.86 2723.10 N 4556.45 W 6002650.03 N 561206.96 E 0.675 5307.38 7139.54 73.580 297.230 3404.62 3477.87 2764.35 N 4636.71 W 6002690.57 N 561126.33 E 1.976 5397.53 7234.63 72.61 0 297.800 3432.27 3505.52 2806.38 N . 4717.40 W 6002731.89 N 561045.28 E 1.170 5488.43 7322.73 72.980 298.210 3458.33 3531.58 2845.90 N 4791.70 W 6002770.75 N 560970.63 E 0.612 5572.54 7418.10 72.790 298.190 3486.40 3559.65 2888.97 N 4872.03 W 6002813.11 N 560889.92 E 0.200 5663.65 7512.83 72.1 50 298.970 3514.93 3588.18 2932.18 N 4951.35 W 6002855.62 N 560810.22 E 1.036 5753.95 ~..... 7605.76 73.370 299.120 3542.48 3615.73 2975.27 N 5028.94 W 6002898.03 N 560732.26 E 1.322 5842.70 7700.06 72.380 298.220 3570.24 3643.49 3018.50 N 5108.01 W 6002940.56 N 560652.81 E 1.391 5932.79 7791.98 74.110 297.800 3596.74 3669.99 3059.84 N 5185.72 W 6002981.21 N 560574.74 E 1.932 6020.76 7884.29 72.230 298.230 3623.47 3696.72 3101.33 N 5263.72 W 6003022.02 N 560496.38 E 2.085 6109.06 7979.51 73.860 298.640 3651.23 3724.48 3144.70 N 5343.80 W 6003064.68 N 560415.91 E 1.701 0200.11 8072.32 70.940 299.570 3679.29 3752.54 3187.72 N 5421.09 W 6003107.02 N 560338.25 E 3.288 G288.56 8166.34 70.620 302.000 3710.25 3783.50 3233.16 N 5497.36 W 6003151.78 N 560261.59 E 2.404 6377.32 8258.89 73.170 302.110 3739.01 3812.26 3279.84 N 5571.91 W 6003197.81 N 560186.63 E 2.758 6465.22 8353.20 72.810 302.670 3766.60 3839.85 3328.15 N 5648.06 W 6003245.44 N 560110.05 E 0.684 6555.31 8448.25 72.700 302.340 3794.78 3868.03 3376.93 N 5724.62 W 6003293.55 N 560033.07 E 0.351 6646.00 - ------------~---+ -- ,..-- - - -- .-_u_---- .- -- ---_._~-._._- _n --._._~. . .----- -- ---'-'---~--'+- ------~-'--_. - 23 February, 2002 - 22:02 Page 4 of 6 DriflQlIest 2.00.09.008 Sperry-Sun Drilling Services . Survey Report for MPS-21 Your Ref: 500292306500 Job No. AKZZ22018, Surveyed: 7 February, 2002 8P EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northfngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8536.89 69.510 301.550 3823.48 3896.73 3421.30 N 5795.77 W 6003337.29 N 559961.53 E 3.696 6729.80 8629.55 68.420 300.580 3856.74 3929.99 3465.93 N 5869.84 W 6003381.26 N 559887.06 E 1.529 6816.26 8723.55 66.050 298.540 3893.11 3966.36 3508.70 N 5945.22 W 6003423.36 N 559811.31 E 3.219 6902.92 ~::;,¡- 8817.58 61 .440 297.610 3934.70 4007.95 3548.39 N 6019.60 W 6003462.40 N 559736.59 E 4.982 6987.19 8909.25 57.270 296.180 3981.41 4054.66 3584.07 N 6089.91 W 6003497.46 N 559665.97 E 4.743 7065.93 9003.72 53.550 295.400 4035.03 4108.28 3617.91 N 6159.92 W 6003530.68 N 559595.66 E 3.996 7143.49 9096.87 49.660 294.460 4092.88 4166.13 3648.69 N 6226.10 W 6003560.88 N 559529.21 E 4.250 7216.20 9180.46 45.630 293.460 4149.18 4222.43 3673.79 N 6282.53 W 6003585.48 N 559472.57 E 4.901 7277.63 9282.33 41.850 291.690 4222.77 4296.02 3700.85 N 6347.53 W 6003611.97 N 559407.33 E 3.900 7347.48 9378.62 39.920 290.140 4295.57 4368.82 3723.37 N 6406.39 W 6003633.96 N 559348.27 E 2.264 7409.73 9388.83 39.870 289.240 4303.40 4376.65 3725.57 N 6412.56 W 6003636.11 N 559342.08 E 5.675 7416.17 9453.00 39.870 289.240 4352.65 4425.90 3739.13 N 6451.40 W 6003649.33 N 559303.13 E 0.000 7456.60 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.071 ° (29-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 299.890° (True). ,_c Based upon Minimum Curvature type calculations, at a Measured Depth of 9453.00ft., The Bottom Hole Displacement is 7456.65ft., in the Direction of 300.096° (True). --------_.~-----_._---.-_._._~-- ---._----- - - ----- _._--..u-- . -------.--.---.-..--- ---~~_.._-._._.._----- 23 February, 2002 - 22:02 Page 5 of 6 ÐrillQ(I(!s( 2.00.09.008 DrillQIICf;( 2.00.09.008 Page 60f6 23 February, 2002 - 22:02 ------- - ------. ----._~_._,._.~----._._-------- _ ___,_,__.__ ._n___ _ - .-".--..---.-------------.-- .- 4425.90 AK-6 BP _IFR-AK 9453.00 0.00 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (It) From Measured Vertical Depth Depth (It) (ft) Survey tool program for MPS·21 Projected Survey 6451.40 W 3739.13 N 4425.90 9453.00 .-.. Comment Station Coordinates TVD Northlngs Eastlngs (ft) (It) (It) Measured Depth (ft) Comments BPXA MPS-Pad BP EXPLORATION (ALASKA) INC. Milne Point Unit . Sperry-Sun Drilling Services Survey Report for MPS·21 Your Ref: 500292306500 Job No. AKZZ22018, Surveyed: 7 February, 2002 ~Dd'OO9 27 -Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-21 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 9,453.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) CEIVED P ,'I, r¡ n ! ~'0(\? \ Ij ~:-\\ -" U i,~. L.- 'Ii v..., AlaskaOil & Gas Cons. Commission Ancborage BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad, Slot MPS-21 MPS-21 MWD Job No. AKMW22018, Surveyed: 7 February, 2002 - SURVEY REPORT 25 February, 2002 Your Ref: 500292306500 Surface Coordinates: 5999967.17 N, 565187.21 E (700 24' 37.2707" N, 1490 27' 51.5237" W) Kelly Bushing: 73.25ft above Mean Sea Level spe"''''Y-SUI! D f:t IL LING S SFtV ICE S A Halliburton Company Survey Ref: svy10069 DrilfQuest 2.00.08.005 Page 2 0'6 25 February, 2002 - 11:58 ~- --------~- ------_. Sperry-Sun Drilling Services . Survey Report for MPS-21 MWD Your Ref: 500292306500 Job No. AKMW22018, Surveyed: 7 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad 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 -73.25 0.00 0.00 N O.OOE 5999967.17 N 565787.21 E 0.00 MWD Magnetic ~'" 204.00 0.250 312.040 130.75 204.00 0.30 N 0.33W 5999967.4 7 N 565786.88 E 0.123 0.44 289.35 1.640 316.040 216.09 289.34 1.30 N 1.32W 5999968.46 N 565785.88 E 1.629 1.79 379.06 3.640 328.250 305.70 378.95 4.65N 3.71 W 5999971.79 N 565783.46 E 2.303 5.53 467.25 4.700 327.440 393.65 466.90 10.07 N 7.12W 5999977.18 N 565780.00 E 1.204 11.20 559.72 6.700 332.370 485.66 558.91 18.05 N 11.67 W 5999985.11 N 565775.39 E 2.225 19.11 651.73 9.600 338.790 576.73 649.98 29.96 N 16.93 W 5999996.98 N 565770.02 E 3.299 29.61 742.25 12.640 337.600 665.54 738.79 46.15 N 23.44 W 6000013.12 N 565763.37 E 3.368 43.32 834.76 14.520 334.530 755.46 828.71 65.98 N 32.28 W 6000032.87 N 565754.35 E 2.176 60.87 929.20 16.340 332.230 846.50 919.75 88.43 N 43.56 W 6000055.21 N 565742.87 E 2.033 81.84 1021.54 18.360 328.230 934.63 1007.88 112.29 N 57.28 W 6000078.95 N 565728.95 E 2.539 105.62 1118.71 20.580 323.990 1026.25 1099.50 139.12 N 75.38 W 6000105.62 N 565710.61 E 2.707 134.68 1210.11 22.950 322.350 1111.13 1184.38 166.23 N 95.71 W 6000132.55 N 565690.04 E 2.677 165.82 1304.77 27.200 319.140 1196.85 1270.10 197.22 N 121.15 W 6000163.31 N 565664.33 E 4.713 203.32 1396.80 34.710 317.180 1275.72 1348.97 232.40 N 152.77 W 6000198.21 N 565632.40 E 8.233 248.26 1490.03 36.920 317.890 1351.31 1424.56 272.64 N 189.59 W 6000238.13 N 565595.23 E 2.412 300.24 1584.38 36.040 318.830 1427.18 1500.43 314.56 N 226.86 W 6000279.72 N 565557.59 E 1.105 353.44 1678.38 39.180 319.690 1501.63 1574.88 358.03 N 264.28 W 6000322.86 N 565519.78 E 3.387 407.55 1773.41 38.680 318.900 1575.56 1648.81 403.30 N 303.23 W 6000367.78 N 565480.44 E 0.741 463.87 1867.72 39.030 319.020 1649.00 1722.25 447.92 N 342.07 W 6000412.06 N 565441.21 E 0.380 519.79 1960.61 44.790 320.430 1718.10 1791.35 495.27 N 382.13 W 6000459.05 N 565400.73 E 6.283 578.11 2055.56 44.4 20 319.920 1785.70 1858.95 546.48 N 424.83 W 6000509.88 N 565357.58 E 0.542 640.65 2150.32 46.940 319.820 1851.90 1925.15 598.31 N 468.53 W 6000561.33 N 565313.43 E 2.660 704.36 2245.03 50.140 318.250 1914.60 1987.85 651.88 N 515.07 W 6000614.48 N 565266.42 E 3.600 771.41 2339.93 50.860 315.630 1974.97 2048.22 705.36 N 565.06 W 6000667.53 N 565215.96 E 2.261 841 .4 1 2433.86 54.040 312.130 2032.22 2105.47 756.93 N 618.75 W 6000718.62 N 565161.81 E 4.492 913.65 2527.22 59.360 309.140 2083.47 2156.72 807.67 N 677.98 W 6000768.84 N 565102.15E 6.295 990.29 2621.50 64.740 305.490 2127.66 2200.91 858.07 N 744.21 W 6000818.65 N 565035.4 7 E 6.651 1072.83 2715.27 69.750 303.700 2163.92 2237.17 907.13 N 815.38 W 6000867.08 N 564963.87 E 5.625 1158.98 2808.,40 74.730 300.260 2192.32 2265.57 954.05 N 890.60 W 6000913.34 N 564888.25 E 6.400 1247.57 DríllQuest 2.00.08.005 Page 3 of6 25 February, 2002 - 11:58 --~-- ----------_._._---~- ----,--- Sperry-Sun Drilling Services . Survey Report for MPS-21 MWD Your Ref: 500292306500 Job No. AKMW22018, Surveyed: 7 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad 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) (o/100ft) 2902.16 75.830 298.670 2216.15 2289.40 998.65 N 969.55 W 6000957.24 N 564808.90 E 2.017 1338.24 2995.51 76.920 295.240 2238.14 2311.39 1039.76 N 1050.40 W 6000997.64 N 564727.69 E 3.757 1428.83 3090.39 77.110 298.630 2259.47 2332.72 1081.63 N 1132.81 W 6001038.78 N 564644.91 E 3.487 1521 .15 3183.96 76.120 296.350 2281.13 2354.38 1123.65 N 1213.55 W 6001080.09 N 564563.80 E 2.596 1612.09 3278.69 74.960 293.960 2304.79 2378.04 1162.64 N 1296.57 W 6001118.35 N 564480.45 E 2.733 1703.50 3372.88 74.330 290.340 2329.74 2402.99 1196.89 N 1380.68 W 6001151.85 N 564396.04 E 3.766 1793.48 3465.77 73.940 294.900 2355.14 2428.39 1231.24 N 1463.14 W 6001185.47 N 564313.29 E 4.741 1882.09 3558.42 73.600 294.600 2381.04 2454.29 1268.48 N 1543.92 W 6001222.00 N 564232.18 E 0.481 1970.68 3654.63 73.860 294.430 2407.99 2481.24 1306.80 N 1627.95 W 6001259.58 N 564147.81 E 0.319 2062.64 3748.01 74.010 295.170 2433.83 2507.08 1344.44 N 1709.41 W 6001296.50 N 564066.02 E 0.778 2152.01 3842.73 73.690 292.870 2460.18 2533.43 1381.47 N 1792.51 W 6001332.80 N 563982.61 E 2.357 2242.51 3938.32 73.230 297.500 2487.41 2560.66 1420.45 N 1875.40 W 6001371.05 N 563899.37 E 4.668 2333.81 4033.28 73.260 295.080 2514.79 2588.04 1460.72 N 1956.92 W 6001410.60 N 563817.50 E 2.440 2424.55 4127.99 73.500 295.810 2541.88 2615.13 1499.71 N 2038.87 W 6001448.87 N 563735.21 E 0.781 2515.03 4222.35 73.750 297.650 2568.48 2641.73 1540.43 N 2119.72W 6001488.87 N 563654.00 E 1.890 2605.42 4315.61 73.780 296.970 2594.56 2667.81 1581.51 N 2199.28 W 6001529.25 N 563574.08 E 0.701 2694.87 4409.48 71 .990 296.850 2622.18 2695.43 1622.12 N 2279.28 W 6001569.15 N 563493.73 E 1.911 2784.46 4502.58 70.710 297.890 2651.95 2725.20 1662.67 N 2357.61 W 6001609.01 N 563415.04 E 1.735 2872.58 4597.87 70.890 296.960 2683.29 2756.54 1704.11 N 2437.49 W 6001649.75 N 563334.81 E 0.941 2962.49 .~ 4690.66 72.210 297.760 2712.66 2785.91 1744.57 N 2515.66 W 6001689.51 N 563256.28 E 1.641 3050.42 4784.21 73.570 298.360 2740.18 2813.43 1786.63 N 2594.56 W 6001730.87 N 563177.02 E 1.578 3139.78 4880.55 72.450 295.200 2768.34 2841.59 1828.14 N 2676.79 W 6001771.66 N 563094.42 E 3.345 3231.76 4972.59 72.100 294.690 2796.36 2869.61 1865.11 N 2756.28 W 6001807.93 N 563014.60 E 0.651 3319.11 5066.78 72.240 297.020 2825.20 2898.45 1904.21 N 2836.97 W 6001846.32 N 562933.58 E 2.360 3408.54 5161.03 72.250 296.880 2853.94 2927.19 1944.89 N 2916.98 W 6001886.30 N 562853.21 E 0.142 3498.19 5255.49 72.190 296.880 2882.79 2956.04 1985.56 N 2997.21 W 6001926.25 N 562772.63 E 0.064 3588.01 5349.70 72.040 295.390 2911.72 2984.97 2025.05 N 3077~ 70W 6001965.04 N 562691.79 E 1.514 3677.47 5444.22 72.160 293.930 2940.78 3014.03 2062.58 N 3159.44 W 6002001.84 N 562609.73 E 1.475 3767.04 5539.65 72.350 297.200 2969.87 3043.12 2101.80 N 3241.42 W 6002040.33 N 562527.41 E 3.270 3857.66 5634.12 73.000 294.370 2998.01 3071.26 2141.02 N 3322.61 W 6002078.84 N 562445.87 E 2.941 3947.60 DrillQuest 2.00.08.005 Page 4 of6 25 February, 2002 ~ 11:58 -- ---- --~--'------------~-- Sperry-Sun Drilling Services . Survey Report for MPS-21 MWD Your Ref: 500292306500 Job No. AKMW22018, Surveyed: 7 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5729.37 72.290 295.580 3026.42 3099.67 2179.40 N 3405.02 W 6002116.49 N 562363.12 E 1.423 4038.17 _k 5822.70 72.490 295.360 3054.65 3127.90 2217.66 N 3485.33 W 6002154.04 N 562282.48 E 0.310 4126.87 5917.23 72.560 294.480 3083.04 3156.29 2255.65 N 3567.10 W 6002191.31 N 562200.38 E 0.891 4216.69 6010.48 72.660 294.680 3110.91 3184.16 2292.66 N 3648.03 W 6002227.61 N 562119.13 E 0.231 4305.30 6103.94 74.130 296.240 3137.62 3210.87 2331.17 N 3728.89 W 6002265.40 N 562037.94 E 2.243 4394.59 6198.24 75.110 295.420 3162.63 3235.88 2370.78 N 3810.72 W 6002304.29 N 561955.75 E 1.335 4485.28 6291.68 74.860 296.600 3186.84 3260.09 2410.36 N 3891.83 W 6002343.15 N 561874.30 E 1.249 4575.32 6385.57 74.500 296.320 3211.65 3284.90 2450.70 N 3972.90 W 6002382.78 N 561792.88 E 0.479 4665.71 6479.89 74.620 296.110 3236.76 3310.01 2490.86 N 4054.46 W 6002422.23 N 561710.96 E 0.249 4756.44 6572.86 74.590 297.480 3261.44 3334.69 2531.27 N 4134.47 W 6002461.92 N 561630.60 E 1.421 4845.94 6667.23 73.940 295.880 3287.03 3360.28 2572.06 N 4215.63 W 6002501.99 N 561549.09 E 1.771 4936.63 6762.04 76.000 296.710 3311.62 3384.87 2612.62 N 4297.71 W 6002541.83 N 561466.65 E 2.331 5028.01 6855.36 76.830 297.480 3333.54 3406.79 2653.93 N 4378.4 7 W 6002582.43 N 561385.54 E 1.198 5118.61 6950.77 75.840 297.070 3356.08 3429.33 2696.42 N 4460.87 W 6002624.19 N 561302.77 E 1.118 5211.22 7045.89 75.430 300.210 3379.68 3452.93 2740.58 N 4541.73 W 6002667.64 N 561221.52 E 3.227 5303.33 7139.54 73.580 298.680 3404.70 3477.95 2784.94 N 4620.31 W 6002711.31 N 561142.55 E 2.526 5393.57 7234.63 72.610 300.150 3432.35 3505.60 2829.62 N 4699.56 W 6002755.29 N 561062.91 E 1.797 5484.54 7322.73 72.980 300.670 3458.41 3531.66 2872.22 N 4772.14 W 6002797.25 N 560989.96 E 0.703 5568.70 .