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Home My WebLink About201-0781. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ 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 12,087 feet 10,523 & 11,147 feet true vertical 4,436 feet N/A feet Effective Depth measured 10,523 feet 9,854 & 9,962 feet true vertical 4,327 feet 4,160 & 4,187 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TC-II 9,963' 4,188' 7" x 4-1/2" HES T&T Packers and SSSV (type, measured and true vertical depth)7" x 5" SL-ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: Burst N/A Collapse N/A 5,410psi11,160' N/A N/A 7,240psi 8,430psi N/A N/A 10,419' 4,303' 7,500psi 3,405' Casing Conductor 4,360' 4,345' 13,668' 13,810' 456' 11,194'Production Liner L2 Liner 13-3/8" 7" 4-1/2" 79' ADL0025516, ADL0047434 & ADL0047437 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT C-41 Plugs Junk measured measured TVD 4-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-078 50-029-23014-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 110' Size 110' 4,398' Length L1 Liner 3,583' N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 1180 000 0 1960205 160 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 323-121 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.12 07:23:49 -08'00' David Haakinson (3533) Other Stimulate MILNE POINT / SCHRADER BLUFF OIL 323-121 DSR-4/13/23WCB 12-27-2023 MILNE PT UNIT C-41 RBDMS JSB 041323 201-078 Service Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 LRS 50-029-23014-00-00 201-078 3/22/2023 3/22/2023 3/24/2022 - Friday No operations to report. 3/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I = 1550/1267 Oil Safe AR Treatment, Pumped 7 bbls Oil Safe AR, Pumped 146 bbls produced water down Tubing, Pumped 5 bbls 60/40 flowline freeze protect, FWP = 1100/1500 3/23/2022 - Thursday No operations to report. No operations to report. No operations to report. 3/25/2022 - Saturday No operations to report. 3/28/2023 - Tuesday 3/26/2023 - Sunday No operations to report. 3/27/2023 - Monday Pumped 7 bbls Oil Safe AR, Pumped 146 bbls produced water down Tubing, Pumped 5 bbls 60/40 flowline freeze protect, 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): 12,087'N/A Casing Collapse Conductor N/A Production 5,410psi Liner 7,500psi L2 Liner N/A L1 Liner N/A 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: Conditions of approval: Notify AOGCC 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 AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4,436' 10,523' 4,327' 4,302 10,523 & 11,147 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: AOGCC USE ONLY Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 Authorized Title: Operations Manager Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 3/1/2023 7" x 4-1/2" HES T&T, 7" x 5" SL-ZXP and N/A 9,854 MD/ 4,160 TVD & 9,962 MD/ 4,187 TVD PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 201-078 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23014-00-00 Hilcorp Alaska LLC MILNE PT UNIT C-41 MILNE POINT / SCHRADER BLUFF OIL C.O. 477.05 ADL0025516, ADL0047434, ADL0047437 C.O 477 & Length Size 110' 110' 12.6# / L-80 / TC-II TVD Burst 9,963 N/A MD N/A 8,430psi 7,240psi4,398' 4,303' 11,194' 79' 13-3/8" 7"11,160' 456' N/A Perforation Depth MD (ft): 10,419' See Schematic 3,583' 4-1/2" See Schematic 13,810'3,405' 4-1/2" 4,345' 4,360'4-1/2" 4-1/2" 13,668' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 1:31 pm, Feb 27, 2023 323-121 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.02.27 12:56:00 -09'00' David Haakinson (3533) Approved to stimulate with acid to 2500 psi surface pressure to break skin at perforation. Longterm injection to remain below formation fracture pressure of 0.65 psi/ft. MGR03MAR23 DSR-2/27/23SFD 2/27/2023 10-404 GCW 03/07/23JLC 3/7/2023 3/7/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.07 12:15:52 -09'00' RBDMS JSB 030923 Well: MPC-41 PTD: 2010780 API: 50-029-23014-00-00 Well Name:MPC-41 API Number:50-029-23014-00-00 Current Status:Injector Rig:Fullbore LRS Estimated Start Date:03/01/2023 Estimated Duration:1 days Regulatory Contact:Tom Fouts AFE:222-00420.08.02 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Brian Glasheen (907) 564-5277 (O) (907) 545-1144 (M) Current Bottom Hole Pressure:Injecting at 2,388 WHP, Estimated (0.45 psi/ft) 4,271 psi Max. Anticipated Surface Pressure:4,302 psi (Based on 0.1 psi/ft. gas gradient) Brief Well Summary: C-41 was a shut-in Schrader Bluff Oa dual lateral producer that was converted to an injector and had not injected since 2018. The well has a cement retainer w/ +/- 80’ cement on top in the 4-1/2” tbg. 13-3/8” casing was run to 110’ and cemented with 260 sacks of Arctic set cement. A 7’’ production casing was run to 11,197’ MD and cemented in place with 1,456 sacks of 10.7 ppg Arctic set II cement followed by 792 sacks of 15.7 ppg class G cement. During the cement job full returns were observed at surface. In January CTU added perforations in the N sand. The N-sand is currently taking between 200-300 BWPD at over 2,000 psi WHP. It is believed there is severe skin in the perforations. The fracture gradient of the Schrader NB is estimated to be 0.6 psi/ft for a pressure of 2,511 psi at the top of the perforations. Based on the current injection performance it is evident there is significant skin after perforating the NB in MPC-41. The skin is likely due to poor perforation performance perforating through 4- 1/2” tubing, cement, and 7” casing. The well was unable to sustain injection until surface pressure was increased to ~2,000 psi. The chart below shows the injection rate vs injection pressure. A break from a linear slope has not been observed indicating we are not currently frac’ing away injection fluid but experiencing significant pressure loss across the perforations. Well: MPC-41 PTD: 2010780 API: 50-029-23014-00-00 Objectives: The objective of this procedure is to spot acid across the newly perforated zone. Allow the acid to soak and then resume water injection. Well Notes: Coil added perforations in the N-sand from 9,952’-10,009’ MD (4,185’- 4,199’ TVD). Limit maximum allowable pumping surface pressure to 2500 psi to avoid frac’ing away acid. Fluid Denisities: Produced Water: 8.65 ppg OilSafe AR: 9.25 ppg Procedure: Fullbore 1. Rig up LRS 2. Establish circulation down tubing with produced water. a. Well is currently taking ~336 BWPD at 2,158 psi. b. Expect to pump fluids between 0.25 and 0.5 BPM. c.Limit pump pressure to 2500 psi. 3. Pump a full tote (~7 bbls) of OilSafe AR. 4. Follow acid with 146 barrels of produced water and 5 barrels of 60/40 methanol (flowline freeze protect) a. Goal is to spot acid across perfs. b. Volume to top perforation is 151 barrels. 