- 7418.10 72.790 300.310 3486.48 3559.73 2918.47 N 4850.68 W 6002842.80 N 560911.01 E 0.412 5659.84 7512.83 72.150 295.040 3515.03 3588.28 2960.41 N 4930.64 W 6002884.04 N 560830.69 E 5.347 5750.06 7605.76 73.370 296.450 3542.57 3615.82 2998.96 N 5010.58 W 6002921.88 N 560750.41 E 1.955 5838.58 7700.06 72.380 294.420 3570.34 3643.59 3037.67 N 5091.95 W 6002959.87 N 560668.70 E 2.310 5928.42 7791.98 74.110 287.900 3596.87 3670.12 3069.40 N 5173.99 W 6002990.88 N 560586.38 E 7.047 6015.36 7884.29 72.230 297.900 3623.65 3696.90 3103.69 N 5255.27 W 6003024.45 N 560504.80 E 1 0.566 6102.92 7979.51 73.860 297.230 3651.42 3724.67 3145.84 N 5336.01 W 6003065.89 N 560423.69 E 1.839 6193.92 8072.32 70.940 296.880 3679.48 3752.73 3186.07 N 5414.79 W 6003105.43 N 560344.57 E 3.167 6282.27 8166.34 70.620 300.760 3710.44 3783.69 3228.86 N 5492.56 W 6003147.52 N 560266.43 E 3.912 6371.01 8258.89 73.170 300.780 3739.20 3812.45 3273.86 N 5568.13 W 6003191.86 N 560190.46 E 2.755 6458.96 8353.20 72.810 303.640 3766.80 3840.05 3321.92 N 5644.43 W 6003239.24 N 560113.74 E 2.925 6549.06 8448.25 72.700 302.230 3794.98 3868.23 3371.27 N 5720.62 W 6003287.92 N 560037.12 E 1.421 6639.71 DrillQuest 2.00.08.005 Page 5 of6 25 February, 2002 ~ 11 :58 --~_.._----_._--- - -----~---- ----_.-----.~---- Based upon Minimum Curvature type calculations, at a Measured Depth of 9453.00ft., The Bottom Hole Displacement is 7450.36ft., in the Direction of 300.1130 (True). The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 299.890° (True). Magnetic Declination at Surface is 26.0710 (29-Jan-02) All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Sperry-Sun Drilling Services . Survey Report for MPS-21 MWD Your Ref: 500292306500 Job No. AKMW22018, Surveyed: 7 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8536.89 69.510 302.560 3823.68 3896.93 3416.20 N 5791.42 W . 6003332.22 N 559965.92 E 3.616 6723.48 8629.55 68.420 300.580 3856.94 3930.19 3461.48 N 5865.10 W 6003376.85 N 559891.85 E 2.315 6809.92 8723.55 66.050 298.610 3893.31 3966.56 3504.29 N 5940.45 W 6003419.00 N 559816.12 E 3.177 6896.59 8817.58 61.440 298.030 3934.90 4008.15 3544.29 N 6014.66 W 6003458.34 N 559741.56 E 4.934 6980.86 8909.25 57.270 298.590 3981.61 4054.86 3581.68 N 6084.08 W 6003495.12 N 559671.81 E 4.579 7059.68 9003.72 53.550 296.450 4035.24 4108.49 3617.63 N 6153.02 W 6003530.46 N 559602.56 E 4.357 7137.37 9096.87 49.660 294.310 4093.08 4166.33 3648.95 N 6218.95 W 6003561.20 N 559536.36 E 4.547 7210.13 9180.46 45.630 288.660 4149.41 4222.66 3671.64 N 6276.33 W 6003583.38 N 559478.78 E 6.939 7271.19 9282.33 41.850 293.360 4223.02 4296.27 3696.78 N 6342.07 W 6003607.94 N 559412.82 E 4.891 7340.71 9378.62 39.920 290.690 4295.82 4369.07 3720.44 N 6400.47 W 6003631.08 N 559354.22 E 2.704 7403.13 9388.84 39.870 291.540 4303.66 4376.91 3722.80 N 6406.59 W 6003633.39 N 559348.08 E 5.357 7409.61 9453.00 39.870 291.540 4352.90 4426.15 3737.90 N 6444.84 W 6003648.16 N 559309.69 E 0.000 7450.30 Projected Survey Sperry-Sun Drilling Services Survey Report for MPS-21 MWD Your Ref: 500292306500 Job No. AKMW22018, Surveyed: 7 February, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~ ~ ~ Comment ~> 9453.00 4426.15 3737.90 N 6444.84 W Projected Survey Survey tool program for MPS-21 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9453.00 4426.15 MWD Magnetic - -~-_.._-_._-~--- - --.-~--..-.,- .-.-.-- --'-'~ 25 February, 2002 - 11 :58 Page 60f6 DrillQuest 2.00.08.005 Note to File Well MPS-21 i PTO 202-009 Sundry 302-246 The Area of Review around well MPS-21i was checked by H. Okland and W. Aubert on 8/7/02. AOGCC's GeoFrame planimeter measurement function was calibrated in feet. No wells in the AOGCC GeoFrame database pass within one quarter mile of MPS-21 i's injection interval. W ~A- f/IL/ð L Winton Aubert Petroleum Engineer t \ , (. STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL VJ~/t {/1/0L ~ ~7/~ ~ ð /clY 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Suspend [] Plugging ..JJ Time Extension II Perforate 0 Repair Well [] Pull Tubing ð Variance II Other 0 Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Completion of Well 5. Type of well: 6. -Datum Elevation (DF or KB) 0 Development KBE = 73.251 0 Exploratory 7. Unit or Property Name 0 Stratigraphic Milne Point Unit II Service 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 4. Location of well at surface 3301' NSL, 224' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 1678' NSL, 11941 WEL, SEC. 02, T12N, R10E, UM At effective depth 1737' NSL, 13391 WEL, SEC. 02, T12N, R10E, UM At total depth 1757' NSL, 1395' WEL, SEC. 02, T12N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number MPS-21 i 9. Permit Number 202-009 10. API Number 50- 029-23065-00 11. Field and Pool Milne Point Unit / Schrader Bluff Effective depth: measured true vertical 9453 feet 4426 feet 9359 feet 4354 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 781 9411' 20" 711 260 sx Arctic Set (Approx.) 1236 sx 'l', 327 sx 'G', 88 sx 'C', 96 sx 'l' (top job) 111' 9444' 111' 4419' Perforation depth: measured None RE E I Ii [' true vertical None AUG 0 6 2002 Tubing (size, grade, and measured depth) None Alaska DB & Gas COBS. l;ommiS51O! Anchora08 Packers and SSSV (type and measured depth) None 13. Attachments II Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation August 24, 2002 16. If proposal was verbally approved Service Water Injection Name of approver Date Approved Contact Engineer Name/Number: Robert Odenthal, 564-4387 17. I hereby certify that the fo"'~ing iS~land ~~..éG6 the best of my knowledge Signed RObertOdenthal~.L../~ Uc..... ~-- Title Drilling Engineer Prepared By Name/Number: Sandra Stewman, 564-4750 Conditions of Approval: Notify c~mmi~sion so representative may)Vitness A roval No. 30 Z - ¿ il {p , Plug Integnty - BOP Test L Location clearance - pp T Mechanical Integrity Test í Subsequent fom"equired 19- i./o 7 T ~+- e,o ~E- ~ }SOO 1'''':1" M1, ~+ 1~i, lð, ~ttt./JN!d. ()N.Il.Il.,. ~~ ~~M.Ik£«Jj(z", ML ~S". till. b.J W~\Ii~.~~ Approved by order 01 the Commission Øng1nal !ìlgnedI~) n ! «;'1 N A Commissioner Date ~ I t>;;¡ Form 10-403 Rev. 06/15/88 Cammy 0echsIi I ð~!'é' ',"'. j I,.J I '- Submitln ip cate S-21 1. MIRU N-4ES. 2. ND tree and valve. NU SOPE. 3. Pressure test casing to 3500 psi 4. RIH and perforate using TCP guns on 3 V2" tubing. 4/2302) (Reference log SCMT Perforated interval will be 9140-9160' MD OA sand 9214-9234' MD OB sand Perforation guns will be 3 3/8" HSD, 4 SPF, random phasing, 34B HJ II, RDX (21.9" pen, .4" eh) 5. Run 7" packer on 3-1/2" tubing. 6. Set packer -8875' MD. (Waiver applied to set more than 200' above top perforations) 7. ND BOPE/NU 4 V2" 5M CIW Tree. 8. Freeze protect well. 9. Set SPY. 10. RDMO N-4ES. ( .Iœe.:. 7 1/16" 5M , WellheRd: 11" 5M FMC Gen 6 Unibore wI 7" FMC Tubing Hanger, 7" Mod BTC lift threads, 7" ISA-100 BPV profile 20" 91.1 ppf, H-40 1112' 1 ~ KOP @ 300' Max Hole Angle = 70-77 deg, fl 2800' to 8500' Hole angle through perfs. = xx deg. OLS = 8.26 deg/100' @ 1397' 7" 26#/ft., L-80, BTRC, Csg (drift 10 = 6.151", cap. = 0.0383 bpf) Stimulation Summary Perforation Summary Ref. I 09 ##1##/## xxx/xxx Size SPF Interval (TVD) "XXXXX Jet Charges @ 60 deg. phasing" MPU 5-21 i ( ~ ~it.,:;'::',:_-,<,f.~~'. ~ COMMENTS DATE REV. BY 02/11/02 Lee Hulme Initial completion Nabors 27-E Orig. RT Elev. = 73.25' (N-27E) Orig. GL Elev. = 39.00' (N-27E) ~ 0 1 987' I TAM Port Collar 7" short jt. from 9015' to 9034' 7" float collar I 9359' I 9443' 7" float shoe MILNE POINT UNIT WELL 8-21 i API NO. 50-029-23065 BP EXPLORATION (AK) OA Perfs 9140-9160 OS Perfs 9214-9234 - ( j 1"1 .~. t>; "~ 'J, <i :~ ! Î 1 [1 ';; ~~ ,1 Jf n T ~ 1 ~ if ~ iI: ~ ~;¡... .I:.ï \1.. ¡¡¡ ~r , ~, f.!j II l1 k ¡~ ¡~ :'¡ I: i:i ~: ¡.¡~ ~: fi~ r " ~ '-'~~ ~ ~ ~,~i.' ï: ¡;t. ~: ~ ,'jï !, f~ t '~ ..~.., ,'-' ,....::¡c ç c~ l '} , p¡U/ ~- 5-21 Injector comPI!tlon Diagram (PROPOSED 6-5-02) ~ Tubing hanger connection 4-1/2" NSCT pin x-over pup 4-1/2" NSCT box X 3-1/2" 1ST pin 3-1/2" 9.3# L80 1ST tubing 3-1/2" 'X' nipple (2.813') set at -2200' md 3-1/2" 9.3# L80 1ST tubing 3-1/2" 1ST box X 4-1/2" NSCT Pin x-over 7" x 4-1/2" packer - Saker S-3 (set at -8875' md) 4-1/2" NSCT box X 3-1/2" 1ST pin x-over 3-1/2"" 9.3# L80 pup jt (-10') 3-1/2" 'XN' nipple with 2.75" no-go 3-1/2" 9.3# L80 pup jt (-10') Re-entry guide 7", 26#, L-80, STC-M R3 l' ~.--: ~- U ':~ 4000 ":.. I, ...~jOGO ,,6000 7 I. 08. 1 .7000 ¡"¡.-Ol' ., ~ ,,;' . ,.j5.:~. ivi F' ::; ..... 2 _1 i H""Gi.ìil ð ~ H ...O"~, ,~ \1 tv1 F) ':;, 15 I If .,. ..\I,.,,,, -......~ ~...- ~~- ~~~ ...~ .¡r.'" .'1''''1\- ". bp To: Winton Aubert, AOGCC Date: August 2, 2002 From: Robert Odenthal Subject: Waiver of 20 AAC 25.412 (b) Under the captioned item it states, "The packer must be placed within 200' measured depth above the top perforations, unless the commission approves a different placement depth of as the commission considers appropriate given the thickness and depth of the confining zone I would like a waiver of the 200' policy for wells S-21 and S-31, which we will be completing later this month (- August 20, 2002). We will be running a single packer completion string to inject in the OA and OB sands. We will have ......20' of tailpipe below the packers. The OA sand in both instances is roughly -220-260' below the proposed setting depth. We would like to be able to set the packers here because the N sands are - 50' below the tailpipe. We would like to keep open the possibility of being able to come back later and perforate those N sands and be able to inject into that formation. The tables below show the depths for these wells. 8-31 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand ( to be perforated) OB sand (to be perforated) Depth (MD) 7620' 7640 ' 7690' 7846-7866' 7900-7920' 8-21 Item Packer setting depth Tail Pipe Depth N sand (not to be perforated at this time) OA sand (to be perforated) OB sand (to be perforated) Depth (MD) 8875' 8895' 8945 ' 9140-9160' 9214-9234 ' If you have any questions or need for any additional Information please call me at 564-4387 or 440-0185. Sincerely, /---- Î)'~~~~ Robert Odenthal ACT W orkover Engineer 564-4387 05/06/02 SeblUllbll'ler NO. 2054 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Blueline Sepia E-21 A '~1- J~ ~ 22185 MCNL 04/03/02 K-19A I <6-/10 22186 MCNL 04104/02 ,D.S.18-29B lq~"Olðq 22189 MCNL 04/10/02 MPS-21 .4 ~- OO~ 22195 SCMT 04/23/02 Color Prints CD 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnlcal Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 RECEIVED t.,~ l'.'( 1 / "002 11-1 . .,'( '- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Date Delivered: AIMkAOiI,\ GM('~nS. ComrIIiMinn Ancborage Receive~~G. ~~ ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle Well MPS-21 Ö)ca ..COc:y Job # 22158 SCMT Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED þpp 1 9 2002 Alaska Oil & Gas Cons. ComII1istion Anchorage Date Delivered: Date 03/09/02 4/15/2002 NO. 1989 Company Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point CD Color 2 Sepia BL Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Receivedb~~ He: t-'Ulllng v~.... on ~-paa ( ( Subject: Re: Pulling VSP on S-pad . Date: Tue, 19 Mar 2002 17:06:41 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Campbell, Steve K" <CampbeIS@BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Steve, Thanks for the additional information regarding the VSP surveys. I had some questions from the inspectors regarding the work. You had described the work in the original permit to drill applications for the S pad wells. This message gives further details regarding the operation. It is interesting that there are individual BOP stacks on the wells. Regardless, the wells are still unperforated and will remain so until4ES completes the wells. You have approval to proceed with the operations as you describe. I will copy this message and place it in the respective well files. You do not need to provide a 403 for the operations. Please call if you have any questions. Tom Maunder, PE AOGCC IICampbell, Steve KII wrote: \ .~Oð--C)O~ > Reference wells: MPS-15, 21, 31 & 9 > > Tom, > > In the original permits for the above mentioned wells, I did not include the > pulling of the VSP from the wells using the Klondike rig which will already > be over one of the wells waiting on the completion of the surveys. After > the surveys have been completed the plan is to have the Klondike rig pull > the VSP from each of the wells leaving the well as it was when the drilling > rig left it. Nabors 4es will be coming out to run the completions at a > later date. > > Procedure for pulling the VSP's: > > 1. > 2. > 3. > 4. > 4. > 5. > 6. > > Can you give me a verbal to do this work and we could send you a 10403 to > follow it up for each well? > > Thanks for your consideration! > > Steve Campbell > BP Drilling Engineer > 907-564-4401 (0) > 907-564-4441 (f) > campbels@bp.com Run survey's Move Klondike rig on to well PullVSP from the well Install BPV Close master valve and Nipple down thè BOP's Install tree cap and secure well Move Klondike rig off 10f2 3/20/02 12:31 PM ~e: pUlling V~P on ~-paa 20f2 ( 1 Tom Maunder <tom maunder@admin.state.ak.us> : ¡ ¡ Sr. Petroleum Engineer ¡ Alaska Oil and Gas Conservation Commission ì ( 3/20/02 12:31 PM MPS-21i permit ( Subject: MPS-21i permit Date: Mon, 28 Jan 2002 13:15:59 -0600 From: "Campbell, Steve K" <CampbeIS@BP.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Archey, Patti <ArcheyPJ@BP.com>, "Stewman, Sondra DtI <StewmaSD@BP.com> Tom, as of 10:00 hours on 01/28/02 the well first well on S-pad MPS-15i has been drilled to TD and casing run and cement without any problems. The rig is schedule to move over to the next well MPS-21 i at 23:00 hours today 1/28/02. If you could please expedite the approval of the MPS-21 i permit it would be greatly appreciated. Thanks for your help! Steve Campbell 907 -564-4401 (0) 907-564-4441 (f) campbels@bp.com Potk~ 5104- ~ro3 Ç208- o~z: 1 of 1 1/28/02 11:22 AM ~~~~'E (' : F fÆ~fÆ~~~l TONY KNOWLES, GOVERNOR A.ItA.SK& OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. , PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPS-21i BP Exploration (Alaska) Inc. Permit No: 202-009 Sur. Loc. 3301' NSL, 224' WEL, Sec. 12, TI2N, RI0E, UM Btmhole Loc. 1740' NSL, 1419' WEL, Sec. 02, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPS-2li. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, C~~l~~ Chair BY ORDER OF THE COMMISSION DATED this 28th day of January, 2002 jjcÆnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA( STATE OF ALASKA - AND GAS CONSERVATION COMf\(' 310N PERMIT TO DRILL \1 1 (z,c¡{v¡' 20 AAC 25.005 ðM \tJ6A &c lii9JV( I{ 'L 3/0 L J/z. q lò~ t/;)~' [0:) 1 a. Type of work. Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3301' NSL, 224' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 1658' NSL, 1263' WEL, SEC. 02, T12N, R10E, UM At total depth 1740' NSL, 1419' WEL, SEC. 02, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025906, 3539' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing Weight Grade Coupling Length 20" 92# H-40 Welded 80' 7" 26# L-80 BTC 9533' 1 b. Type of well 0 Exploratory O,stratigraphic Test 0 Development Oil . Service 0 Development Gas 17 Single Zon~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 68.00' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-21 i 9. Approximate spud date January 30, 2002 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9533' MD / 4446' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 750 Maximum surface~psig, At total depth (TVD) 4301' / 1934 psig Setting Depth 1S't>l.f /~l) TQD Botom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 9533' 4446' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 42" 9-7/8" Quantitv of Cement (include staoe data) 260 sx Arctic Set (Approx.) 1007 sx Class 'L', 313 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVE 1 6 2002 Perforation depth: measured Alaska Oil & Gas Coos. Commission Anchorage true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch. Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 21. I hereby certify that and correct to the best of my knowledge Signed Pat Archey Title Senior Drilling Engineer 20. Attachments Prepared By Name/Number: Sondra Stewman, 564-4750 Date t/;.5 /OC:Z Permit NU!!1ber A,.---Q API Number "i? .... /- ~ /...../-..... ApprPJ~~D~w f") See cover letter '7-D 2- - c.-L.J I 50- 02- q -- ~ ;>0'11 ~ - ~ \, 0'0 I (J 17"'- for other requirements Conditions of Approval: Samples Required 0 Yes ~o Mud Log ~equired 0 Yes ~o Hydrogen Sulfide Measures 0 Yes .1\10 Directional Survey Required "B'Yes 0 No Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K 0 3.5K psi for.CTU K\",,\q,~ '- Other: ¡Jcrl-t~ AOC1C-L. o~ C'ULð dAC¿~M~t tUV~ff-êV~V~ c\/\.- test. ~ Approved By Original Signed By Commissioner ~:e o~~~:i:sion Date \; ì~ >l /0 d- Form 10-401 Rev. 12-Q1-asèammy 0edJaj 0 RIG I N A L Submit I~ Triplicate (- Schrader Bluff "S" Pad f Qram M PS-21 i Well Plan IWell Name: I MPS-21 i Drill and Complete Plan Summary 1 Type of Well (service / producer / injector): 1 S-Shaped Injector Surface Location: Target Start Location: "OA" Target Start Location: "OB" Bottom Hole Location: 3301' FSL (1978' FNL), 224' PEL (5054' FWL), Sec 12, T12N ,R10E X=565,787.03 Y=5,999,967.31 1658' FSL (3621' FNL), 1263' PEL (4015' FWL), Sec. 02, T12N, R10E X=559,435.27 Y =6,003,552.47 1683' FSL (3596' FNL), 1311' PEL (3968' FWL), Sec. 02, T12N,R10E, X=559,387.50 Y =6,003,577.00 1740' FSL (3539' FNL), 1419' PEL (3859' FWL), Sec. 02, T12N,R10E X=559,278.60 Y =6,003,632.91 1 AFE Number: 1 TBD 1 Estimated Start Date: 1 01/30/02 I MD: 19533 1 I Ria: 1 Nabors 27E I Operatina days to complete: 18 I TVD: 14446 I I Max Inc: 175 1 KBE: 168 I Well Design (conventional, slim hole, etc.): I Conventional Grass Roots Injector I Objective: 1 Schrader "OA" & "OB" Mud Program: seeA~d 9-7/8" Production Hole Mud Properties: Density (ppg) Funnel visc VP HTHP ./ 8.6 - 9.20 75 - 150 25 - 60 N/A Spud - LSND Freshwater Mud pH API FiltrateLG Solids < 6.5 9.0-9.5 <8 Cement Program: Casing Size 17" 26 lb/ft L-80 BTC Surface casing Basis 250% excess over gauge hole in permafrost interval, 40% excess over gauge hole below permafrost Total Cement Volume: Wash 50 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg Spacer 75 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 10.50 ppg Lead 1007 sxs 10.7lb/gal Class L 4.15 cuft/sx (cement to surface) Tail 313 sxs 15.8 Prem "0" 1.15 cuft/sx of tail at 3594' Temp BHST ~ 80° F from SOR, BHCT 85° F estimated by Halliburton 2 Milne P(' t MPS-21 i Well Plan Evaluation Program: 9 7/8" Hole Section: Open Hole: MWD/GRlRES Cased Hole: USIT (post rig) Formation Markers: Formation Tops MD kb (ft) TVDrkb Pore Pressure Estimated EMW r (ft) (Psi) (ppg) Base Permafrost 1818 1750 SV1 Top Ugnu 7149 3456 1523 8.65 Top Ugnu M 8866 3974 1756 8.65 NA 9060 4094 1810 8.65 NB 9095 4118 1821 8.65 NC 9140 4149 1835 8.65 NE 9162 4165 1842 8.65 NF 9228 4214 1864 8.65 Top OA 9259 4237 1874 8.65 Base OA 9297 4266 1887 8.65 Top OB 9342 4301 1903 8.65 Base OB 9379 4329 1916 8.65 TD 9533 4446 1969 8.65 CasinglTubingProgram: See attached Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb M D / TVDrkb 42" 20" 92# H-40 Welded 80' 0' 113' / 113' 9 7/8" 7" 26# L-80 BTC 9533' 0' 9533' / 4446' Recommended Bit Program: BHA Hole Depth (M D) Bit Type Size 9 7/8" 0' - 6000' 97/8" 6000' - 9533' 1 2 MXC-1 MXC-1 Nozzle/Flow rate 3-13 & 1-10 3-13 & 1-10 3 Milne P( t MPS-21 i Well Plan Well Control: . Production hole will be drilled with a diverter. . No close approach issues Surface Interval . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: 1934 psi @ 4301' TVDrkb - Top of "OB" 1504 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) function test diverter N/A 8.6 ppg KCL / 6.8 ppg Diesel Drilling Hazards & Contingencies: Hydrates . Hydrates have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 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 . 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. We do not expect losses while drilling this well. . 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. . H-05 (1995): Lost returns drilling at 5360 (3700 tvd), 40 bph to keep full, treated w/ LCM pills for two days, total losses 838 bbls, made hole opener run with some continued losses. . H-05 (1995): Ran 9-5/8" casing, lost 46 bbls conditioning mud. . H-07 (1995): Lost 50 bbls running 9-5/8" casing. . E-24 (1998): Made hole opener run, worked tight spots 1965, 2620, 3465, 5900 and 6000, lost 72 bbls while circulating. . H-08A (1997): Had some minor losses while running 4-1/2" liner. . 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. 4 Milne P( ~ MPS-21i Well Plan Expected Pressures . It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to b,7 (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. This well WEfbe drilled in the undrained portion of the MPH-07 fault block. Offset injectors that have above normal shut-in pressures will be shut-in prior to drilling this well. Some of the wells on H-pad have experienced sever gas cut mud well below the permafrost. Have gas detector installed prior to drilling on S-pad. v Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Free ~ encountered below the Upper Ugnu. C../ Faults . 90 - 120' fault at oraround the Ugnu. The well plan was designed to stay away from the fault. Hydrogen Sulfide . MPS Pad is not designated as an H2S Pad. 5 Milne P( ~ MPS-21 i Well Plan DRILL & COMPLETION PROCEDURE Drillinq 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Prior to moving rig onto location, complete a pre-rig inspection with Pad operator. Ensure that the landing ring has been welded on the 20" conductor and check the height of the conductor for correct space out for the rig and diverter line. MI RU drilling rig. Conduct spud meeting and HSE compliance briefing with all personnel on board rig. ./ Nipple up 21-1/4", 2000 psi diverter system with 16" outlet on existing 20" landing ring. Ensure diverter setup conforms to diagram posted with AOGCC, and that any flowlines that may be in the path of the diverter are protect~. Function test diverter, and record it on the IADC and morning report. Notify the AOGCC prior to conducting the function test on the diverter and provide them with a written copy of the test after it is completed. PU enough 5" drill pipe to drill to 9.533' MD. PU 9-7/8" MXC-1, Sperry Motor, MWD/GR/Res. Drill 9-7/8" hole to KOP @ :t300. TVD/MD RKB. Start building angle at 2°/100' up to 3°/100' with an azimuth of 297° to end of build @ 2.946' MD. 2373' TVD as per mud and directional plan. . 400 - 500 gpm flow rate Continue drilling 9-7/8" hole, holding angle and direction to the start of drop @ 8382' MD. 3773' TVD/RKB. Drop 4°/100' to 9259' MD. 4237' TVD/RKB . Continue drilling to TO holding angle and direction at 9533' MD. 4446' TVD/RKB. Make a conditioning trip. Circulate and condition the mud as per mud program for cementing the 7" casing. Circulate until clean. Rig up 7" casing running equipment. Ensure the cross over with safety valve is on the rig floor and has been function tested. Run 7" 26#, L-80, BT&C surface casing to total depth. (See "detailed casing section" for centralizer placement) Circulate and condition the mud as per mud program for cementing the 7" casing. Circulate 1- 1/2" open hole volume. Mix and pump cement as per Halliburton Cement program and ADW recommended practices (RP) for surface Interval Cementing. Follow the recommended pump schedule to ensure not to exceeding anticipated formation fracture pressure. Continue reciprocating the pipe as long as practical. Bump the plug with 1,000 psi over circulating pressure. Checkj!oat equipment to make sure it's holding. Note that the cement will be displaced with KCL and Diesel for freeze protection. See casing and cement section for details. Nipple down diverter system, pick up and install FMC 20" x 11" 5M Gen 6 wellhead system. Have FMC service hand on location to supervise installation and testing of wellhead. Test wellhead system as per FMC. Nipple up 11" x 7-1/16" 5M FMC hold down flange, FMC 7-1/6" ~ gate valve and Tree cap (with gauge). Rig up HBR. Test wellhead and 7" casing to 4500 psi for 30 min on a chart. Install BPV & Secure well. 11. 