5. Shutdown injection leaving acid to soak at perforations for at least 12 hours. 6. Bring well on injection after 12 hour soak. Tree: 4 1/2 ", 5M Wellhead:11" x 4 1/2 " TCII T&B. Hnr. w/4-1/2" Type 'H' BPV profile DATE REV. BY COMMENTS MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 BP EXPLORATION (AK) MPC-41 KB elev. = 30.10’ DF elev. = 45.17’ GL elev. = 16.50’ 4-1/2” SLOTTED INTERVALS 83 jts of slotted liner ( 10,515‘-13,765’) 4.5“ 12.6# L-80 IBT tubing Baker Guide Shoe @ 13,810‘ Baker Packoff Bushing @ 13,765’ OA L2 - 10,515‘ - 13,765’ MD 4,324‘ - 4,345’ TVD OA L1 - 10,695’ - 13,623’ MD 4,345‘ - 4,348’ TVD Baker Payzone Packer (13,954’ - 13,977‘) 3 jts 4.5“ 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096’ 4.5” Halliburton Float Shoe 14,141‘ 7.5 bbls (493’) cement (13,977’ - 14,470) Halliburton Casing shoe 11,194‘ 110' Mill to 10,098' Hole Punch 10,010' to 10,015' 4-1/2" Cement Retainer 9,930' 4-1/2" CIBP 10,450' Perfed 9,952' to 10,009' MD (4,185' to 4,199' TVD) 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Mill Cement 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 12,087 feet 9,825 feet true vertical 4,436 feet N/A feet Effective Depth measured 9,825 feet 9,854 & 9,962 feet true vertical 4,152 feet 4,160 & 4,187 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TC-II 9,963' 4,188' 7" x 4-1/2" HES T&T Packers and SSSV (type, measured and true vertical depth)7" x 5" SL-ZXP N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 322-184 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 110' 0 Size 110' 4,398' 265 13900 0 12700 2175 measured TVD 4-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-078 50-029-23014-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025516, ADL0047434 & ADL0047437 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT C-41 Plugs Junk measured Length L1 Liner 3,583' 3,405' Casing Structural 4,360' 4,345' 13,668' 13,810' 456' 11,194'Production Liner L2 Liner 13-3/8" 7" 4-1/2" 79' 11,160' N/A N/A 7,240psi 8,430psi N/A N/A 10,419' 4,303' Burst N/A Collapse N/A 5,410psi 7,500psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 8:01 am, Feb 17, 2023 Schrader Bluff Oil Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.02.17 07:09:31 -09'00' David Haakinson (3533) RBDMS JSB 120623 Mill Cement DSR-2/22/23 Perforat WCB 11-20-2023 201-078 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT C-41 Sundry Number 322-184 Tree: 4 1/2 ", 5M Wellhead:11" x 4 1/2 " TCII T&B. Hnr. w/4-1/2" Type 'H' BPV profile DATE REV. BY COMMENTS MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 BP EXPLORATION (AK) MPC-41 KB elev. = 30.10’ DF elev. = 45.17’ GL elev. = 16.50’ 4-1/2” SLOTTED INTERVALS 83 jts of slotted liner ( 10,515‘-13,765’) 4.5“ 12.6# L-80 IBT tubing Baker Guide Shoe @ 13,810‘ Baker Packoff Bushing @ 13,765’ OA L2 - 10,515‘ - 13,765’ MD 4,324‘ - 4,345’ TVD OA L1 - 10,695’ - 13,623’ MD 4,345‘ - 4,348’ TVD Baker Payzone Packer (13,954’ - 13,977‘) 3 jts 4.5“ 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096’ 4.5” Halliburton Float Shoe 14,141‘ 7.5 bbls (493’) cement (13,977’ - 14,470) Halliburton Casing shoe 11,194‘ 110' Mill to 10,098' Hole Punch 10,010' to 10,015' 4-1/2" Cement Retainer 9,930' 4-1/2" CIBP 10,450' Perfed 9,952' to 10,009' MD (4,185' to 4,199' TVD) Well Name Rig API Number Well Permit Number Start Date End Date MPU C-41 CTU 50-029-23014-00-00 201-078 1/14/2023 1/30/2023 CTU #9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. RIH/PU to flag. Correct depth at flag and perforate 9968-9998' CTM. POOH. MU 2nd HES 2.75" GEO Razor guns and RIH. Correct depth at flag and perforate 9952'-9970' CTM. POOH. MU 3rd run HES 2.75" GEO Razor guns and RIH. Correct depth at flag and perforate 9999'-10009' CTM. POOH and FP well. RDMO. CTU #9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. MIRU CTU. Job Continued 1-15-23. 1/14/2022 - Saturday CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. Mill to 10098'. Confirm with OE that deep enough. Pump gel sweep and chase OOH. Park at 3500' and circ in diesel for freeze protect. POOH and MIT-T well. MIT-T not stablized. Discuss with OE. MIT-IA well-pass. RIH with HES logging tools. POOH and confirm good data. OE/GEO confirms +17' correction. MU HES 2.75" GEO Razor guns and RIH. 1/17/2023 - Tuesday 1/15/2023 - Sunday CTU #9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. MIRU CTU. MU BOT milling BHA and RIH and mill cement from 9820' to 10098'. 1/16/2023 - Monday 1/13/2022 - Friday No operations to report. 1/11/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/12/2022 - Thursday No operations to report. CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. Mill to 10098' Correct depth at flag and perforate 9968-9998' CTM. POOH. MU 2nd HES 2.75" GEO Razor guns and RIH. Correct depth at flag and perforate 9952'-9970' CTM. POOH. MU 3rd run HES 2.75" GEO Razor guns and RIH. Correct depth at flag and perforate 9999'-10009' CTM. POOH and FP well. RDMO. Well Name Rig API Number Well Permit Number Start Date End Date MPU C-41 CTU 50-029-23014-00-00 201-078 1/14/2023 1/30/2023 No operations to report. No operations to report. 1/21/2022 - Saturday T/I/O= 2145/1398 (Pre AOGCC MIT-IA PASSED) Pressured up IA to 1765 psi with .35 bbls of 120* diesel. 1st 15 min IA lost 9 psi. 2nd 15 min IA lost 2 psi for a total loss of 11 psi in 30 min. Bled IA to 1000 psi, bled back .65 bbls. Final Whps=2146/1000. 1/24/2023 - Tuesday 1/22/2023 - Sunday No operations to report. 1/23/2023 - Monday 1/20/2022 - Friday T/I/O=450/146/NA (Warm up TBG/POI) Pumped 2 bbls 60/40 followed by 90 bbls of 110* produced water down TBG, capped with 3 bbls 60/40. Pad Op to POI. Final Whp's=1450/1350 1/18/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Mill cement, Log, Adperf. Finish RDMO. 1/19/2022 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MPU C-41 LR 50-029-23014-00-00 201-078 1/14/2023 1/30/2023 No operations to report. No operations to report. 1/28/2022 - Saturday T/I = 2235/1316 AOGCC MIT-IA, 2700 psi Passed, First 15 min IA lost 47 psi, Second 15 min IA lost 7 psi, 1.3 bbls diesel to pressure up, FWP = 2230/1300 1/31/2023 - Tuesday 1/29/2023 - Sunday No operations to report. 1/30/2023 - Monday 1/27/2022 - Friday No operations to report. 1/25/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/26/2022 - Thursday No operations to report. AOGCC MIT-IA, 2700 psi Passed, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-41 MILNE PT UNIT C-41 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 C-41 50-029-23014-00-00 201-078-0 W SPT 4160 2010780 2000 2232 2250 2233 2232 OTHER P Kam StJohn 1/29/2023 MIT-I/A to 2000 psi per 322-184 after Coil milling cement and add perf. Mono bore 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-41 Inspection Date: Tubing OA Packer Depth 1312 2901 2854 2847IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230129155701 BBL Pumped:1.3 BBL Returned:1.3 Friday, March 17, 2023 Page 1 of 1            Test was due 5/2020; well was suspended (plug) 11/2018; jbr Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/23/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 1-09A 50029217430100 197029 1/15/2023 HALLIBURTON MFC40 END 1-09A 50029217430100 197029 1/16/2023 HALLIBURTON MFC40 MPU C-41 50029230140000 201078 1/16/2023 HALLIBURTON COILFLAG PBU W-06B 50029218220200 222099 1/6/2023 BAKER MRPM Please include current contact information if different from above. 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Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƉĞƌĨŐƵŶƐ ŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘ ϭϰ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐƵŶƐƉĞƌƐĐŚĞĚƵůĞďĞůŽǁ͘ŽŶƐƚĂŶƚůǇ ŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚ ǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ WĞƌĨ^ĐŚĞĚƵůĞ ΎϮ͘ϳϱ͟'ĞŽZĂǌŽƌŐƵŶƐǁĞƌĞƵƐĞĚƚŽĞƐƚŝŵĂƚĞĨŽƌƚŚŝƐũŽďĂŶĚĐĂůĐƵůĂƚĞŐƵŶǁĞŝŐŚƚƐ͘ WĞƌĨ/ŶƚĞƌǀĂů WĞƌĨ>ĞŶŐƚŚ 'ƵŶ>ĞŶŐƚŚ tĞŝŐŚƚŽĨ 'ƵŶ;ůďƐͿ ZƵŶϭ ^ĐŚƌĂĚĞƌE ϵϵϱϮͲϭϬϬϭϮ͛D ;ͲϰϭϰϬͲхͲϰϭϱϱ͛dsƐƐͿ ϲϬ͛ ϲϬ͛dŽƚĂů ϱϱϮůďƐ ;ϵ͘ϮƉƉĨͿ ϭϱ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐĐŽƌƌĞůĂƚŝŽŶ͘WŝĐŬƵƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌWĞƌĨ^ĐŚĞĚƵůĞĂďŽǀĞ͘ Ă͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϲ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ϮϬϬ͛ƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůů ŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇ͕ďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ ϭϳ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϴ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘ ϭϵ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ŐƵŶ,͘ tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ ϮϬ͘ ZDKdh͘ Ϯϭ͘ ZdWŽƌ&WǁĞůů͘ WK^dǆƚĞŶĚĞĚƉĞƌĨƐ͗ &ƵůůďŽƌĞ ϮϮ͘ D/dͲ/ƚŽϮϬϬϬƉƐŝĂĨƚĞƌƐƚĂďŝůŝǌĞĚŝŶũĞĐƚŝŽŶ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϱ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ ϲ͘ dŝĞ/Ŷ>ŽŐͬWĞƌĨ^ŚĞĞƚ tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ 7UHH 0 :HOOKHDG [ 7&,, 7 % +QU Z 7\SH + %39 SURILOH '$7( 5(9 %< &200(176 0,/1( 32,17 81,7 :(// & $3, 12 %3 (;3/25$7,21 $. 03&.% HOHY ¶ ') HOHY ¶ */ HOHY ¶ ´ 6/277(' ,17(59$/6 MWV RI VORWWHG OLQHU µ¶ ³/,%7WXELQJ %DNHU *XLGH 6KRH # µ %DNHU 3DFNRII %XVKLQJ # ¶ 2$ / µ ¶ 0' µ ¶ 79' 2$ / ¶ ¶ 0' µ ¶ 79' %DNHU 3D\]RQH 3DFNHU ¶ µ MWV ³ / ,%7 6ROLG WXELQJ +DOOLEXUWRQ )ORDW &ROODU ¶ ´ +DOOLEXUWRQ )ORDW 6KRH µ EEOV ¶ FHPHQW ¶ +DOOLEXUWRQ &DVLQJ VKRH µ 0LOOWR +ROH3XQFK WR &HPHQW5HWDLQHU &,%3 3HUIV WR 0' WR 79' 352326(' tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ ŽŝůĞĚdƵďŝŶŐKWƐ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ 7LH,Q tĞůů͗DWͲϰϭ Wd͗ϮϬϭϬϳϴϬ W/͗ϱϬͲϬϮϵͲϮϯϬϭϰͲϬϬͲϬϬ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations Ll Fracture StimulateLl Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate[:] Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforale New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: Inspect Well ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Stratigraphic❑ Exploratory ❑ Service ❑� 201-078 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23014-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025518 MILNE PT UNIT C-41 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 12,087 feet Plugs measured 9,825 feet true vertical 4,436 feet Junk measured N/A feet Effective Depth measured 9,825 feet Packer measured 9,854 & 9,962 feet true vertical 4,152 feet true vertical 4,160 & 4,187 feel Casing Length Size MD TVD Burst Collapse Conductor 79' 13-3/8" 110' 110' NIA N/A Production 11,160' 7" 11,194' 4,398' 7,240psi 5,410psi Liner 456' 4-1/2" 10,419' 4,303' 8,430psi 7,500psi L2 Liner 3,583' 4-1/2" 13,668' 4,360' N/A N/A L1 Liner 3,405' 4-1/2" 13,810' 4,345' N/A NIA Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / TC -II 9,963' 4,188' 7" x 4-1/2" HES T&T Packers and SSSV (type, measured and true vertical depth) 7" x 5" SL-7XP N/A See Above N/A 12. Stimulation or cement squeeze summary: NIA Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 1 0 0 Subsequent to operation: 1 0 0 0 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory[] Development E] Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑Z SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations M nager Contact Email: wriyard(a)hiICOrp.cOm Authorized Signature: (/ y �--- Date: 8/13/2019 Contact Phone: 777-8547 M Form 10-404 Revised 4/2017 'wil)4(i RBDMS AUG 2 12019 Submit Original Only Tree: 41/2", 5M MPC -41 KBelev. =30.10' Wellhead: 11"x 41/2 "TCII T&B. Hnr. w/ DF elev. = 45.17' 4-1/2" Type'H' BPV profile GL elev. = 16.50' 133/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' Itilrorp Alaska,lAA: 7" 2( ppf, L -SC, B1ra praducden ageing SCHEMATIC Revised 1/29/2019 (ddB 10.6.161", cap.. C.CG C. bpl) 4.5" 12.6# L-80 TG- 11 tubing ( ID= 3.956', ccap=.01528PF) 4-1/2" SLOTTED INTERVALS OA L2 - 10,515' - 13,765' MD 4,324' - 4,345' TVD OA L1 -10,695' - 13,623' MD 4,345' - 4,348' TVD 7113/B1 MW Unnea a t:acee Naoofa ate 7124111 B. Hasebe, ESP Completion Nabors 4ES 7/18/05 I Lee Hulme I Isolate L2 & Open L1 Sands 4 -ES 3/25/14 B.Kruskie Doyon 16 RWO from ESP to Injector 4-1&X Nipple{3.813"IDj 9823' TOC 9,825' 7X 4-1t2 L-83 HES T&T Packer 9854' MOP ®aCf' Max Mdll;ae Angle- 75' A 0a(V-1(,CEV MD 4-1f2XNipple{3813"10) 9890. Hole angle trough pato = 9C deg. 4-112" Cement Retainer 9,930' 7"x 5` Baku SL-ZXP Leer top pkr. 9,962' ■[ ' 4-L2- WLEG 9962 Hole Punch 10,010 to 10,015' Sleeve dosed during 7118105 RM 10,04 t' Upper Window 10,091'- 10,103' , 4.5" Baker CMD Sbdig sleeve L2 4.5' HES XN Nipple ( 3.725- WGre 10,398 4.5 12.6#L -8C IBTtubino Baker Tie backstem 5.25" -4.375"10,419' 14jts. of solid Itner(1C,1C9'-1C,696') 740s- of Slotted Liner (10,695 -13,623') Lower Window 10,505' -10,518') Baker float shoe ® 13,568' 4-112" CIBP 10,450' Baker packolf bushing ® 13,623' L' Baker HR settino sleeve 10,405' Baker HMC Ilner hangar 1C 421' 83#z of slotted liner (1 C,515'-13,755') EZSV Bridge Plug #2 10523' 45" 12.6*L-SC IBTtubino (Above Abandoned Lateral) Baker Guide Shoe V 13,816 Halliburton float cc -liar 11,113' Baker PackVI ,13,,7F.F' EZSV Bridge Plug 41 11,147` (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer (13,954' - 13,977') 3 jts 4.5" 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open -Hole OB Lateral to 12,205' MD 4.5" Halliburton Float Shoe 14,141' 75 bbls (493') cement (13,977' - 14,470) 4-1/2" SLOTTED INTERVALS OA L2 - 10,515' - 13,765' MD 4,324' - 4,345' TVD OA L1 -10,695' - 13,623' MD 4,345' - 4,348' TVD 7113/B1 MW Unnea a t:acee Naoofa ate 7124111 B. Hasebe, ESP Completion Nabors 4ES 7/18/05 I Lee Hulme I Isolate L2 & Open L1 Sands 4 -ES 3/25/14 B.Kruskie Doyon 16 RWO from ESP to Injector Date Inspected: w STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Operator:r,�ur�pi za4�Yb Oper. Rep: /v1=-, i! ^f� Oper. Phone: S Oper. Email: AL1nt4(L (-1;:, ,CDS Suspension Date: Date AOGCC Notified:'�f" 14"W440-"W44e.