12. 13. 14. 15. 6 16. POST RIG 1. 2. 3. 4. 5. 6. 7. 8. 9. NOTE: Milne P( 'MPS-21i Well Plan Rig down and release the rig. Complete a post rig inspection with the Pad operator prior to the rig moving off of the well. Fill out well handover form. Rig up coil and perform cle;91 out run Rig up wireline and run VSIT Move in Klondike #1 work platform NV 7-1/16" 5M BOP stack and test blind/shear rams 250 psi low; 4,000 psi high and test the annular to 250 psi low and 1,000 psi high. Pull BPV Rig up and run 1-1/2", 2.4ppf, N-80, 10 rd EVE, with Seismic cable and Geophones strapped to the outside of the tubing to TD. Land tubing in split bowl on top of the annular. Install valve in top of 1-1/2" tubing and test same with nitrogen to 90 psi RD Klondike and support equipment and move off / Com/J/etion for final injection will be done at a later date and /Jermittedas reQuired. ~h,c... \ c..o ""~$.-\-\ (:) '" \.-0 Þ e C-O\J<L,Q ~'ì '-\ $ ~"'W\ \t.a.~e ~ . 7 Milne r1 MPS-21 i Well Plan Detailed Casina Proaram 7" Surface Casina 7" Range 3 casing of the following design to be inspected as per BP specifications, and threads cleaned, inspected and doped prior to running. Size Section Length 7" 0 - 9533' 9533' Weiqht 26 ppf Grade Coupling L-80 BTC Drift 6.151 The Production casing will be run as follows: 1. Down jet float shoe, thread locked. 2. First two joints with 2 bowspring centralizers per joint with stop collar between. 3. Float collar on top of second joint, thread locked on bottom only. 4. Place one bowspring centralizer per joint for the next 22 joints without stop collars. 5. TAM port collar to be installed at 1,000' MD (Only used if no cement returns observed) have TAM opening tool in the pipe shed ready to run if required, & 1000' of 3-1/2" drill pipe ready to pickup. 6. Dope all connections with Best of Life 2000 7. Run casing to total depth. Cement as per cement program. Have on rig floor while running casing, 7" BTC x 2" swedge with 2" full open valve attached. 8. Nipple up FMC 11" 5m Gen 6 wellhead system Cement Information: Cement Company: Halliburton 20 bbls Fresh Water 50 bbls Alpha Spacer weighted at 10.2 ppg Lead Cement: *1007 sks Permafrost L, 10.7 ppg, 4.15 cuftlsk Tail Cement: 313 sks Premium + 20/0ßalcium Chloride, + .20/0 Halad 344), 15.8 ppg, 1.15 cuftlsk (estimated top of tail cement at 8560' MD/3594' TVD) Displace until the plug bumps with DIESEL (3000') & 3% KCL (for freeze protection) *Note: Have enough lead cement at the rig to pump until cement returns are observed at the surface prior to pumping tail. * 250% excess in permafrost section and 400/0 excess elsewhere 8 Field: Milne Point Well: 5-21i DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE MWD/GRlRES I FR/CAS 12/31/2001 FORM Base of Permafrost Top ofTail Cement Top of N sand OA sand OB sand Total Depth BP EXPLORATION Milne Point Unit MPS.21 i Actual Surface Location: 3300' FSL & 223' FEL Bottom Hole Location: 1740' FSL & 1419' FEL Status: not drilled DEPTH MD I TVD 110' 1,818' 1,750' 8,560' 3,594' 9,060' 4,094' 9,259' 4,237' 9,342' 4,301' 9,533' 4,446' 110' HOLE SIZE 9-7/8" MXC-1 ENG: Steve Campbell RIG: Nabors 27E RKB: 68' CASING SPECS MUD INFO PIT INFO 42 20" 92# H40 Welded Insulated Production Casing 7" 26# L-80 BT&C MW = 9.2 INFORMATION Wellhead FMC Gen 6 20" x 11" 5M KOP @ 300' EOB @ 2946' AA=75 VS=1318' SOD @ 8382' EOD @ 9259' AA=40 VS=7470' MPI-21 i well plan schematic.xls o 1000 2000 3000 4000 Vertical Section at 299.890 5000 1000ft/in] Tota Depth: 9533.28' MD, 6000 1000 I 8000 I 9000 5000 4000 Start Jir 4°/100' 8382.49' MD, ---- " 1000 Top Ugnu ~ '2 ~ o o Ë 2000 ~ Q ~ '€ > ~ 3000 1000 All TVD depths are ssTVD plus 72' for RKBE o A Start-Dir 1°/100': 300' MD, 300'TVD .--- Start Dir 2°/100' : 400' MD, 399.99'TVD =- StartDir 2.5°/100' : 502.52' MD, 502.45'TVD .------ StE.rt Dir 3°/100' : 981.58' MD, 980.1'TVD / End Dir : 1868.38' MD, 1150' TVD '1-.5°1 : 2135.1' MD, 1950'TVD ~ End Dil .2916.89' MD, 23-13.36' TVD ......... 3JOO ------ ~ 4000 - 5000 o t'; ------- 6000 I 2 3 4 5 6 1 8 9 10 II 3456.00 3914.00 4094.00 4118.00 4149.00 4165.00 4214.00 4231.00 4266.00 4301.00 4329.00 1149.36 8866.01 9060.39 9095.15 9140.10 9162.46 9228.91 9259.21 9291.13 9342.82 9319.31 Top Ugnu Top Ugnu M Schrader NA Schrader NB Schrader NC Schrader NE Schrader NF TSBD-OA TSBC (base OA) TSBB-OB SBA5 (base OB) No. FORMATION TOP DETAILS TVDPath MDPath Formation Sec I 2 3 4 5 6 7 8 9 10 II 12 MD 72.00 300.00 400.00 502.52 987.58 1868.38 2135.10 2946.89 8382.49 9259.21 9383.28 9533.28 Inc 0.00 0.00 1.00 3.00 15.00 41.42 41.42 75.01 15.01 40.00 40.00 40.00 0.00 0.00 345.00 330.00 315.00 315.00 315.00 291.70 291.70 297.68 297.68 297.68 Azi Name MPS-21 II JgnuM Schrader NA ,7" Schrader NB /' Schrader NC //<~____- ~ _ Schrader NE ~.::"'" Schrader NF /'- -+- TSBD-OA End D"'-~'MD,-4237'.T_V J /~~. ~.'~. :::---'---_.JSBC (base OA) ! 1" .1 ------!SBB-OB 444ó.9I,tVD SBA5 (base OB) I f i i 72.00 300.00 399.99 502.45 980.10 1150.00 1950.00 2373.36 3113.68 4237.00 4332.00 4446.91 lVD 4316.10 4237.00 TVD +Ni-S 4325.17 364132 0.00 0.00 0.84 4.03 59.62 351.44 416.22 861.56 3302.89 3641.32 3618.35 3723.14 SECTION DETAILS TARGET DETAILS +Fl-W Northing -Ð371.87 6004235.78 -Ð320.54 6003552.47 +N/-S No. +E/-W 0.00 0.00 -0.23 -1.80 -52.72 -344.54 -469.33 1025.44 5615.68 6320.54 6391.13 6476.51 TVD 4446.90 Easting 59377.92 59435.27 MD 9533.21 DLeg 0,00 0.00 1.00 2.00 2.50 3.00 0.00 4.50 0.00 4.00 0.00 0.00 S Point ('¡",Ie (Radius: 200) CASING DETAILS Name 1 TFace 0.00 0.00 45.00 31.15 41.40 0.00 0.00 28.86 0.00 19.98 0.00 0.00 VSec 0.00 0.00 0.62 3.51 15.42 413.86 644.23 1318.40 6566.68 1294.41 1314.06 1410.41 Size 1.000 MPS-2 Target Tla O_:·__:·~·':4.bP -« -y ~''';'{<'i~:.t COMPANY DETAILS BP Amoco Calculation Method Minimum Curvature ElTOr System: ISCWSA S<;an Method: Tl1Iv Cylinder North ElTOr Surface: Elliptical + Casing Wami~ Method: Rnles Based REFERENCE rNFORMATION Co-ordinat.e (NIE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Measured Depth Reference: Calcnlation Method: Well Ceutre: Plan MPS-2I. S-Pad Dev 72.00 Slot - (O.OON,O.OOE) S-Pad Dev 72.00 MÎI1imum Curvature True North Name Plan MPS-21 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 72.00 1000.00 Planned: MPS-21 Wp03 V I CB-GYRO-SS 1000.00 953328 Planned: MPS-2 I Wp03 V I MWDHFR+MS +Ni-S .73 +Fl-W 10 Nortlung 5999967.31 Plan: MPS-21 Wp03 (l'lan MPS-2 I !Plan MPS-21 re-dted By: Ken Allen Ie: ~UU Checked: Ie: Reviewed: ,te: WELL DETAILS Eastmg .03 .SHtude 4'37.272N ,ongituoo 149'27'51.529W Slot NiA 1000 6000 5000 -4000 3000 -2000 W est(- )Æast( +) [I OOOft/in] 1000 I 000 2000 o Start Dir 3°/1 00' : 981.58' MD, 980.1'TVD Star'! Dir 2.5°/100': 502.52' MD, 502.45'TVD 1000,~~art Dir 2°/100': 400' MD, 399,99'TVD 50(1 Start Dir 1°/100': 300' MD, 300'TVD Start Dir 4.5°/1 00' : 2135.1' MD, 1950'TVD d Dir : 1868.38' MD, 1750' TVD REFERENCE INFORMATION Co-ordiuate (N/E) Reference: Well Centre: Plan MPS-21, True North Vertical (TVD) Reference: S-Pad Dev 72.00 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: S-Pad Dev 72.00 Calculation Method: Minimum CUlVSture CASING DETAILS No. TVD MD Name 4446.90 9533.27 1" 1000 '2 ~ o o ~ ~ 2000 ::= ~ ::= g rI'J 4000- MPS-21 Wp03 Total Depth: 9533.28' MD, 4446.91' TVD j MD 4237' TVD r \~ ' 8382.49' MD, 3713.68'TVD 3000 All TVD depths are ssTVD plus 72' for RKBE FORMATION TOP DETAILS No. TVDPath MDPath Formation I 3456.00 7149.36 Top Ugnu 2 3974.00 8866.01 Top Ugnu M 3 4094.00 9060.39 Schrader NA 4 4118.00 9095.15 Schrader NB 5 4149.00 9140.10 Schrader NC 6 4165.00 9162.46 Schrader NE 1 4214.00 9228.91 Schrader NF 8 4231.00 9259.27 TSBD-OA 9 4266.00 9297.13 TSBC (base OA) 10 4301.00 9342.82 TSBB-OB II 4329.00 9379.37 SBA5 (base OB) Size 1.000 2946.89' MD, 2313.36' TVD Name +Ni-S +Fl-W Northmg Hasting ,8tlludc Longitude Slot Plan MPS-2 I -5.73 -558.10 5999967.31 5787.03 70"24'37.272N 149"27'5L529W NiA TARGET DETAILS Name TVD "Ni-S +EI-W Northing r"'sting Shape MPS-2I TIa 4237.00 3641.32 -6320.54 6003552.47 559435.27 Ci",Ie (Radius: 200) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 7:.00 0.00 0.00 72.00 0.00 0.00 0.00 0.00 0.00 2 \1111.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 IIII.OO 1.00 345.00 399.99 0.84 .0.23 1.00 345.00 0.62 4 ,,': .52 3.00 330.00 502.45 4.03 1.80 2.00 337.75 3.51 5 ',x7.58 15.00 315.00 980.70 59.62 ':.72 2.50 341.40 15.42 6 I xhx.38 41.42 315.00 1150.00 351.44 IU.54 3.00 0.00 473.86 ~ 7 ~'I \'.10 41.42 315.00 1950.00 416.22 "·'.33 0.00 0.00 644.23 8 ~'·'"'.89 15.07 297.10 2313.36 861.56 111:'.44 4.50 -28.86 131 8.40 9 x \'<:.49 75.07 291.70 3713.68 3302.89 'n 7-.68 0.00 0.00 6566.68 10 ":"'.21 40.00 297.68 4237.00 3641.32 r,I:II.54 4.00 -179.98 7294.41 MPS-21 rIa II I, IX \.28 40.00 291.68 4332.00 3618.35 h \"1.13 0.00 0.00 1314.06 12 '" \ 1.28 40.00 291.68 4446.91 3723.14 r.J 7".51 0.00 0.00 1470.41 ,I I ,I 11 I ~## '#', , , , c::. "/~ , ~ ~ ~ r1' .~ .J1 /~ /' bp 0·-······-·········'··'··'·'··'···.'.-., -' '~, COMPANY DETAILS BP Amoco Calculation Method: Error System: Scan Method: Error Surface: WarnÎnJ;t Method: Minimwn Curvature ISCWSA Tl1Iv Cylioder North Elliptical + Casiug Rules Based SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 72.00 1000.00 Planned: MPS-21 Wp03 VI CB-GYRO-SS 1000.00 9533.28 Planned: MPS-21 Wp03 VI MWD+IFR+MS Ian: MPS-21 Wp03 (Plan MPS-2111'lan MPS·21) Cre-dled By: Ken Allen Ie: ~O() I Chcçked: Ie: Reviewed: Ie: BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt S Pad Working Well: Plan, MPS-21 WeUpath: Plan MPS-21 Date: 11/2812001 Time: 09:33:41 Page: CO"'Ordinate(NE)Referenœ: Well: Plan MPS..21, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Seetion (VS)Rererenee: Well' (0.ooN,0.00E.299.89Azi) Plan: MPS-21Wp03 1 Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Site: M Pt S Pad Working Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-21 Slot Name: Suñace Position: +N/-S -5.73 ft Northing: 5999967.31 ft Latitude: 70 24 37.272 N +E/-W -558.10 ft Easting: 565787.03 ft Longitude: 149 27 51.529 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -5.73 ft Northing: 5999967.31 ft Latitude: 70 24 37.272 N +E/-W -558.10 ft Easting : 565787.03 ft Longitude: 149 27 51.529 W Measured Depth: 72.00 ft Inclination: 0.00 deg Vertical Depth: 72.00 ft Azimuth: 0.00 deg I Wellpath: Plan MPS-21 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Well Ref. Point 0.00 ft Mean Sea Level 26.28 deg 80.78 deg Direction deg 299.89 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57460 nT Depth From (TVD) ft 0.00 Height 72.00 ft Plan: MPS-21 Wp03 Date Composed: 11/26/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information MD Incl Azim, TV» +N/-S +E/~W DLS Build Turn TFO Target ft deg deg ft ft ft d~g.I1 000 d~g/100ft, deg/100ft deg 72.00 0.00 0.00 72.00 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 0.00 400.00 1.00 345.00 399.99 0.84 -0.23 1.00 1.00 0.00 345.00 502.52 3.00 330.00 502.45 4.03 -1.80 2.00 1.95 -14.63 337.75 987.58 15.00 315.00 980.70 59.62 -52.72 2.50 2.47 -3.09 341.40 1868.38 41.42 315.00 1750.00 351.44 -344.54 3.00 3.00 0.00 0.00 2135.10 41.42 315.00 1950.00 476.22 -469.33 0.00 0.00 0.00 0.00 2946.89 75.07 297.70 2373.36 861.56 -1025.44 4.50 4.14 -2.13 -28.86 8382.49 75.07 297.70 3773.68 3302.89 -5675.68 0.00 0.00 0.00 0.00 9259.27 40.00 297.68 4237.00 3641.32 -6320.54 4.00 -4.00 0.00 -179.98 MPS-21 T1a 9383.28 40.00 297.68 4332.00 3678.35 -6391.13 0.00 0.00 0.00 0.00 9533.28 40.00 297.68 4446.91 3723.14 -6476.51 0.00 0.00 0.00 0.00 Section 1: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turll TFO ft deg deg ft ft ft ft deg/1OOft deg/10Oftdeg/10Oft deg 72.00 0.00 0.00 72.