- z o 6 ^ (� Type of Inspection: ®ai5 JS �pv G t t1We1lbDfe Diagram Avail.? Y.� Well Pressures (psi): Tubing IVA Photos Taken? IA .4!�' OA _AIJA Of of ng Surface up Aciions "�jC�'l3twT �u IESs a v �E 1z, c3PL�.� SS✓ G- r REVIEWED BY: Insp. Supra Comm PLO 1212674 Newest Copy of Suspended Well Inspection Form - Copy %% qp6 Inspector: Well Name: 41 J PTD No.: a O`' p- 7 Q Location Verified? 1 E 5 If verified, How? -PAb A5. -dutw.'i' tAA�' )nehore Offshore: Operator:r,�ur�pi za4�Yb Oper. Rep: /v1=-, i! ^f� Oper. Phone: S Oper. Email: AL1nt4(L (-1;:, ,CDS Suspension Date: Date AOGCC Notified:'�f" 14"W440-"W44e.- z o 6 ^ (� Type of Inspection: ®ai5 JS �pv G t t1We1lbDfe Diagram Avail.? Y.� Well Pressures (psi): Tubing IVA Photos Taken? IA .4!�' OA _AIJA Of of ng Surface up Aciions "�jC�'l3twT �u IESs a v �E 1z, c3PL�.� SS✓ G- r REVIEWED BY: Insp. Supra Comm PLO 1212674 Newest Copy of Suspended Well Inspection Form - Copy WELL NAME R41, Rvil11, R41 OWNER Milne Point Unit OPERATOR RILCORP Masks, LLC SUR, LOCATION SE 1 A, Sec. 10, T1 3N, R1 OE DRILLING PERMIT 201-078 1 7 a;�' ',df�`f'��5'�"�y�Y'�4 I� �.?'lh�Z�Yi�' ,�P' � _`C rswM. �.F w ti. _.•'.1 r_ .. ..r. �- . _ .. Suspended Well Inspection Review Report InspectNo: susBDB190805064001 Date Inspected: 8/1/2019 Inspector: Brian Bixby Type of Inspection: Initial Well Name: MILNE PT UNIT C-41 Permit Number: 2010780 Suspension Approval: Sundry # 318-432 Suspension Date: 1/12/2019 - Location Verified? ❑O If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Wellhead Condition Good Tubing: IA: 0 OA: Condition of Cellar Good, Looks very clean - Surrounding Surface Condition Good Date AOGCC Notified: 7/31/2019 Operator: Hilcorp Alaska LLC Operator Rep: Matt Linder Wellbore Diagram Avail? Photos Taken? ' Fluid in Cellar? ❑ BPV Installed? ❑ VR Plug(s) Installed? ❑ Comments ✓ There was no pressure on the flow line to get a reset on the pilot to open the SSV for the tubing pressure. There is no OA as it is a monobore completion. The location was verified with a Bell Survey As Built pad map. Supervisor Comments Photos (3) attached / Wednesday, August 14, 2019 IP ww MOM �. AL 2019-0801 _Suspend _MPU_C-41_photos_bb.docx 2 Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI(1N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended E 2Wc 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service Q Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or 1/12/2019 Abend.: 14. Permit to Drill Number/ Sundry: 201-078 / 318-432 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 7. Date Spudded: 5/28/2001 15. API Number: 50-029-23014-00-00 - 4a. Location of Well (Governmental Section): Surface: 694' FSL, 2297' FEL, Sec 10, T13N, R10E, UM, AK Top of Productive Interval: 2451' FSL, 95' FWL, Sec 23, T13N, R10E, UM, AK Total Depth: 1486' FSL, 351' FWL, Sec 23, T13N, R10E, UM, AK 8. Date TO Reached: 6/13/2001 16. Well Name and Number: Milne Pt Unit C-41 9. Ref Elevations: KB: 45.17. GL: 16.50 • BF: 17. Field / Pool(s): Milne Pt Unit/ Schrader Bluff 10. Plug Back Depth MDfrVD: •9,825MD/4,152TVD' 18. Property Designation: DL0025518 APL-e47V'3 HnLz�5/G, 7L 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558167.1705 y- 6028976.132 • Zone -4 TPI: x- 560642.6915 y- 6020193.323 Zone -4 Total Depth: x- 560908.1325 y- 6019230.941 Zone -4 11. Total Depth MD/TVD: 12,087MD/ 19. DNR Approval Number: 3, �;5: N/A 12. SSSV Depth MDMID: 10,523MD/ 4,327TVD 20. Thickness of Permafrost MDRVD: 1,800 (Approx.)/ 1,721 (Approx.) 5. Directional or Inclination Survey: Yes L (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) I 21. Re-drill/Lateral Top Window MD/TVD: N /R 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary EC EI VIS® ��, \»\ FEB 21 2p19 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM PULLED 13-3/8/20 94#/ 54.5# H -40/J-55 Surface 110' Surface 110' 30" 260sx Arctic Set (Approx.) 7" 26# L-80 37' 11,197' 37' 4,399' 9-7/8" 1,456sx Arctic Set III, 792sx Class 4-1/2" 12.6 L-80 9,963' 10,419' 4,188' 4,303' 6-1/8" 4-1/2" 12.6 L-80 10,085' 13,668' 4,219' 4,348' 6-1/8" 4-1/2" 12.6 L-80 10,405' 13,810' 4,277' 4,365' 6-1/8" 4-1/2" 1 12.6 L-80 1 13,954' 14,141' I 4,371' 4,379' 6-1/8" 24. Open to production or injection? Yes ❑ No ❑a If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 9,963' 9,854'MD / 4,160 -TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information UNTAND KIND OF MATERIAL USED DEPTH INTERVAL (MD)q8S7bb1s 9,825'to 10,450' of 16ppg, Class'G' Cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (torr): orm 10-407 Revised 5/201, 3—y—� VlmIMMIy tz RBDMS FEB 2 d 201�UbmitD l' 17 lhC 28. CORE DATA Conventional Core(s): Yes ❑ No 0 - Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MDITVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Top Ugnu 8,237' 3,725' Top Ugnu M 9,443' 4,046' Attach separate pages to this form, if needed, and submit detailed test Schrader NA 9,800' 4,146' information, including reports, per 20 AAC 25.071. Schrader NB 9,940' 4,182' Schrader NC 10,050' 4,210' Schrader NE 10,154' 4,237' Schrader NF 10,345' 4,286' Top Schrader 10,500' 4,322' Base OA / TSBC 10,715' 4,359' Top Schrader OB 11,120' 4,395' Base OB / SBA5 —I-? I, µu 11,197' 4,399' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore schematic & operations summary. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman -,TJ Authorized Ttle: Operations Manager Contact Email: twellmafl hilcor .Com Authorized11 Contact Phone: 777-8449 Signatur �Zc ( C l e ate: 2/25/2019 INSTRUCTIONS Generi This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only Tree: 412 ", 5M Wellhead: 11" x41/2 "TCI I T&B. Hnr. wl 4-12" Type'H' BPV profile — 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' 7" X ppf, L -84C, Bva produatian oacfng (drin ID a 6.151", oap.. C.0090 bpi) 4.5' 12.60 L-80 TC- II tubetg ( ID = 3.956, cap =.0152 BPF I KOP Lu 3CC' Max Nvlkee Anglo: 76' 0 03(['•1(,(6( MD Hole angle hough pelts = PC deg. 7'x Wilson BL-7XP Line, top Pin9,962' Hole Punch 10,010 to 10015' 4.5'Baker CMD Siding slows 1004P 4.5' NES XN Nipple ( 3.725' No.Gu 1 10,396 Baker Tie back stem 5.25' -4.375' 10419' Lowe rlNntdow 70505' 10,518') rico anV n5o 83jts of slotted liner (iC,515'- 4.5` 12.6#L -8C 18 Baker Gulde Shoe Q9 Baker Paalea't9ss'lliins Baker Payzone Packer (13,954' -13,977') 3 its 4.5" 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 7.5 bbis (493) cement (13,977' -14,470) MPC -41 KBelev.=30.10' DF elev = 45.1T GL elev. =16.50' 11 Ililcorp11,10skik, LLC SCHEMATIC Revised 1/29/2019 4-12 X Nipplo 13813"ID) 9623' 7 X4-/2 L-80 HES T&T Packer 9854' 4- 172 X Nipple 13813' 10) 98g0. • 4-112' WLEG 9962' _�Slaevo closed duutg 7118105 RWO Upper Window 10,091'-10,103' 12 4.5" 12.6#L -BC IBT tubing 14jts. of solid liner (1C,109 -1C,696') 74 its. of Slotted Liner (1(,695' - 13,623') Baker float shoe ® 13,668' Baker paekolf bushing ®13,623' Baker HR selling sleeve 10,405 Baker HMC liner hander iC 421' EZSV Bridge Plug #2 10523' (Above Abandoned Lateral) Hallibution float collar 11 113' EZSV Bridge Plug #1 11,147` (Above Abandoned Lateral) Halliburton Casing shoe 11 194' Abandoned Open -Hole OB Lateral to 12,205' MD 44/2" SLOTTED INTERVALS OA L2 -10,516 - 13,766 MD 4,324' -4,345 TVD OA L1 -10,695' -13,623' MD 4,345' - 4,348' TVD 4_RL 5 �.' L• I1 1 � 11 7116105 ' Lee Hulme I Isolate L2 & Open L1 Sands 4 -ES 325714 B.Kruskle Doyon 16 RWO from ESP to Injector Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1/12/2019 Daily Operations. 1/2/2019 - Wednesday No activity to report. 1/3/2019 -Thursday No activity to report. 1/4/2019 - Friday No activity to report. 1/5/2019 -Saturday No activity to report. 1/6/2019 -Sunday No activity to report. 1/7/2019 - Monday No activity to report. 1/8/2019 -Tuesday MIRU CTU 6. PJSM. MU BHA #1- 3.10" OD CTC, 3.12" OD DBPV, TJ disconnect (3/4" ball), 3.10" OD XO, 2.375" OD PDS carrier with GR/CCL logging tool enclosed, 2.10" OD XO, 3.65" OD Jet Nozzle. CAL= 17.15'. Head to well and stab on. Function test BOP rams. All move all open. Head to well and stab on. Function test BOP rams. All move all open. RIH with BHA #1 taking returns to tank. Start pumping down coil SLK 1%. 4,500'. Increase pump rate to 2.5 bpm, 6,500'ctm. Continue RIH. Swap to gel 10 bbls at 8,250'2.5 bpm at 2,100psi. set down weight at 8500'. Continue jetting through at 2.5 bpm. Pump second gel pill. Hard spot at 9,277'. Switch to slick water. set down slightly at 9,700'., Continue jetting. Making short 300' trips. Make trip from 9,860' up to 9,330'. Continue RIH with short trips. Sending 10 bbl gel pills. Stop at 10,500' ctm. Increase rate to 3.2 bpm. Pump 150% bottoms up. Slow rate to 1 pam. Log Memory GR/CCL from 10,500' to 9,700'. Stop and flag pipe at 10,250' and 9,849'. Start POH pumping 1 bpm. slick. Switch to MW for freeze protect. Saw sligt over pull at 6,700'. continue POH while FP with M/W. Pipe starting to come back dark. Pack off pressure increased indicating possibly pulling debris up from well on CT. Well is fully freeze protected. Tried pumping mW and cold diesel into bops to clear pipe. Suspect heavy crude set up due to cold freeze protect fluids. Call out Ad Hoc LRS hot oil truck. LRS on location. Safety meeting. PT Treating line 250/2,500psi. Start pumping 135 deg F diesel into the top of the well. RIH with CT to make sure problem area is addressed. Pumped 50 bbls of hot diesel. POH with out problem and clean CT. PCH to surface. SD LRS. RD hot oil unit. Secure well for the night. Install night cap and pressure test 250/2,500psi. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1/12/2019 Daily Operations. 1/9/2019- Wednesday CTU crew on site. Start Breaking down lubricator to check Packoffs Temperature -35 deg F. Change out Packoffs Heavy solid oil in packoffs. Need to heat to get apart.. Make up Lub. MU CTC. Pull test 3,0000#s. MU BHA #2 - 3.10" OD CTC, 3.12" OD DBPV, TJ disconnect (3/4" ball), 3.10" OD XO, 2" Ported Crossover to 3/4" SRT, 4.5" BO Shifting Tool (1.58'), OAK 7.72. Stab on to well. PT Coil and PCE Low/ High 300/3995 Psi. Test check valves. RIH with BHA2. Tie into Top Flag. Log EOP is 9,829.95. Plus 7.72 to correct to flag. Corrected 0 feet correction to upper flag. Wt check 12,600# at 8,737'. Drop below the Baker CMD Sliding Sleeve. Pull back through to close sleeve. Did not see tension increases. Ran through Slicing sleeve at varying speeds multiple times. Verification that Sliding sleeve is closed. POH. On surface. Ball of steel shavings on top of shifting tool. Recover sample. Secure well for the night. 1/10/2019 - Thursday Dry Run to swab with magnets to attempt to clean out bop. Removed a bunch of shavings from bops. Stab back on with same tool string to make short magnet run.. Pressure test back side. Low/ High. 250/1,950 PSI RIH for short trip with mag. Go to 200 ft. POH to check magnets. On surface. Magnet loaded up with small shavings. Not a matt of metal shavings. Clean magnet and make another run. PT low/ hi 250/2,500 psi RIH for another Magnet trip. RIH to 3,500'. POH to check/clean magnet. Back on surface. A lot of shavings on magnet. Some "brillo pad" shavings. MU BHA #4 - 3.10" OD CTC, 3.12" OD DBPV, 3.12" Tl disconnect (3/4" ball), 3.10" OD XO, 3.1" Crossover,2.6" X over, #10 J Hydraulic settint tool 2.63", Adapter Kit 3.5: 4-1/2" CIBP 3.59" OD. CAL 14.47'. Pt on backside low/ hi 250/2,500 psi RIH with CIBP. Wt check 14,000# at 9,500'. Tie in to the flag.(EOP 10230.1 LOG) Make depth 10,243.93 . Depth is corrected to center element of CIBP. Continue down hole. Set CIBP at 10,450. Load ball into CT. Bull head fluid into formation to pump ball around coil. Start pumping M/W to send setting ball. Pumped 37 bbl M/W to seat ball. Pressure up0 CT to 4,500 psi. Bled pressure off back side. Setting tool sheared and set the CIBP at 10.450'. Set down weight to verify plug set. Pressure test plug and sliding Sleeve. MIT pressure test to 2,000 psi for 30 minutes. Good test. POH. Re paint flags. On surface. RD setting tool. PT MHA low / high 450/3,500 psi. PT Firing head. Prep to pert in AM. Secure well for the night. 1/11/2019 - Friday PT PCE on back side. Low/ High 250/ 2,500 PSI. RIH with Tubing punch pert gun. 5' long, 4 spf, HNS Charges. Find fluid at 2325'. Tie into upper flag at 8949.5', Correct to GR/CCL log. Set Gun with top shot at 10010'. Circulate 37 bbls to displace ball to firing head. Shoot gun 110,010 to 10,015' corrected md. Good indication gun fired. Injectivity test. Initial .9 at 1,445 psi. POH pumping FP down back side of CT. On surface. All shots fired. MU BHA 5 Cement retainer. PT PCE on back side. Low/ High 250/ 2,500 psi. RIH with BHA #5 MU BHA #4 - 3.10" OD CTC, 3.12" OD DBPV, 3.12" TJ disconnect (3/4" ball), 3.10" OD XO, 3.1" Crossover,2.6" X over, #101 Hydraulic settint tool 2.63", Adapter Kit 3.5:, 4-1/2" Cast Irom Cement retainer. 3.59" OD. OAL 14.89'. Cought fluid at 600'. Tie into Upper flag at 9,849.5, Correct to GR/CCL log. Place Retainer at 9.930 COE. Pump 40bbls m/w for ball to seat. Pressure up to 4,300 psi. Bleed pressure fro back side. Cl Cement Retainer set. Set down 4000 # to verify set. POH. On surface. RD running equipment. RU baker Stinger. Secure well for the night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1 1/12/2019 Daily Operations. 