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 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 0.00 Company: BP Amoco Field: Milne Point Site: M Pt S Pad Workíng WeD: Plan MPS-21 WèUpath: Plan MPS-21 Section 2: Start MD ft 400.00 Incl deg 1.00 Section 3: Start MD ft 502.52 Incl deg 3.00 Section 4: Start Azim deg 345.00 Azim deg 330.00 BP Amoco Planning Report - Geographic TVD ft 399.99 TVD ft 502.45 +N/~S ft 0.84 +N/-S ft 4.03 ~te: ',' 11/2812001 Time: 09:33:41 Page: Ccrordinate(NE)Reference: Well: Plan MPS-21, True North Vertical (TVD) Reference: 8-Pad Dev 72.0 Settion (VS) Reference: Well (0.OON,0.00E,299.89Azi) Plan: MP8-21 Wp03 +E/-W ft -0.23 +E/-W ft -1.80 VS ft 0.62 VS ft 3.57 2 DLS Build Turn TFO degl100ft . deg/1 00ft degl100ft deg 1.00 1.00 0.00 0.00 DLS Build Turn TFO ' deg/100ft deg/10Oft" deg/10Oft deg 2.00 1.95 -14.63 -22.25 600.00 5.37 700.00 7.84 800.00 10.32 900.00 12.82 987.58 15.00 Section 5: Start MD ft 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1868.38 lncl deg 15.37 18.37 21.37 24.37 27.37 30.37 33.37 36.37 39.37 41.42 Section 6: Start MD ft 1900.00 2000.00 2100.00 2135.10 loci deg 41.42 41.42 41.42 41.42 Section 7: Start MD ft 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 2946.89 Incl deg 44.00 48.03 52.12 56.25 60.43 64.62 68.84 73.08 75.07 Section 8: Start MD ft 3000.00 3100.00 3200.00 3300.00 Incl deg 75.07 75.07 75.07 75.07 321.66 318.39 316.68 315.63 315.00 Azim deg 315.00 315.00 315.00 315.00 315.00 315.00 315.00 315.00 315.00 315.00 Azim deg 315.00 315.00 315.00 315.00 Azim deg 312.97 310.19 307.74 305.56 303.57 301.74 300.04 298.43 297.70 Azim deg 297.70 297.70 297.70 297.70 599.66 698.99 797.73 895.69 980.70 TVD ft 992.69 1088.37 1182.40 1274.53 1364.50 1452.06 1536.97 1619.00 1697.93 1750.00 TV» ft 1773.71 1848.70 1923.69 1950.00 TVD ft 1997.69 2067.13 2131.30 2189.81 2242.29 2288.42 2327.92 2360.53 2373.36 TVD ft 2387.04 2412.81 2438.57 2464.33 9.82 18.58 30.20 44.65 59.62 +N/-S ft 61.92 82.44 106.48 133.96 164.81 198.95 236.28 276.71 320.11 351.44 +N/-S ft 366.23 413.01 459.79 476.22 -5.90 -13.33 -24.01 -37.92 -52.72 +EI-W ft -55.02 -75.54 -99.58 -127.06 -157.91 -192.05 -229.38 -269.81 -313.21 -344.54 +E/,.W ft -359.33 -406.11 -452.89 -469.33 +N/:'S +E/-W 'ft 'ft ' 506.77 -501.01 554.46 -554.85 602.63 -614.48 650.99 -679.55 699.23 -749.64 747.07 -824.33 794.21 -903.15 840.34 -985.63 861.56 -1025.44 +N/-S ft 885.41 930.33 975.24 1020.16 +E/-W ft -1070.88 -1156.43 -1241.98 -1327.53 10.01 20.82 35.87 55.13 75.42 VS ft 78.56 106.58 139.39 176.92 219.04 265.65 316.62 371.82 431.08 473.86 VS ft 494.05 557.92 621.79 644.23 VS ft 686.92 757.36 833.07 913.58 998.39 1086.99 1178.82 1273.31 1318.40 VS ft 1369.68 1466.24 1562.79 1659.34 2.50 2.50 2.50 2.50 2.50 2.43 2.47 2.49 2.49 2.49 -8.55 -3.27 -1.71 -1.05 -0.72 DLS Build Turn deg/100ft deg/100ft deg/100ft 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 2.99 2.99 0.00 DLS Build Turn deg/1 OOftdeg/1 OOft deg{1 OOft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 DLS Build Turn deg/1 OOfLdeg/1 OOft deg/10Oft 4.50 3.97 -3.13 4.50 4.03 -2.78 4.50 4.09 -2.45 4.50 4.14 -2.19 4.50 4.17 -1.99 4.50 4.20 -1.83 4.50 4.22 -1.70 4.50 4.24 -1.61 4.50 4.25 -1.56 DLS Build Turn deg/100ffdeg/10Oft dèg/10óft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -18.60 -10.28 -7.03 -5.34 -4.29 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 180.00 180.00 180.00 180.00 TFO deg -28.86 -27.37 -25.44 -23.86 -22.58 -21.54 -20.70 -20.02 -19.52 TFO deg 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 11/2812001 Time: 09:33:41 Page: 3 Field: Milne Point Co-Grdinate(NE) Referençe: Well: Plan MPS-21. True North Site: M Pt S Pad Working Vertical (TVD) Referen-çe: S-Pad Dev 72.0 WeD: Plan MPS-21 8œtion(VS) Reference: Well (O.00N;0.00E.299.89Azi) WeDpath: Plan MPS-21 Plan: MPS-21 Wp03 Section 8: Start MD Inel Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degJ100ft degl100ft degl100ft deg 3400.00 75.07 297.70 2490.10 1065.07 -1413.08 1755.90 0.00 0.00 0.00 0.00 3500.00 75.07 297.70 2515.86 1109.99 -1498.63 1852.45 0.00 0.00 0.00 0.00 3600.00 75.07 297.70 2541.63 1154.90 -1584.18 1949.00 0.00 0.00 0.00 0.00 3700.00 75.07 297.70 2567.39 1199.82 -1669.73 2045.56 0.00 0.00 0.00 0.00 3800.00 75.07 297.70 2593.15 1244.73 -1755.28 2142.11 0.00 0.00 0.00 0.00 3900.00 75.07 297.70 2618.92 1289.65 -1840.83 2238.66 0.00 0.00 0.00 0.00 4000.00 75.07 297.70 2644.68 1334.56 -1926.38 2335.22 0.00 0.00 0.00 0.00 4100.00 75.07 297.70 2670.45 1379.48 -2011.93 2431.77 0.00 0.00 0.00 0.00 4200.00 75.07 297.70 2696.21 1424.39 -2097.48 2528.32 0.00 0.00 0.00 0.00 4300.00 75.07 297.70 2721.97 1469.31 -2183.03 2624.88 0.00 0.00 0.00 0.00 4400.00 75.07 297.70 2747.74 1514.22 -2268.58 2721.43 0.00 0.00 0.00 0.00 4500.00 75.07 297.70 2773.50 1559.14 -2354.13 2817.98 0.00 0.00 0.00 0.00 4600.00 75.07 297.70 2799.27 1604.05 -2439.68 2914.54 0.00 0.00 0.00 0.00 4700.00 75.07 297.70 2825.03 1648.97 -2525.23 3011.09 0.00 0.00 0.00 0.00 4800.00 75.07 297.70 2850.79 1693.88 -2610.78 3107.64 0.00 0.00 0.00 0.00 4900.00 75.07 297.70 2876.56 1738.80 -2696.33 3204.20 0.00 0.00 0.00 0.00 5000.00 75.07 297.70 2902.32 1783.71 -2781.88 3300.75 0.00 0.00 0.00 0.00 5100.00 75.07 297.70 2928.08 1828.63 -2867.43 3397.30 0.00 0.00 0.00 0.00 5200.00 75.07 297.70 2953.85 1873.54 -2952.98 3493.86 0.00 0.00 0.00 0.00 5300.00 75.07 297.70 2979.61 1918.46 -3038.53 3590.41 0.00 0.00 0.00 0.00 5400.00 75.07 297.70 3005.38 1963.37 -3124.09 3686.96 0.00 0.00 0.00 0.00 5500.00 75.07 297.70 3031.14 2008.29 -3209.64 3783.52 0.00 0.00 0.00 0.00 5600.00 75.07 297.70 3056.90 2053.20 -3295.19 3880.07 0.00 0.00 0.00 0.00 5700.00 75.07 297.70 3082.67 2098.12 -3380.74 3976.62 0.00 0.00 0.00 0.00 5800.00 75.07 297.70 3108.43 2143.03 -3466.29 4073.18 0.00 0.00 0.00 0.00 5900.00 75.07 297.70 3134.20 2187.95 -3551.84 4169.73 0.00 0.00 0.00 0.00 6000.00 75.07 297.70 3159.96 2232.86 -3637.39 4266.28 0.00 0.00 0.00 0.00 6100.00 75.07 297.70 3185.72 2277.78 -3722.94 4362.83 0.00 0.00 0.00 0.00 6200.00 75.07 297.70 3211.49 2322.69 -3808.49 4459.39 0.00 0.00 0.00 0.00 6300.00 75.07 297.70 3237.25 2367.61 -3894.04 4555.94 0.00 0.00 0.00 0.00 6400.00 75.07 297.70 3263.01 2412.52 -3979.59 4652.49 0.00 0.00 0.00 0.00 6500.00 75.07 297.70 3288.78 2457.44 -4065.14 4749.05 0.00 0.00 0.00 0.00 6600.00 75.07 297.70 3314.54 2502.35 -4150.69 4845.60 0.00 0.00 0.00 0.00 6700.00 75.07 297.70 3340.31 2547.27 -4236.24 4942.15 0.00 0.00 0.00 0.00 6800.00 75.07 297.70 3366.07 2592.18 -4321.79 5038.71 0.00 0.00 0.00 0.00 6900.00 75.07 297.70 3391.83 2637.10 -4407.34 5135.26 0.00 0.00 0.00 0.00 7000.00 75.07 297.70 3417.60 2682.01 -4492.89 5231.81 0.00 0.00 0.00 0.00 7100.00 75.07 297.70 3443.36 2726.93 -4578.44 5328.37 0.00 0.00 0.00 0.00 7200.00 75.07 297.70 3469.13 2771.84 -4663.99 5424.92 0.00 0.00 0.00 0.00 7300.00 75.07 297.70 3494.89 2816.76 -4749.54 5521.47 0.00 0.00 0.00 0.00 7400.00 75.07 297.70 3520.65 2861.67 -4835.09 5618.03 0.00 0.00 0.00 0.00 7500.00 75.07 297.70 3546.42 2906.59 -4920.64 5714.58 0.00 0.00 0.00 0.00 7600.00 75.07 297.70 3572.18 2951.50 -5006.19 5811.13 0.00 0.00 0.00 0.00 7700.00 75.07 297.70 3597.95 2996.42 -5091.74 5907.69 0.00 0.00 0.00 0.00 7800.00 75.07 297.70 3623.71 3041.33 -5177.29 6004.24 0.00 0.00 0.00 0.00 7900.00 75.07 297.70 3649.47 3086.25 -5262.85 6100.79 0.00 0.00 0.00 0.00 8000.00 75.07 297.70 3675.24 3131.16 -5348.40 6197.35 0.00 0.00 0.00 0.00 8100.00 75.07 297.70 3701.00 3176.08 -5433.95 6293.90 0.00 0.00 0.00 0.00 8200.00 75.07 297.70 3726.76 3220.99 -5519.50 6390.45 0.00 0.00 0.00 0.00 8300.00 75.07 297.70 3752.53 3265.91 -5605.05 6487.01 0.00 0.00 0.00 0.00 8382.49 75.07 297.70 3773.68 3302.89 -5675.68 6566.68 0.00 0.00 0.00 0.00 Section 9: Start MD lilcl . Azbn TVD +Nl-S +EI-:W VS DLS BuRd' Turn TFO ft dëg deg ft ft ft ft . deg/1OQftdeg/100ft. deg/10Oft deg 8400.00 74.37 297.70 3778.29 3310.74 -5690.64 6583.55 4.00 -4.00 0.00 -179.98 8500.00 70.37 297.70 3808.58 3355.03 -5775.00 6678.77 4.00 -4.00 0.00 -179.98 8600.00 66.37 297.70 3845.43 3398.23 -5857.29 6771.64 4.00 -4.00 0.00 -179.98 8700.00 62.37 297.70 3888.68 3440.13 -5937.10 6861.71 4.00 -4.00 0.00 -179.98 8800.00 58.37 297.69 3938.11 3480.52 -6014.05 6948.56 4.00 -4.00 0.00 -179.98 8900.00 54.37 297.69 3993.48 3519.20 -6087.76 7031.74 4.00 -4.00 0.00 -179.98 9000.00 50.37 297.69 4054.52 3556.00 -6157.88 7110.86 4.00 -4.00 0.00 -179.98 9100.00 46.37 297.69 4120.94 3590.72 -6224.05 7185.54 4.00 -4.00 0.00 -:179.97 BP Amoco Planning Report - Geographic Company: BP Amoco Date: " 11/2812001 Time: 09:33:41 Page: 4 Field: Milne Point Co..ordinate(NE) Reference: Well: PlaoMP$-21, True NOrth . Site: M Pt S Pad Working Vertical (fVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-21 Settion(VS)Reference: Well (0.OON,O.00E,299.89Azi) WeUpath: Plan MPS-21 Plan: MPS~21 Wp03 Section 9: Start MD Incl Azim TVD +N/~S +EI~W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ftdeg/10Oft degJ1000 deg 9200.00 42.37 297.68 4192.41 3623.20 -6285.96 7255.40 4.00 -4.00 0.00 -179.97 9259.27 40.00 297.68 4237.00 3641.32 -6320.54 7294.41 4.00 -4.00 -0.01 -179.94 Section 10: Start MD Incl Azim TVD VS DLS BuDd Turn TFO ft deg deg ft ft (teg(100ftdegI100ft . degJ1 000 deg 9300.00 40.00 297.68 4268.20 3653.48 -6343.72 7320.57 0.00 0.00 0.00 180.00 9383.28 40.00 297.68 4332.00 3678.35 -6391.13 7374.06 0.00 0.00 0.00 180.00 Section 11 : Start MD Incl Azim TVD +N/-S +EI~W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ftdeg/10Oft deg/1 QOft deg 9400.00 40.00 297.68 4344.81 3683.34 -6400.65 7384.80 0.00 0.00 0.00 180.00 9500.00 40.00 297.68 4421.41 3713.20 -6457.57 7449.03 0.00 0.00 0.00 180.00 9533.28 40.00 297.68 4446.91 3723.14 -6476.51 7470.41 0.00 0.00 0.00 180.00 Survey Map . Map <-Latitude-:--> ~- Longkude ,~ MD Incl Azim TVD +N/-S +EI-W Northing Easting Deg Min See Deg Min See ft deg deg ft ft ft ft ft 72.00 0.00 0.00 72.00 0.00 0.00 5999967.31 565787.03 70 24 37.272 N 149 27 51.529 W 100.00 0.00 0.00 100.00 0.00 0.00 5999967.31 565787.03 70 24 37.272 N 149 27 51.529 W 200.00 0.00 0.00 200.00 0.00 0.00 5999967.31 565787.03 70 24 37.272 N 149 27 51.529 W 300.00 0.00 0.00 300.00 0.00 0.00 5999967.31 565787.03 70 24 37.272 N 149 27 51.529 W 400.00 1.00 345.00 399.99 0.84 -0.23 5999968.15 565786.79 70 24 37.280 N 149 27 51.536 W 502.52 3.00 330.00 502.45 4.03 -1.80 5999971.32 565785.19 70 24 37.312 N 149 27 51.582 W 600.00 5.37 321.66 599.66 9.82 -5.90 5999977.07 565781.04 70 24 37.369 N 149 27 51.702 W 700.00 7.84 318.39 698.99 18.58 -13.33 5999985.77 565773.53 70 24 37.455 N 149 27 51.920 W 800.00 10.32 316.68 797.73 30.20 -24.01 5999997.30 565762.76 70 24 37.569 N 149 27 52.233 W 900.00 12.82 315.63 895.69 44.65 -37.92 6000011.62 565748.72 70 24 37.711 N 149 27 52.640 W 987.58 15.00 315.00 980.70 59.62 -52.72 6000026.46 565733.79 70 24 37.858 N 149 27 53.074 W 1000.00 15.37 315.00 992.69 61.92 -55.02 6000028.74 565731.47 70 24 37.881 N 149 27 53.142 W 1100.00 18.37 315.00 1088.37 82.44 -75.54 6000049.08 565710.77 70 24 38.083 N 149 27 53.743 W 1200.00 21.37 315.00 1182.40 106.48 -99.58 6000072.89 565686.53 70 24 38.319 N 149 27 54.448 W 1300.00 24.37 315.00 1274.53 133.96 -127.06 6000100.13 565658.81 70 24 38.589 N 149 27 55.253 W 1400.00 27.37 315.00 1364.50 164.81 -157.91 6000130.71 565627.69 70 24 38.893 N 149 27 56.157 W 1500.00 30.37 315.00 1452.06 198.95 -192.05 6000164.54 565593.25 70 24 39.229 N 149 27 57.158 W 1600.00 33.37 315.00 1536.97 236.28 -229.38 6000201.54 565555.60 70 24 39.596 N 149 27 58.252 W 1700.00 36.37 315.00 1619.00 276.71 -269.81 6000241.60 565514.82 70 24 39.993 N 149 27 59.437 W 1800.00 39.37 315.00 1697.93 320.11 -313.21 6000284.62 565471.04 70 24 40.420 N 149 28 0.710 W 1868.38 41.42 315.00 1750.00 351.44 -344.54 6000315.67 565439.44 70 24 40.728 N 149 28 1.628 W 1900.00 41.42 315.00 1773.71 366.23 -359.33 6000330.33 565424.52 70 24 40.874 N 149 28 2.062 W 2000.00 41.42 315.00 1848.70 413.01 -406.11 6000376.69 565377.33 70 24 41.334 N 149 28 3.433 W 2100.00 41.42 315.00 1923.69 459.79 -452.89 6000423.05 565330.15 70 24 41.794 N 149 28 4.804 W 2135.10 41.42 315.00 1950.00 476.22 -469.33 6000439.33 565313.57 70 24 41.955 N 149 28 5.286 W 2200.00 44.00 312.97 1997.69 506.77 -501.01 6000469.60 565281.62 70 24 42.256 N 149 28 6.215 W 2300.00 48.03 310.19 2067.13 554.46 -554.85 6000516.81 565227.37 70 24 42.725 N 149 28 7.793 W 2400.00 52.12 307.74 2131.30 602.63 -614.48 6000564.45 565167.32 70 24 43.199 N 149 28 9.541 W 2500.00 56.25 305.56 2189.81 650.99 -679.55 6000612.22 565101.84 70 24 43.674 N 149 28 11.449 W 2600.00 60.43 303.57 2242.29 699.23 -749.64 6000659.85 565031.33 70 24 44.148 N 149 28 13.503 W 2700.00 64.62 301.74 2288.42 747.07 -824.33 6000707.02 564956.23 70 24 44.619 N 149 28 15.693 W 2800.00 68.84 300.04 2327.92 794.21 -903.15 6000753.45 564877.00 70 24 45.082 N 149 28 18.004 W 2900.00 73.08 298.43 2360.53 840.34 -985.63 6000798.86 564794.13 70 24 45.536 N 149 28 20.421 W 2946.89 75.07 297.70 2373.36 861.56 -1025.44 6000819.72 564754.14 70 24 45.745 N 149 28 21.589 W 3000.00 75.07 297.70 2387.04 885.41 -1070.88 6000843.17 564708.50 70 24 45.979 N 149 28 22.921 W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 11/28/2001 Time: 09:33:41 Page: 5 Field: Milne Point Co-ôrdlnäte(NE) Rd'erence: Well: Plan MPS-21. True North Site: M Pt S Pad Working Vertical (TVD)Reference: S-PadDev 72.0 WeD: Plan MPS-21 SectiOn (VS)Reference: WèU(0.OON,O.00E,299.89Azi) WeDpath: Plan MPS-21 Plan: MPS-21 Wp03 Survey Map Map <-Latitude ----> <- Longitude -> MD lAd AZÎIII TVD +N/-S +Ef..W Nortlling Eåsting Dêg M"m 'See Deg Min ' See ft deg deg ft ft ft ft ft 3100.00 75.07 297.70 2412.81 930.33 -1156.43 6000887.33 564622.56 70 24 46.421 N 149 28 25.429 W 3200.00 75.07 297.70 2438.57 975.24 -1241.98 6000931.48 564536.63 70 24 46.862 N 149 28 27.937 W 3300.00 75.07 297.70 2464.33 1020.16 -1327.53 6000975.64 564450.70 70 24 47.304 N 149 28 30.445 W 3400.00 75.07 297.70 2490.10 1065.07 -1413.08 6001019.80 564364.76 70 24 47.746 N 149 28 32.953 W 3500.00 75.07 297.70 2515.86 1109.99 -1498.63 6001063.95 564278.83 70 24 48.187 N 149 28 35.461 W 3600.00 75.07 297.70 2541.63 1154.90 -1584.18 6001108.11 564192.89 70 24 48.629 N 149 28 37.969 W 3700.00 75.07 297.70 2567.39 1199.82 -1669.73 6001152.26 564106.96 70 24 49.070 N 149 28 40.478 W 3800.00 75.07 297.70 2593.15 1244.73 -1755.28 6001196.42 564021.02 70 24 49.512 N 149 28 42.986 W 3900.00 75.07 297.70 2618.92 1289.65 -1840.83 6001240.57 563935.09 70 24 49.953 N 149 28 45.494 W 4000.00 75.07 297.70 2644.68 1334.56 -1926.38 6001284.73 563849.15 70 24 50.395 N 149 28 48.002 W 4100.00 75.07 297.70 2670.45 1379.48 '-2011.93 6001328.88 563763.22 70 24 50.836 N 149 28 50.511 W 4200.00 75.07 297.70 2696.21 1424.39 -2097.48 6001373.04 563677.28 70 24 51.278 N 149 28 53.019 W 4300.00 75.07 297.70 2721.97 1469.31 -2183.03 6001417.19 563591.35 70 24 51.719 N 149 28 55.527 W 4400.00 75.07 297.70 2747.74 1514.22 -2268.58 6001461.35 563505.42 70 24 52.161 N 149 28 58.036 W 4500.00 75.07 297.70 2773.50 1559.14 -2354.13 6001505.51 563419.48 70 24 52.602 N 149 29 0.544 W 4600.00 75.07 297.70 2799.27 1604.05 -2439.68 6001549.66 563333.55 70 24 53.044 N 149 29 3.053 W 4700.00 75.07 297.70 2825.03 1648.97 -2525.23 6001593.82 563247.61 70 24 53.485 N 149 29 5.561 W 4800.00 75.07 297.70 2850.79 1693.88 -2610.78 6001637.97 563161.68 70 24 53.927 N 149 29 8.070 W 4900.00 75.07 297.70 2876.56 1738.80 -2696.33 6001682.13 563075.74 70 24 54.368 N 149 29 10.578 W 5000.00 75.07 297.70 2902.32 1783.71 -2781.88 6001726.28 562989.81 70 24 54.809 N 149 29 13.087 W 5100.00 75.07 297.70 2928.08 1828.63 -2867.43 6001770.44 562903.87 70 24 55.251 N 149 29 15.596 W 5200.00 75.07 297.70 2953.85 1873.54 -2952.98 6001814.59 562817.94 70 24 55.692 N 149 29 18.104 W 5300.00 75.07 297.70 2979.61 1918.46 -3038.53 6001858.75 562732.01 70 24 56.134 N 149 29 20.613 W 5400.00 75.07 297.70 3005.38 1963.37 -3124.09 6001902.90 562646.07 70 24 56.575 N 149 29 23.122 W 5500.00 75.07 297.70 3031.14 2008.29 -3209.64 6001947.06 562560.14 70 24 57.016 N 149 29 25.631 W 5600.00 75.07 297.70 3056.90 2053.20 -3295.19 6001991.22 562474.20 70 24 57.458 N 149 29 28.139 W 5700.00 75.07 297.70 3082.67 2098.12 -3380.74 6002035.37 562388.27 70 24 57.899 N 149 29 30.648 W 5800.00 75.07 297.70 3108.43 2143.03 -3466.29 6002079.53 562302.33 70 24 58.340 N 149 29 33.157 W 5900.00 75.07 297.70 3134.20 2187.95 -3551.84 6002123.68 562216.40 70 24 58.782 N 149 29 35.666 W 6000.00 75.07 297.70 3159.96 2232.86 -3637.39 6002167.84 562130.46 70 24 59.223 N 149 29 38.175 W 6100.00 75.07 297.70 3185.72 2277.78 -3722.94 6002211.99 562044.53 70 24 59.664 N 149 29 40.684 W 6200.00 75.07 297.70 3211.49 2322.69 -3808.49 6002256.15 561958.59 70 25 0.106 N 149 29 43.193 W 6300.00 75.07 297.70 3237.25 2367.61 -3894.04 6002300.30 561872.66 70 25 0.547 N 149 29 45.702 W 6400.00 75.07 297.70 3263.01 2412.52 -3979.59 6002344.46 561786.73 70 25 0.988 N 149 29 48.211 W 6500.00 75.07 297.70 3288.78 2457.44 -4065.14 6002388.61 561700.79 70 25 1.430 N 149 29 50.720 W 6600.00 75.07 297.70 3314.54 2502.35 -4150.69 6002432.77 561614.86 70 25 1.871 N 149 29 53.229 W 6700.00 75.07 297.70 3340.31 2547.27 -4236.24 6002476.93 561528.92 70 25 2.312 N 149 29 55.738 W 6800.00 75.07 297.70 3366.07 2592.18 -4321.79 6002521.08 561442.99 70 25 2.753 N 149 29 58.247 W 6900.00 75.07 297.70 3391.83 2637.10 -4407.34 6002565.24 561357.05 70 25 3.195 N 149 30 0.756 W 7000.00 75.07 297.70 3417.60 2682.01 -4492.89 6002609.39 561271.12 70 25 3.636 N 149 30 3.266 W 7100.00 75.07 297.70 3443.36 2726.93 -4578.44 6002653.55 561185.18 70 25 4.077 N 149 30 5.775 W 7200.00 75.07 297.70 3469.13 2771.84 -4663.99 6002697.70 561099.25 70 25 4.518 N 149 30 8.284 W 7300.00 75.07 297.70 3494.89 2816.76 -4749.54 6002741.86 561013.31 70 25 4.959 N 149 30 10.793 W 7400.00 75.07 297.70 3520.65 2861.67 -4835.09 6002786.01 560927.38 70 25 5.401 N 149 30 13.303 W I 7500.00 75.07 297.70 3546.42 2906.59 -4920.64 6002830.17 560841.45 70 25 5.842 N 149 30 15.812 W 7600.00 75.07 297.70 3572.18 2951.50 -5006.19 6002874.32 560755.51 70 25 6.283 N 149 30 18.321 W 7700.00 75.07 297.70 3597.95 2996.42 -5091.74 6002918.48 560669.58 70 25 6.724 N 149 30 20.831 W 7800.00 75.07 297.70 3623.71 3041.33 -5177.29 6002962.64 560583.64 70 25 7.165 N 149 30 23.340 W 7900.00 75.07 297.70 3649.47 3086.25 -5262.85 6003006.79 560497.71 70 25 7.606 N 149 30 25.850 W 8000.00 75.07 297.70 3675.24 3131.16 -5348.40 6003050.95 560411.77 70 25 8.048 N 149 30 28.359 W 8100.00 75.07 297.70 3701.00 3176.08 -5433.95 6003095.10 560325.84 70 25 8.489 N 149 30 30.869 W 8200.00 75.07 297.70 3726.76 3220.99 -5519.50 6003139.26 560239.90 70 25 8.930 N 149 30 33.378 W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 1112812001 Time: 09:33:4.1 Page: (; Field: Milne Point Co-ordinate(NE) Ref~n(e,:""eJl: Plan MP8-21 , True North Site: M Pt S Pad Working Vertical (TVD) Reference: 8-Pad Dev 72.0 Well: Plan MPS-21 Section (VS) Referenc:e: Well (0.00N,0.OOE,299.89Azi) Wellpath: Plan MPS-21 Plan: MP8-21 Wp03 Survey Map M_p <-Latitude --> <-- .Longitude ,-> MD Incl Azim TVD +N/-S +EI-W Northing Easting Deg Min See Deg Min See ft deg deg ft ft ft ft ft 8300.00 75.07 297.70 3752.53 3265.91 -5605.05 6003183.41 560153.97 70 25 9.371 N 149 30 35.888 W 8382.49 75.07 297.70 3773.68 3302.89 -5675.68 6003219.77 560083.02 70 25 9.734 N 149 30 37.960 W 8400.00 74.37 297.70 3778.29 3310.74 -5690.64 6003227.49 560068.00 70 25 9.811 N 149 30 38.399 W 8500.00 70.37 297.70 3808.58 3355.03 -5775.00 6003271.03 559983.25 70 25 10.246 N 149 30 40.874 W 8600.00 66.37 297.70 3845.43 3398.23 -5857.29 6003313.50 559900.59 70 25 10.670 N 149 30 43.288 W 8700.00 62.37 297.70 3888.68 3440.13 -5937.10 6003354.68 559820.42 70 25 11.082 N 149 30 45.629 W 8800.00 58.37 297.69 3938.11 3480.52 -6014.05 6003394.39 559743.13 70 25 11.478 N 149 30 47.887 W 8900.00 54.37 297.69 3993.48 3519.20 -6087.76 6003432.42 559669.09 70 25 11.858 N 149 30 50.049 W 9000.00 50.37 297.69 4054.52 3556.00 -6157.88 6003468.59 559598.66 70 25 12.220 N 149 30 52.106 W 9100.00 46.37 297.69 4120.94 3590.72 -6224.05 6003502.73 559532.19 70 25 12.561 N 149 30 54.047 W 9200.00 42.37 297.68 4192.41 3623.20 -6285.96 6003534.66 559470.00 70 25 12.880 N 149 30 55.863 W 9259.27 40.00 297.68 4237.00 3641.32 -6320.54 6003552.47 559435.27 70 25 13.057 N 149 30 56.878 W 9300.00 40.00 297.68 4268.20 3653.48 -6343.72 6003564.43 559411.98 70 25 13.177 N 149 30 57.558 W 9383.28 40.00 297.68 4332.00 3678.35 -6391.13 6003588.88 559364.36 70 25 13.421 N 149 30 58.949 W 9400.00 40.00 297.68 4344.81 3683.34 -6400.65 6003593.79 559354.80 70 25 13.470 N 149 30 59.228 W 9500.00 40.00 297.68 4421.41 3713.20 -6457.57 6003623.14 559297.62 70 25 13.763 N 149 31 0.898 W 9533.28 40.00 297.68 4446.91 3723.14 -6476.51 6003632.91 559278.60 70 25 13.861 N 149 31 1.454 W 1/22/20025:13 PM 1 of 1 Steve Campbell 907-564-4401(0) 907-564-4441(f) campbels@bp.com Steve Campbell 907-564-4401(0) 907-564-4441(f) campbels@bp.com Thanks! I will send you a faxed copy of the mud program.. Max surface pressure = 1504 psi The well will be an Water Injector only Waste Disposal: NO annnular injection. Drill cuttings taken t oDS-4. Exempt liquid wastes can be taken to DS-4 or KRU 1R Subject: Date: Tue, 22 Jan 2002 18:54:23 -0600 From: "Campbell, Steve K" <CampbelS@BP.com> To: '''steve _ davies@admin.state.ak.us'" <steve _ davies@admin.state.ak.us> _,,~~/22/_~.~02 17 :_~:I FAX 907 564 4440 .. BP-ACT DEPT. ~OOl t [Click:. here and f)'pc addrc::~sJ To~ Steve Davies Fax: 276- 7542 From: Steve Campbell Date: 1/22/2002 Re: MPS-21í Pages: [Click b=œ and type number of pages] CO: [Click here and type name) 0 Urgent a For Revtew CJ Please Comment tJ Please Reply 0 Ple.e...oe;e R~le . . ,:,:!l~~,:~",'; :',.. ''<'iV:il¡;, #' :1~.!ii:M!~¡~':' ~~~!I~'lf,'~r." '1'.1'i"., ,,: I':~,', .;~¡~V~ 1I~li¡!{~, '1 ' , :¡\~.!lr:'!1 :¡~:(' ;~)' 11,::;,:¡~'~',il.l,:r",\, ~;'~If,f, 1" j "'Ii,:,,, :~ L1S¡~;¡:i'~I"'I'!¡. ,'¿I' :\Å;ff:oJ.\.~;~~:1 I . .¡";f ;/~~'JI¡";~ 1~~;\. " 'T'~"Y~~' , "I;l'I'III'I""~~ ,rt:'i~I"tid ,;' ' ¡"~~~i~I'~i:'I!; , i,¡ I, ....;'¡I,¡,~,)!!,. .',¡'/I'Mi!'. I,'" ' ',II,,,F' '~~V.';¡I,~I~I': P~~Y,";:'\"':~\!:A~!f: II' 'J' . r' ¡-II," I 'Ii I~. ',,(,::ry,~II,;-:~ \!;: "('I~'¡'~''~~!~"i) . "!':"\""'~1:1\1:\'~:1":\ .. tI~I/,I,I:';;ili " .,' ..' . ' ~ I-.i il¡1 :1'1't:~il"~'l'/' '.',i'Ú~,:i:ì;:,:'",:I;:,~I~:,~'b{ß " ,.~\,>";ilr..,.I::!,I.,l'i" . . . . . . . RECEIVED JAN 2 2 2002 ;~,~k« au & Gas Cons. CommissiOft Antborage , : ' ': : ':: : ;, :',:~ ¡, 'i : ;: , : : ,:: ':, :.'; L; ;: ", , " " I ,I ¡ ,I /I ), ~ I : ' ~: II " I ~, :,,11 ',': L,:~: II ,::,::,:::'1','::,::,',11:':\ r : r '¡ I' 1 II "'U" I I II" I . I ""I I~ I I I t r 1111 t lilt ::" ';,~:', :':; ::'1:'/';;" ',';: ,':: I,:, ':~,:,,~" ; " r I' ,', I :': .. I I, "II, I 1111 r ','UJlII! ", "::~:~~:II':fI :1: I,ll I :: r~I:: .:, :: I II IJ i, '~ "_I.."...."....".."... 1.\1\1 -:;- 01~2~/2002 17: 04 .I:AX 907 564 4440 BP-ACT DEPT. [4J 002 " ~ ISO 9001 & 14001 Certified ~-I LLt.,. A SmithlSeblumbClrger Company -721 w. Fint Ave. ADcltO~ge. AK 99501 Tel: (907) 274-556 Fu:: (907) 279-6729 œ "J .... bp _III 0 DRilLING FLUIDS 'PROGRAM Milne Point 5-21 i Schrader Bluff OA and OB Injector \ ""-'""/ ~ame Originator: Hal M.artens Reviewed by: Joh.n Murphy/Paul Hanson Customer Approval: ' Steve Campbell Version: 1 Signat~re A.f~fIf~ Dãte I-Z¿ -d~ Date: 1- 2Z -0 ¿, ''-.-t'' ..-' 01/22/2002 17: O( pAX 90~.. 564 44.40 BP-ACT DEPT. 141 003 '...J ',--,/ ,,../ ': r:7J Table of Contents Introduction Fluid and Drilling Concerns Generalized Geology Expected Formation Tops Overview and Drilling Concerns Generalized Geology Interval Drilling Concerns -_.. "~--'-_."'...-- -...-,' ---- Operations Recommendation Fluids and Product Usage Recommended Fluid Properties Product Usage Inlttal Make-Up and Sweep Formulas Solids Control Equipment Lost Circulation Recommendations Cost Estimates 01/22/2002 17:05 FAX 907 56!-!~40 - ----... ~ . ., . r BP-ACT DEPT. f4JOO4 ~ BP Milne Point 5-21 ¡Injector / '----- Introduction MPS-21 i is to be directionally drilled as a "Conventional Grassroots Injector" to support future production at the Milne Point S-pad location. The well will be drilled and a long string will be set within the Schrader Bluff formation at a depth of 9,533' MD (4A46' lVD). The injection zone targe1ed Schrader Bluff OA and 08 sands have expected formation pressures of 1,916-psi (8.65 EMW). Fluid and Drilling Concerns ), Well bore stability throughout the directional drilling and casing running phases of the operations. > Hole cleaning throughout the drilling operation. Running gravels have hindered operations on several of the previous S-pad wells. ',--,) > Possible gas breakout due to hydrates. This has been a common problem on this pad while drilling below the permafrost. » Lost circulation while drilling and particularly while running casing. » Minimization and control of waste management costs for any udrill cuttings! and associated fluids. Monitoring and efficient utilization of the trucks that are required for this operation. Daily and interval summaries will be tallied and summarized as part of M-I's well reporting procedure. ',.....,/ Expected Formation Tops. Estimated Top.