1/12/2019 -Saturday PT CT and PCE 250/ 3,990 psi. RIH with BHA#6. Halliburton cementers on location. Tie into Flag, Wt check 15,200 at 9,800'. Jet some M/W out stinger to make sure top of Retainer is clean. Sting into cement Retainer. Set down 5k# on retainer. Pressure test back side of CT. Holding good. No communication. safety Operational meeting. PT Hallib treating line low/ High 800/4,500 psi. start to warm up CT with warm slick water before starting Cement. Cement wet at 11:07. FP CTU pump. Start pumping Fresh water pre flush. Start pumping 16 PPG, Glass G cement down the coil. Slow rate to 1.2 bpm at 2800 psi as cement leaves Coil and enters Liner. Complete pumping Cement. Flush with fresh water. Volume 85 bbls of cement. SD at 39 bbis of water displacement down the ct. Unsting from Cement retainer. Start pump back up and lay in 2 bbls of cement on top of retainer. When cement out nizzle pull up to 9,500 for safety. Circulate in slug of GeoVis gel for contamination and lift. RUN back down Dress off top of cement to 9825'. Jet out extra cement to surface chasing with 1%KCI Slick water. FP the well to 2,750'. Secure well. RIG down CTU #6. Pt of cement plug after 15 hours minimum for 1,000 psi compressive strength. 1/13/2019 -Sunday No activity to report. 1/14/2019 - Monday No activity to report. 1/15/2019 -Tuesday No activity to report. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Y113c) / DATE: Monday, January 28, 2019 y'I I P.I. Supervisor f f SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-41 FROM: Bob Noble MILNE PT UNIT C-41 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Jam" NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT C-41 Insp Num: mitRCN190120154737 Rel Insp Num: API Well Number 50-029-23014-00-00 Inspector Name: Bob Noble Permit Number: 201-078-0 Inspection Date: 1/19/2019 Packer Depth Well c-41 Type Inj N TVD 4160 Tubb PTD 2010780 Type Test sPr .Test psi soo IA _._j_ BBL Pumped: z? "BBL Returned: 2.7 OA Interval! OTHER P Notes: Mono -Bore well. Sundry number 318-432. Pressure test L4. St-sx's" P 1 $ Pretest Initial 15 Min 30 Min 45 Min 60 Min 14 314 317 317 3 2224 2172 1 216 Monday, January 28, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p�DATE: Tuesday, January 29, 2019 P.I. Supervisor 1 )` 11 24, �� 9 SUBJECT: Mechanical Integrity Tests 1 HILCORP ALASKA LLC C-41 FROM: Bob Noble MILNE PT UNIT C-41 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv� NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT C-41 API Well Number 50-029-23014-00-00 Inspector Name: Bob Noble Permit Number: 201-078-0 Inspection Date: 1/19/2019 Insp Num: mitRCN190120154244 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C41 - Type Inj I N "TVD 4160 - Tubing 13 2231 1 2207 219 PTD 2010780 " Type Testi SPT Test psi 1500 IA a 8 8 ' BBL Pumped: 1.4 - BBL Returned: 2 ' OA Interval OTHER P/F P Notes: Mono -Bore well. Sundry number 318-432. Pressure test tubing. " P�- Tuesday, January 29, 2019 Page 1 of I THE STATE °fALASKA GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU C-41 Permit to Drill Number: 201-078 Sundry Number: 318-432 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vdwW.a ogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French k� DATED this day of October, 2018. Chair RBDM L�OCT 101010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAc 9s 9Rn CVEIV E D SEP 2 r 1. Type of Request: Abandon❑�// Plug Perforations ❑ Fracture Stimulate 11 Repair Well El Operations shutdoen 11Suspend [YJ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aker Casing ❑ Other. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. — Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service O _ 201-078 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number. Anchorage Alaska 99503 50-029-23014-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MILNE PT UNIT C-41 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025518 MILNE POINT/ SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,08- 4,436 10,523' 4,327' 1,250 10,523 & 11,147 WA Casing Length Size MD TVD Burst Collapse Conductor 79 13-318" 110' 110' WA NIA Production 11,160' 7" 11,194' 4,398' 7,240psi 5,410psi Liner 456 4-1/2" 10,419' 4,303' 8,430psi 7,500psi L2 Liner 3,583 4-11, 113,668' 14,3N/A NIA 60' L1 Liner 3,409 4-1/2" 13,810' 4,345' WA NIA Perforation Depth MD (ft): Perforation Depth TVD (R): Tubing Size: Tubing Grade: Tubing MD (11): See Schematic See Schematic 4-1/2" 12.6#! L-80! TC -II 9,963 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): -' x 4-1/2" HES T&T, 7" x 5" SL-ZXP and N/A 9,854 MD/ 4,160 TVD & 9,962 MD14,187 TVD 12. Attachments: , Proposal Summary r Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/11/2018 OIL ❑ WINJ ❑ WDSPL ❑ u coded 0 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdovrn ❑ Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. // M r" )) ✓'Y./le;12 e, Yi Authorized Name: Be York Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(ahilcorD.Com Contact Phone: 777-8449 �f Authorized Signature: Date: ' Z7 �U commiss1 N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '`.i✓' Plug Integrity [� BOP Test ❑ Mechanical Integrity Test ❑ El/ Location Clearance Other. .)f � (vi50_.c:'t,. Y' i.✓/ r.,.� Post Initial Injection MIT Req'd7 Yes ❑ No ❑ �1 Spacing Exception Required'? ?Yes 13 No Subsequent Form Required: /L) — L/V 7 APPROVED BY Approved by: O � COMMISSIONER THE COMMISSION Date: 1 Q It; 'VV QG I I oSDMS� OCT 1010 /03 : ODI �1^� /� f .'f��% �,o./•/ J a r* 1J f-� itrc S is i Form and Form 10-403 Revised 4Y2017 Approved application is v li f r m h f o date of approval. Attachments in Duplicate H Iiikorp Mask.. LG Reservoir Abandonment Well: MPU C-41 Date:09/19/2018 Well Name: MPU C-41 API Number: 50-029-23014-00 Current Status: Water Injector Pad: MP C -Pad Estimated Start Date: October 7, 2018 Rig: Coil Tubing Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-078 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 1,650 psi @ 4,000' TVDss (SBHPS 10/03/15; 8.0 ppg EMW) Maximum Expected BHP: 1,650 psi @ 4,000' TVDss (SBHPS 10/03/15; 8.0 ppg EMW) MPSP: 1,250 psi (0.1 psi/ft gas gradient) y� Brief Well Summary: MPC -41 was originally drilled as a production well in the OB sands in 2001. The OB sands were isolatedland the II was sidetracked into a multilateral (2 laterals) in the OA sands in 2005. The well produced until zo03 iuhen— he well was converted to multilateral water injection. 