(ss) 1,750' TVD - 1 ,8~ 8' MD, 3,456' TVD - 7,149' MD 3,974' TVD - 8,866' MD 4,094' TVq,.- 9,060' MD 4,1 1 S' 1VD - 9,095' MD 4,1~~' TVD-9,140' MD._ 4,165' TVD-9,126~ MD 4.214' TVD - 9,228' MD 4,2ð7' TVD - 9,259' MD'- 4,266' TVD - 9,297' MD 4,301' TVD - 9,342' MD 4,329' lVD - 9,533' MD 1\ _ LD_ -iLL _ 1....0_ .1J.' ---------- .øa~ - .. - - - - - - - ::JDar--- ------- "tI"t'~ 1'''1& I. . 'lJu11:.,I4 mud .. ~IO ~I ."..1. e..lt,"'vldul ....11 plan 'or IIp.t¡.lnc mud Uta-1ahl.. PRESSURE INFORMATION __ a.,.rvolr Pr..."... _ BUllt,."d ....d 'high, '\J> ¡ a,,,,, 11.1 't" I I 1 . a. MUI!i '"PO ,&'11)- - - - - - - - - TSB8-0B/SB~5 (base 08) ,-----.,./ _ TSBt?-ONTS6C (base OA) Forma~.ion Base of Permafrost Ugnu Ugnu M Schrader NA Schrader NB Schrader NC Schrader NE Schrade~ NF $ohradl!r BILlfP Sands: In'lIrbadded Marine undG, &ntStOflV$ willi somv çlIlJII;. H:rdrOCllrbon bInning :snd prodÙe!'V8 In tha~,..n :snd ·0· 5:sr.cla. TOp of Seabee O~B.nd. I-A.II,C. fI.E.F) 011; CAI I.e..Rd. (,-"D,IJ. 1:1,~.'" N~/NO, ,~' Nil: POI;.$lbI9 nJdrc:u::srbDII bearIng nnds (ail). TOP OF SCHRAD~R DLUPF AT '149' MD (3954' TVD) RIS: L" andi (.".11) I.!v.,lkf '.:: ~ ::: The ronowlng geðlogln, daplhs II '.." . ¡¡re baaed on 1U1 (; Pad W91t · ~ :.::::: n~~~~ops~~bl' travel l··::::J_~ ~onalOMerB\e to 1840'. ':.~>. aase pllrm3frc&' - . s::':c::: Pr9<1cunlaal"lUy conglotrlera,a . grvnl with 'ncrees'"'' I concentr:¡Hlan8 of IIBnlS Clnd çlay ;1$ 2300' Is a,prO:¡II:had. Heavy COflCClfltr:S1101'1 of CUllY :2715' tD 23115', OCCBSIOn;!1 shows of coal. ChQrt hard 5l~911k "t 2710'. slaw ROP. CDlltlnued In1erbeds of $and, CIBYS;Tld sllt$tOlltt Wit'" awc¡aalonal &ho."s of coal from Z~OO' to ~aoo'¡ HEAVY CLAY ass 3100' . $'00' TVI' UGNU: Serln ofco3tS8nlng \lpwi1rd 5i1l1d6 """'et! ölfll mada uJ! of: (from lop 10 boltom eònsCl s3nd, fine sanø, silty shale. Bettl'r <14¡vIIIDpad Intllrvoning shalee liS you p~ð!l(e¡;Slntolhll L3ndM II·,.nd. (..&,II,al K·..nd. (-A,a,a,DI ., lIallannltll.1I LITH FM o G EN ERA-LIZED G EOLOG lCAl FORECAST GEOLOGICAL D ¡¡¡SCRIPTION Generalized Geology ,-.,/ I4J 005 ~ BP-ACT DEPT. 01/22/2002 17:05 FAX 907 564 ~440 -.- .._~-_.. --- - 01/22/2002 17:05 FAX 907 564 4440 .-..-r-' - . BP-ACT DEPT. [4J 006 ( '0 ~ 9 7/8" Hole Overview Lithology through this zone is a composite of small gravel in the upper intervals with a grading downward to sand, clay, siltstone! and sand in the lower zones of the interval. Based upon work done on previous wells a modified spud - LSND mud is recommended for this interval. Initial viscosities of 90 - 150 seclqt should be used through the permafrost, which extends to a depth of 1,818! MD (1,750' TVD). The presence Qf hydrates is likely and win require specific treatments. The rheology will then be adjusted as needed (with a 75 seclqt target) to maintain hole integrity. The 7" longstring casing will be set and the cementwiU be pumped as per program directions (be aware that lost circulation during casing running operations has occurred on several of the offset wells). The cement will be displaced out of the casing with KCI brine and diesel for freeze protection to complete the well. Drilling Concerns: I ,---' ~ Large gravel sizes can cause hole-cleaning problems. If larger than normal gravel is encountered be prepared to increase funnel viscosity to ,150 sec/qt. Have GELEX available for an immediate response to this issue. Several wells on S-pad have encountered running gravel that has hindered the drilUng operation. )- Sticky clays in the permafrost at 900' and 1,300' - 1,6501 TVD and also in the zone below the permafrost at 1,840' - 2,200' can slow ROP from bit and BHA ballíng. Use D-Dand EMI 712 to help reduce the bit and BHA balling caused by the clays. Additions of Lubetex and Fla Lube should also be considered to help reduce torque and drag and to also help reduce with the tendency for the clays to adhere and collect on the bit and collars- :> Swabbing In the clays may also be a problem. Heavy clays are often encountered at a depth of +/-2.200' - 2.350' NO. Below this depth the formatíon makeup Îs composed of interbedded sand and clay layers. To reduce the build up of wall cake and to help reduce the possibility of differential sticking while running casing, LCM addition~ should be considered. prior to drilling into this interval. Past experience has shown that MIX II at 2 - 5 ppb and graded CaC03 at 2 -- 5 ppb introduced into the system after exiting the permafrost should be adequate to block the pore throats of the porous sands within this lithological sequénce. Maintain or slightly increase mud weight (.1 ppg) and continue additions of Lubetex/F/o Lube and also consider wiper runs through these intervals to clear the wellbore of the problem clays. I ,--..,.." }> Hvdrates are commonly f~und on S.pad .~ells. Treat the mud as per Bp4S I4Recommended Practices for Drilling Hydrates" (treating the fluid with Lecithin) to help reduce the effect the hydrates have on the drilling operation. » Lost circulation has been noted on several of the surface intervals on this pad. Be prepared to treat any fluid losses while drilling and running casing, (see the attached LCM recommended pm formula). -__.~~/2002 .~7: 05 FAX ~0.7 564 4440 BP-ACT DEPT. I4J oOi ~ ,'--..../,J Operations Operations Recommendations: 1. Spud mud will be mixed on the rig once the rig is spotted over the well. Add .2 ppb Soda Ash and 25 ppb M-l Gerto the maKe-up water (sourced as cold as possible) and allow to hydrate as long as is possible prior to drilling. 2. Just prior to spud. add Gelex, as needed, to raise viscosity to ./.100 seclqt. Maintain viscosity as required using M-I GeVGe/ex to dean the hole. 3. Drill ahead maintaining volume with additions of water! M-l Gel and Ge/ex as needed. 4. Continue disposing of cuttings utilizing the method developed and evaluated on the F pad wells. Utilize the vacuum trucks as much as possible to reduce the overall cuttings disposal cost. -...J' 5. Run all solids control equipment. Run 60 to 180 mesh shaker screens to maintain a wet discharge for enhanced solids removal. Prior to sending fluid to the disposal well insure that the mesh size selected is adequate to remove the LCM that will be added to the fluid after drilling through the permafrost. Add drìll water below shaker to avoid washing unwanted solids back into the active system. 6. Adjust rheology through the permafrost using NIl GellGelex. After exiting the permafrost utilize the native clays and polymers to increase the rheology. Note however that the use of polymers for rheology adjustments is preferable to a preferential reliance on native clays because the native clays wiJI create higher gel strepgths than will the polymers. To control excessive rheology additions of Desco CF and water may be needed to help control the native clays. 7. Treat the mud system as is outlined in the uRecomTJ1ended~ Prac~tç~!=i f9r Drillino Hvdrates!'. Have Lecithin on hand to treat the fluid. 8. Lower API fluid loss with PAC PLUS UL as needed to maintain hole stability. 9. Add Lubetex and Flo Lube to lubricate the hole and to reduce the tendency for bit balling in the clay sections. 10. If hole conditions allow, let the funnel viscosity drop to +1-75 sec/qt prior to cementing of the casing. Allow surface mud volumes to fall during the later stage of this interval to minimize waste fluid disposal costs. '-..-/ 11. Drill ahead. Adjust the rheology, pipe rotation speed, pipe running speeds and pump rates as needed to balance hole cleaning and ECD. 12. Flow rate for this Interval should be maintained above 650 gpm. , Modeling shows that rates below this will provide marginal wellbore cleaning. Pump pressures and ECD's may need to be monitored closely at these higher rates. ' 01/22/2002 17:06 F~ 907.564 4440 -~.-- BP-ACT DEPT. I4J 008 (' ,-J 13. Drill ahead. Watch for weUbore instabmty or gas influx problems. As a normal course of action any fluid weight adjustments should be prefonned in 0.1 ppg increments for lithologic difficulties and as calculated from shut in pressures for gas. 14. If hole cleaning is adequate. and torque and drag are still an issue. add lubricants as needed to reduce the torque and drag. Do not add more then 30/0 vlv of each (LubetexlFlo Lube) without consultation. 15. Monitor and record drilling parameters on each connection. 16. Upon reaching TD wateh the bottoms-up cuttings closely and circulate at least 1 % time bottoms up or until the hole is clean. Make sure to rotate the pipe while circulating. Condition the mud in preparation to run and cement the 7" casing. 17. Run and cement the 7" casing as per program. 18. Complete the well by disptacing the cement out of casing with diesel and KCI brine as per program. Recommended LCM Pin '"-) The following lost circulation pill is recommended for use in the event that losses occur while drilling the horizontal production interval. It has been selected because of its. ability to seal with minimized formation damage. These products are predominately acid soluble which will make any stimulated cleanup (if needed) much easier. » To existing fluid make a LCM pill with: . 15 ppb Lowate (fine calcium carbonate) . 15 ppb Safe-Carb Medium (medium calcium carbonate) . 15 ppb Safe-Carb Coarse (course calcium carbonate) Insure particle sizes of bridging materials can pass through the downhole tools and motors prior to mixing and spotting. 1. Spot pill across thíef zone! if losses stop, pull into casing and apply 200-psi squeeze pressure and watch for pressure bleed-off, If pressure holds for 15 minutes, resume drilling. If pressure does not hold, spot another pill as described above. 2. If losses cannot be stopped with calcium carbonate only. mix up a LCM pill with: .. 25 ppb MIX II Fine . 15 ppbMIX II Course cellulosic material and spot as above. 3. If seepage losses occur after drilling is resumed, consideration should be given to adding 5 - 8 ppb MIX II Fine cellulosic material to system white circulating. -....J ( ~ sVnâpšhöt @19!J6.2OD1 PM U.C, . All ~Is ~ Geometry Depth MD fWD {n) ~ I H Dïa {In.) (ft) 1m .! t ~ , ? 200 329:J 4266 9-716 l 9.2 Density (lbJgal) 9,-1 9:6 9.8 10_G 10.2 {} PV,YP,LSVP to 20 ~ \ PV FCD ;ESD ,-Sy~ . ¡ I I It l' r . " , . r J I , vr ( 30 Ð AV (ftlmin) 200 144 203 MD: 9299 TVO: 4267 Bit Size: 9.875 Date: 1/17/2002 ~ Hole Clean Ind VG G F P ,1 ( , . 10 , ...... , "- - ~ ~ "- ~ 0 0 ~ ...... -1 . . 0 <» 100 "!j .~ I~ I~ I: ,¡;:.. ,¡;:.. 0 ft 0 perator: ft Well Name: in. Location: Country: BP S-21ì Milne Point US JI 0 <Q 0 25 t:J:' ." I > ('} ~ t:::' 1'1j ~ ¡§;J 0 j\ 01/22/2002 17:07 FAX 907 564 4440 ~.-t.- -t--- - - -. -- BP-ACT DEPT. r:zj ',---- I Fluids and Product Usage Recommended Fluid Properties Weight Funnel Viscosity yp pH API Fluid Loss Product Usage: Weight Material viscoslflers . Fluid Loss Additives Alkalinity Control Bit Balling Lubricants Hydrate Control "---./ ~O10 ( 8.8 - 9.2 ppg' +150 sec/qt (initial) 75 secJqt (final) 25 - 40 8.5-9.0 N.C. - 6 cc/30 min. . ~ M- I Barite, M~ I Gell Gelex, Dùovis PAC Plus UL - Soda ÄSIt,. Caustic. Bicarb DD, EMI-712 Lubetex, Flo Lube. Lecithin ' Recommended Initial Spud Mud Formulations Initial Make-Up and Sweep Formulas Soda Ash M..I Gel .2 ppb 25 ppb (Add to the make-up water and allow to hydrate as long as is possible prior to drilling) add pri~r- to spud to increase the funn,el v~scosity to 90 - ~ 00 see/quart:.,.. Gelex Solids Control Equipment Shaker Screens Desander . M.ud CleêÏnerJDesllter . Centrifuge '0......-/' 60 to faD mesh (or fin~r to elimlnste - LCM added below the Permafrost) Ryn Continuously' Run Continuously as is desiJter"', Run Below Permafrost"""" 01/22/2002 17:07 FAX 907 564 4440 ~ ~t. 1_. -'- ..--.-. _. "'---/ '--_/ ',-- .) ~ Cost Estimates Interval Drill~ng BP-ACT DEPT. 14J01l Summary P10 P50 P90 $ 61,652.63 82,203.50 $123,305.25 III 2 0 2 L. 5 5 III I: 0 L. ~ 2 0 :18 g 5 I: 00 B L. L. ~ 9 III n..' "'~.'- '^."" u.... ," ¡' .,1vU.... \ ê.. c-...ß (J(V\. ,_., ... NOTVALlD AFTER 120 DAYS ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 To The ORDER Of AMOUNT $100.00 DATE 12/07/01 PAY ONE HUNDRED & 00/10Q¥************************************ US DOLLAR 00202455 56-389 4i2 No. H 202455 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO BPEXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 CONSOLIDATED COMMERCIAL ACCOUNT 100.00 100.00 TOTAL ~ HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. \ JA^: 1. Ö 2002 Alaska Oil & Gas Cons. Commission An jhorage tl1VS-ê) /1 RECEIVED Per nit to Drill ~ee S/H - Terrie Hub~le X4628 120501 CK120501E PYMT COMMENTS: HANDLING INST: 00 VENDOR ALASKAOI LA DISCOUNT NET GROSS 100.00 DESCRIPTION INVOICE / CREDIT MEMO DATE 100.00 CHECK NO. 00202455 DATE 12/07/01 H 202455 CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL ~ INJECTION WELL REDRlLL TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITI AL LETTER WELL NAME !J?//v( 0- zit' CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) Pll.,OT HOLE (PH) . ANNULf;POSAL , NO ANNULAR DISPOSAL L..J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well -----' Permit No, , API No. . " Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be dearly . 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). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS L..J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved ,sùbject 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. (Company Name) will assume tbe liability of any protest to the spacing exception that may occur. b'd. øPd, WELL PERMIT CHECKLIST COMPANY -l){/j::::, WE,LL NAME.;:5- 21¿ PROGRAM: exp - dev ~ redrll - serv / wellbore, seg _ann. disposal para req - FIELD & POOL 52'.5/'-/6 INITCLASS ~t/lc.d- 1tJlAl.J GEOLAREA l!q/) UNIT# /Y/I":?~ ON/OFFSHOREO;1 ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool. . . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated. is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Pennit can be issued without conservation order. . . . . . . . ~R DATE 12. Pennit can.be issued without administrative approval. . . . . . /. 2--'"2. D"V 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y NGINEERING 14. Conductor string provided . . . . . . . . .. . . . . . . . .~ f", N J/~¡T\/¡) J' C/21,1A...ev<..-kj ~ lZiPo Ç,,¡L. As. 15. Surface casing protects all known USDWs. . . . . . . . N '. 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N Ackc..<luM en¿(~. ~f f}mfJo ç.¿d . 17. OMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y N f\i./A {/ 18. CMT will cover all known productive horizons. , . . . '. . . . . ~ N 19. Casing designs adequate for C. T, B & pennafrost. . . . . . . ,'N - L t1E 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ^,up oy> 21. If a re-cirill. has a 10-4,03 for abandonment been approved., . . ~' N "'/ A 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N . 23. If diverter required, does it meet regulations. . . . . . . . . . N Piv'4~v to TÞ ¡ MM P =- J50éf fS¿. ¡¿';\I. fCi...-tt?c:Î 2000 f}.t... 24. Drilling ,fluid program schematic & equip list adequate. . , , . 'N. 25. BOPEs, do they meet regulation. , . . , . , . . . . . . . . . Y N IV IA APPR DA T_~ 26. BOPE press rating appropriate; test to psig. Y N tJ.1. A WC7A- 'I 'Z. i 0 ~. 27. Choke' manifold complies w/API RP-53 (May 84). . . , . . . . (ý) N ,.~. \/~ -.~ ;?) 28. Work will occur without operation shutdown. . . . . . . . . . . f() ~') 'J - -L" J J I é . ~/:V{ (X""" 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . '1 ~ Nro"t o.e~~(,..~Q 11l..==> o.~ . '., ..,' GEOLOGY, 30. Pennit can be issued wlo ,hydrogen sulfide measures. . . .. 'iV) N (){r~ ¡lIZ/ t<.><./i: LL~ ~ u"~/F ~ ~ 4/.2,. w»¡ ¡¡; .s Æ - 31. Data presented on potential overpressure zones. . . , , . . '-f~ t2í/~IJ~LJ~ ~ R-;G¡p(¿<!..--k.-:/, ¡ff'1':h~~~~'iJl!NÍ"'"~~ ;'~ð"r#' 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . .~. /{ N /¿g.k!!h)J/ ~.slr 7c-Y .~/':J?I-K-Ä-< ¿~ 3'?u:¿t'(ð-u ~ . £dr4../ú , 'IV A~~ DATE 33. Seabed condition survey (If off-shore). . . . . . . . . , . . . Y N cJ ~ . ß~ /. };Z 'D2- 34. Contact name/phone for weekly progress reports [explorat only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. " to surface;' ' (C) will not impair mechanical integrity .of the well used for disposal; Y N (D) will not damage producing formation .or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ~21NEERING:UIC/Annular COMMISSION: ~~~C ~ v" WM '89s ;51> TEM /l9!N V:$;¡-0;> JMH rl141 ~ APPR DATE Y N Y N ;Jo CwLI/U<-It?vv J; S~~~. Com ments/lnstructions: \, zsl œ.. c:\msoffice\wordian\diana\checklist (rev. 11/011100) '0 0 Z ) 0 -t :E ::0 -t m Z -t :I: en » ::0 m » Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim.pltfy finding information, infonnation 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 infonnation. ( ój ~-oo9 /1/19 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Oct 04 14:22:38 2002 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 10 / 04 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 Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 10 / 04 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-21 500292306500 B.P. Exploration (Alaska), Inc Sperry-Sun Drilling Services 04-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22018 D. LABRECQUE E. VAUGHN MWDRUN 2 AK-MW-22018 D. LABRECQUE E. VAUGHN MWDRUN 3 AK-MW-22018 R. FRENCH E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3300 223 73.25 39.00 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 112.0 (' ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS, AND ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 -3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. LOG AND DIGITAL DATA (LDWG) ONLY ARE SHIFTED TO THE SCHLUMBERGER GAMMA RAY RUN ON 4/23/02; LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. THIS PDC LOG WAS PROVIDED BY D. SCHNORR, GEOQUEST(BP). 5. MWD RUNS 1 - 3 REPRESENT WELL MPS-21 WITH API#: 50-029-23065-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9453'MD / 4426'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...... .02/10/04 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 127.5 127.5 127.5 127.5 127.5 STOP DEPTH 9407.5 9407.5 9407.5 9407.5 9407.5 GR 129.5 8323.5 8365.0 8377.0 8382.5 8388.5 8397.5 8411.5 8415.5 8420.0 8437.0 8446.5 8458.0 8474.0 8481.0 8523.5 8547.5 8557.5 8573.0 8596.5 8600.0 8608.0 8613.5 8642.5 8655.0 8680.5 8696.0 8699.5 8713.5 8721.0 8746.5 8765.0 8814.0 8826.5 8840.5 8843.5 8849.0 8895.0 8904.0 8910.0 8929.0 8939.0 8947.5 8955.0 8986.0 9001.5 9008.0 9032.0 9048.5 9055.0 9070.5 9087.5 9110.5 9118.5 9134.5 9182.0 9204.5 BASELINE DEPTH 127.5 8321.5 8363.5 8375.5 8380.5 8384.5 8394.0 8407.0 8411.0 8416.0 8437.0 8446.5 8461.0 8473.0 8481.5 8522.5 8548.0 8556.5 8569.5 8594.0 8597.0 8606.0 8611.0 8640.0 8654.5 8679.5 8697.0 8701.0 8715.5 8723.5 8748.0 8765.5 8812.5 8824.5 8839.0 8842.5 8846.5 8893.5 8905.0 8911.5 8927.0 8939.0 8946.5 8954.5 8983.5 9000.0 9008.5 9030.0 9046.5 9054.0 9068.5 9085.5 9106.5 9118.5 9134.5 9180.5 9205.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -- 9415.5 9452.5 135.5 172.0 ( ( GR ROP $ ( 9213.0 9242.0 9253.0 9262.5 9278.5 9288.0 9452.0 $ 9212.0 9241.5 9254.0 9262.0 9277.5 9289.0 9453.0 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 129.5 2 4850.0 3 7061.0 MERGE BASE 4850.0 7061.0 9453.0 # REMARKS: MERGED MAIN PASS. $ # 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 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 127.5 9452.5 4790 18651 127.5 9452.5 ROP MWD FT/H 2.86 13033.3 252.076 18562 172 9452.5 GR MWD API 6.9 147.81 64.4032 18561 135.5 9415.5 RPX MWD OHMM 0.17 2000 104.892 18561 127.5 9407.5 RPS MWD OHMM 0.17 2000 111.942 18561 127.5 9407.5 RPM MWD OHMM 0.17 2000 102.747 18561 127.5 9407.5 RPD MWD OHMM 0.11 2000 181.393 18561 127.5 9407.5 FET MWD HOUR 0.06 46.76 0.758018 18561 127.5 9407.5 First Reading For Entire File........ ..127.5 Last Reading For Entire File......... ..9452.5 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/10/04 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...... .02/10/04 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 FET RPM RPS RPX RPD GR ROP $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 129.5 129.5 129.5 129.5 129.5 137.5 174.0 # 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 $ STOP DEPTH 4805.0 4805.0 4805.0 4805.0 4805.0 4813.0 4850.0 02-FEB-02 Insite 66.16 Memory 4850.0 112.0 4850.0 .0 77.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02434HRG6 PB02434HRG6 # 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): 9.875 112.0 Water 9.35 132.0 8.0 600 ( 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: 10.4 1.800 1.800 2.000 2.200 65.0 65.0 65.0 65.0 # 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 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 4850 2489.75 9442 129.5 4850 ROP MWD010 FT/H 10.42 1320.59 216.327 9353 174 4850 GR MWD010 API 6.9 113.42 62.2561 9352 137.5 4813 RPX MWD010 OHMM 0.17 2000 193.94 9352 129.5 4805 RPS MWD010 OHMM 0.17 2000 205.86 9352 129.5 4805 RPM MWD010 OHMM 0.17 2000 185.319 9352 129.5 4805 RPD MWD010 OHMM 0.11 2000 340.992 9352 129.5 4805 FET MWD010 HOUR 0.08 5.3 0.472789 9352 129.5 4805 First Reading For Entire File........ ..129.5 Last Reading For Entire File......... ..4850 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/04 Maximum Physical Record. .65535 F i 1 e 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...... .02/10/04 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 FET RPD RPM RPS RPX GR ROP $ 3 ( header data for each bit run in separate files. 2 .5000 START DEPTH 4805.5 4805.5 4805.5 4805.5 4805.5 4813.5 4850.5 # 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 $ STOP DEPTH 7016.0 7016.0 7016.0 7016.0 7016.0 7024.0 7061.0 03-FEB-02 Insite 66.16 Memory 7061.0 4850.0 7061.0 72.0 76.8 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02434HRG6 PB02434HRG6 # 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): 9.875 112.0 LSND 9.25 73.0 8.0 500 6.7 ( ( RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1.800 1.500 2.000 2.200 65.0 79.2 65.0 65.0 # 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 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 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 4805.5 7061 5933.25 4512 4805.5 7061 ROP MWD020 FT/H 15.82 844.56 389.212 4422 4850.5 7061 GR MWD020 API 27.76 127.73 71.4189 4422 4813.5 7024 RPX MWD020 OHMM 5.51 30.46 9.90459 4422 4805.5 7016 RPS MWD020 OHMM 5.59 29.27 9.77979 4422 4805.5 7016 RPM MWD020 OHMM 5.63 31.72 9.81931 4422 4805.5 7016 RPD MWD020 OHMM 5.97 30.56 10.2622 4422 4805.5 7016 FET MWD020 HOUR 0.06 16.61 0.626893 4422 4805.5 7016 First Reading For Entire File......... .4805.5 Last Reading For Entire File.......... .7061 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/10/04 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.... ...02/10/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.... ...STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 ( header data for each bit run in separate files. 3 .5000 START DEPTH 7016.5 7016.5 7016.5 7016.5 7016.5 7024.5 7061.5 # 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 $ STOP DEPTH 9408.0 9408.0 9408.0 9408.0 9408.0 9416.0 9453.0 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) 07-FEB-02 Insite 66.16 Memory 9453.0 7061.0 9453.0 39.9 75.8 TOOL NUMBER PB02434HRG6 PB02434HRG6 9.875 112.0 LSND 9.30 73.0 8.0 800 5.8 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1.700 1.250 2.100 2.200 65.0 90.5 65.0 65.0 # 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 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 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 7016.5 9453 8234.75 4874 7016.5 9453 ROP MWD030 FT/H 2.86 13033.3 195.617 4784 7061.5 9453 GR MWD030 API 17.58 147.81 62.101 4784 7024.5 9416 RPX MWD030 OHMM 1.64 112.98 18.6448 4784 7016.5 9408 RPS MWD030 OHMM 1.71 180.37 22.8044 4784 7016.5 9408 RPM MWD030 OHMM 1.72 353.38 27.2519 4784 7016.5 9408 RPD MWD030 OHMM 1.88 391.83 27.6652 4784 7016.5 9408 FET MWD030 HOUR 0.15 46.76 1.44207 4784 7016.5 9408 First Reading For Entire File........ ..7016.5 Last Reading For Entire File.......... .9453 File Trailer Service name..... ...... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/10/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name........ ...STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 /10 /04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/10/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File ( Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services