'I'lie objective was to support production from the OA from MPE-20. Since this time injection rates were died in and there is support reaching MPE-20. Notes Regarding Wellbore Condition • The well has passed a MIT -IA to 2000psi on 05/15/18 proving tubing, packer and 7" casing integrity. Obiective• 1. To isolate the Ll lateral from the L2 lateral. 2. Abandon the entire L2 horizontal lateral with cement. The planned redevelopment pattern for the E - Pad Schrader reservoir requires this wellbore to be isolated to help prevent potential MBE's. Coil Tubing Procedure: 1. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 2. Pressure test BOPE to 250psi low/ 3,500psi high, 10 min each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 3. RIH w/ 1.75" nozzle and begin FCO of tubing to a target depth of 10,500' md. a. Note that slickline attempted to drift the well but hit a very thick fluid and fell very slowly. Even putting the well on injection only allowed them to reach 4900' before pulling out of hole. b. Attempt to circulate and gain full returns to surface w/ seawater and gel sweeps. c. If unable to gain returns, jet tubing to target depth to clean tubing walls while taking returns to formation. 4. RIH with shifting tool BHA and close the Baker CMD Sliding Sleeve at 10,041' md. 5. MU 3.66" OD nozzle and memory GR/CCL BHA and RIH to 10,500' md. Log up from 10,500'– 9800' and as per memory logging specialist. a. Stop at 10,250' and paint flagon coil tubing. b. Stop and paint 2nd flat at 9850' md. c. Use MPC -41 lower completion tally dated 12/22/2004 for correlation. 6. MU 4-1/2" CIBP and RIH. Correct depth at flag and set CIBP at ±10,450' md. Reservoir Abandonment Well: MPU C-41 Ililcoro Alaska. LD Date: 09/19/20118 7. Conduct an MIT -T to 2000psi for 30 min (charted) to confirm Cl BP seti/ 1 So/,`. L1' 1 8. MU 5' tubing punch BHA and RIH. Punch tubing from ±10,010'- 10,015' md., a. Use previous coil flag for depth correction. b. Confirm injectivity into the L2 lateral. Target rates are >2bpm. 9. MU 4-1/2" cement retainer and RIH. Set retainer at±9,930' md. a. Set down weight onto retainer to confirm set. b. Pump down CTxT annulus to-100psi to confirm that retainer is fully set. pi, -Z 10. Confirm injection rates into the L2 lateral. 11. Begin to mix cement. Once blend is up 15.8ppg, pump±85bbls of cement down the coil tubing at max rate through the retainer. a. Use freshwater spacers as needed around the cement. b. Target is to get at least 73bbls of cement pumped through the retainer. c. Max pump pressure = xxxxpsi. 12. Once target minimum cement volume is pumped through retainer or with 2bbls of cement in the coil (whichever volume is greater) come off the pumps and unsting from the retainer. Allow --bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle. 13. Swap to contaminate and RIH to clean out to 9,830' md. 14. POOH and circulate coil tubing clean as needed. •�y ,? r i a. Freeze protect well on way out of hole. 15. Wait on cement to gain 1000psi compressive strength. A)p j iY� 16. Pressure test c to.Jr.,00�isi for 30 min charted. -a 17. RD CT unit. ;too0 F,sZ 0 Z000 1052 Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO Sundry Change Form Tree: 41P2", 5M Mhead:11" x 41/2 " TCI I T&B. Hnr. w/ 4-112" Type'H' BPV profile - 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' 7" X ppf, L-8(, Beo, productim ouinp (ddn 10.6.161", cap.. CS400 Epl) 4,5" 12.66 L80 TC- II tubing (ID=3.956', cap=.0152 BPF) KOP @ Kit ' Max welbom Angle76• A 48CC-1C,(6C' MD Hole angle trough pads = 9C deg. 14-1/2" Cement Retainer +/- 9,930'l 7' x 5' Baker SL-ZXP Liner top pkr. 9562' (Hole Punch +/-10,010 to +/-10,015 4.5" Baker CMD Sliding sleeve 10,041' 4.5' HES XN Nipple, ( 3.725' No -GO) 10,396 Baker Tie back stem 5.25' -4.375" 1Q419' Lower Window (10,505' -10,518') 4-1/2" r IBP +/- 10,450' 83 As of slotted liner (1C,51IT-13,765') 4.5` 12.6#L -8C IBTtubing Baker Gulde Shoe 0 13,81C Baker Rackoff Rus^,hily ,,e_ ,13, i> F' I Baker Payzone, Packer (13,954' -13,977') 3 jts 4.5" 12.6# L-801BT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 75 bbis (40) cement (13,977 -14,470) KB elev. = 30.10' MPC -41 DF elev. = 45.17 GL elev. =16.50' Nilcorp Alaska. LLC I� 4-12 X Nipple 13.813"ID) 9823' 7X4 -12L-80 HES T&TPacler 9854' 4-12 X Npple t3.813' ID) 9890' 4-12-WLEO 99;T ,�Sieeee dosed during 7/18105 RM Upper Window 10,091'-10,103' 14 As. of solid liner (1 C,1 C9 -1C,696') 74 As. of Slotted Liner (1C,695' -13,623') Baker float shoe 0 13,668' Baker padwff bushing ID 13,623' Baker HR setting sleeve 10,405' Baker HMC liner hanger 10,421' EZSV Bridge Plug 92 10,523' (Above Abandoned Lateral) Halliburton float collar F11.1113' EZSV Bridge Plug #1 11,147' (Above Abandoned Lateral) - Halliburton Casing shoe 11,194' Abandoned Open -Hale OB Lateral to 12,205' MD ' 4-1/2" SLOTTED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD OA Lt -10,695' -13,623' MD 4,345' - 4,348' TVD DAIL KLV.by WIVIVILNIJ MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 7/13/01 7/24/01 MDO B.Hasebe Drilled & Cased Nabon122 e ESP Completion Nabom 4ES 2//2/4 /20 Mooower Isolate lwerz & ESP 4 -ES 7/18/05 Lee Hulme Isolate L2 & Open Ll Sands 4 -ES 325/14 B.Kruskie Doyon 16 RWO from ESP to Injector Tree: 41/2", 5M MPC -41 KBelev. =30.10' Nkllhead:11" x4 1/2 "TCII T&B. Hnr. w/ DF elev. = 45.17 4-1/2" Type'H' BPV profile GL elev. = 16.50' 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' Hileorp Alaska, IAA: 7" n ppf, 49(, Btr& production oatin, ( drill ID. 6.161", gap, - C.CD96 6pl) 4.5 12.66 L-80 TC -11 taking ( ID= 3.956', cap = .0152 BPF ) r.OP 0 ?CC Max "Iftore Angle 76'® 88(C-1C,CI5V MD Hole snple trough pelt = PC deg. 7'x 5' Baku SL-ZXP Liner top pkr. 9,962' 4.5 Baku CMD Sidiq sleeve 10,041' 4.5" HES XN Nipple ( 3.725' No -Go) 10,398' Baker Tie back stem 5.25' -4.375" 10,419' Lower Window (10.505 -10,518') L1 83 jts of slotted liner (1C,615'-13,765') 4.5" 12.E#L-8C IBTtubino Baker Gulde Shoe ® 13,81C Baker Paekaef 86s^,hiv ' d?, rTEF' Baker Payzone Packer (13,954'- 13,977') 3 jts 4.5" 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 75 bbis (493) cement (13,977'- 14,470) A" 4-112 X Nipple 13.813" IDI 9823' 7X4-V2L-89 HES T&TPacker g854' 4-V2 X Nipple 13.813'ID) 9890' 4-M'WLEG 9982 Sleeve dosed during 7/18/0.5 RM Upper Window 10,091'-10,103' • L2 4.5" 12.6#L -8C IBTtubina 14 jts. of solid liner (1 C,1 C9' -1 7400. o1 gotted Liner (%,695' - 13,573') Baker float shoe ® 13,668' Baker padmfl bushing ® 13,623' Baker HR setting sleeve 10,405' Baker HMC Ilner hanger 1C,421' EZSV Bridge Klug 92 10,523' (Above Abandoned Lateral) Halliburton float collar 11,113' EZSV Bridge Plug #1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Abandoned Open -Hole OB Lateral to 12,205' MD 41/2' SLOTTED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD 0.4 L1 -10,695' -13,623' MD 4,345' - 4,348' TVD DATE REV. BY COMMENTS MILNE POINT UNIT 7/13/01 7/24/01 MDo B.Hasebe pitied & Cased Nabors 22 e ESPCompletbo Nabas4ES WELL C-41 PI NO: 50-029-23014-00M A 8z/izoa ooow r Isolate lwerz e&ESP4-ES 7/18/05 Lee Hulme Isolate L2 & Open L1 Sands 4 -ES 3/25/14 B.Kruska Doyon 16 RWO from ESP to Injector COIL BOPE MILNE POINT UNIT MPU C-41 Hilrnrp Alaska LLC 09/26/2018 Coil Tubing BOP Lubricator to injection head 1.50' Single Stripper Blind/Shear--Ip 1/16 z Pipe .ISI :1_ Pipe Crossover spool 4 1/16 10M X 4 1/16 5M M. � m ME I I 1-M., I I 15:A dyn IUI 1 Manual Gate Manual Gate Crossover spool If. 2 1/8 5M 2 1/8 SM HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: September 26, 2018 Subject: Changes to Approved Sundry Procedure for Well MP C-41 Sundry #: xxx-xxx Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date HAK Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, October 02, 2018 3:24 PM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: MPU C-41 (PTD #201-078) Suspension Sundry Application Mr. Schwartz, We would like to conduct the reservoir abandonment of the L1 and L2 laterals of MPU C-41 and then leave the main bore suspended. At this time, we do not have a sidetrack location selected for the mainbore but would like to main this as a possibility into the future. If after an evaluation there is no further utility identified, we will submit a sundry application for P&A. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Acting Ops Manager for Bo York: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellmanPhilcorp.com 93 I'm reviewing this Sundry Application from Hilcorp for "reservoir abandonment" in MPU C-41, and I have a question. Well / Well Current Expected Status after Operations Proposed in Sundry 318-432 Branch Status MPU C-411_1 1WINJ Plugged and abandoned: permanently isolated by CIPB at about 10,450' MD. C 6~t 0n lti MPU C-411_2 1WIN1 Plugged and abandoned: permanently isolated by cement. MPU C-41 SCIZED Suspended: OB sand isolated by two EZSV Bridge Plugs; Ll isolated by CIBP; L2 isolated by cement; cement in tubing to about 9850' MD. Wouldn't the well records be clearer if Hilcorp submitted three Sundry Applications instead? 1. MPU C-411_1— Plug and abandon (permanent isolation by CIBP), 2. MPU C-411_2 — Plug and abandon (permanent isolation by cement), 3. MPU C-41—Suspend (permanent isolation of open -hole section by bridge plugs, isolation from L1 by CIBP, and cement isolation from 1_2). The schematic drawings and proposed Coiled Tubing Procedure would be the same in each application. Thanks, Steve D. L wY 140/�' y'/E✓N <pMgA? V ��' 3 e5 L 2 —glsa lVed juf7j{,'C417 4 fW 1,000 000 G HILCORP ALASKA LLC, MILNE PT UNIT C-41 (201-078) MILNE POINT, SCHRADER BLFF OIL Monthly Production Rates � e Produced 6zs (MCPM) i ', q Produced 0" (BOPM) I Cum. Prod Oil (bbls): 542,987 00,000 _— — ° Produced Water (BOPM) Cum. Prod Water (bbls): 160,053 - _ - = Cum. Prod Gas (mcf): 351,921 09P- 10,000 n 0 -.—. -_ - - - * e Injectetl bas (MGFMI -- Injec[etl Writer (BOPM) e i 1,000 I 100 10 1,000,000 100,000 W d N 10,000 u+ (D 1,000 O 3 100 T 30 Jan -2000 Jan -2002 Jan -2004 Jan -2006 Jan -2008 Jan -2010 Jan -2012 Jan -2014 Jan -2016 Jan -2018 Jan -2020 Monthly Injection Rates 1,000,000 100,000 L Y 0 10,000 v O' 1,000 LL V L 100 100,000 W v N 10,000 n 0 v 1,000 � 10 30 Jan -2000 Jan -2002 Jan -2004 Jan -2006 Jan -2008 Jan -2010 Jan -2012 Jan -2014 Jan -2016 Jan -2018 Jan -2020 SPREADSHEET_Prod-Inject_Cuwes_Well_V ll6_2010780_M PU_C-41_20183001.xlsx 10/1/2018 -- - - ===7t_ -�— Cum. Ini Liquid (bblsl: 668.353 _— _ Cum. Inj Gas (mcfj: 0 -_ - - e Injectetl bas (MGFMI -- Injec[etl Writer (BOPM) 100,000 W v N 10,000 n 0 v 1,000 � 10 30 Jan -2000 Jan -2002 Jan -2004 Jan -2006 Jan -2008 Jan -2010 Jan -2012 Jan -2014 Jan -2016 Jan -2018 Jan -2020 SPREADSHEET_Prod-Inject_Cuwes_Well_V ll6_2010780_M PU_C-41_20183001.xlsx 10/1/2018 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday,May 18,2018 TO: Jim Regg 5(231.1 P.I.Supervisor (t SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-41 FROM: Bob Noble MILNE PT UNIT C-41 Petroleum Inspector Src: Inspector Reviewed By:,.-�7 P.I.Supry J' NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT C-41 API Well Number 50-029-23014-00-00 Inspector Name: Bob Noble Permit Number: 201-078-0 Inspection Date: 5/14/2018 Insp Num: mitRCN180514154355 Rel Insp Num: J Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Packer Well r C-41 Type In' w TVD ' 4160 - !Tubing 1378 -1 1379 - 1378 - 1 1378 PTD 1_ 2010780 Type Test SPT [Test psi 1500 - IA 649 2114 . I 2058 ` 2048 - I ` ',BBL Returned: ! I " OA BBL Pumped: 1 J — P/F L P Interval OTHER Notes: 2 Year test cycle-monobore. SCANNED JUN 0 12018 Friday,May 18,2018 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,May 31,2016 P.I.Supervisor I l l ' SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-41 FROM: Bob Noble MILNE PT UNIT SB C-41 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvi�?- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB C-41 API Well Number 50-029-23014-00-00 Inspector Name: Bob Noble Permit Number: 201-078-0 Inspection Date: 5/30/2016 Insp Num: mitRCN160530160756 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' C-41 ' Type Inj W'TVD 4160 - Tubing 1250 - 1255- 1254• 1254 --- ----- ---- -- -- PTD 2010780 Test SPT Test psi 1500 IA 309 1914 - 1867 - 1861 Interval OTHER P/F P OA Notes: 2 Year test cycle do to the well being a monobore. CANE t„; Tuesday,May 31,2016 Page I of 1 Imagel" :oject Well History' File Cover Fi je 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. ~_ 0-[ - 07~ Well History File Identifier RESCAN DI(~ITAL DATA OVERSIZED (Scannable) / [] Color items: ,V~ Diskettes, No. (,~ [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL~INDY 1? = TOTALPAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ..]..~.~. PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' X YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: , YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) I! NO NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is/ Quality Checked 12/10/02Rev3NOTScanned.wpd 4. RECEIVED STATE OF ALASKA FEB 2 0 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Convert to Injector 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. - Exploratory ❑ Development Q 201-078-0 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-231 4-00-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? SBL M' -41 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518 • MILN, POINT,SCH- • 'A ER BLFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): 1 Plugs(meas -.): Junk(measured): 12087 . 4436 . 10523 . 4327• Attachment None Casing Length Size MD if Burst Collapse Structural Conductor 79 13-3/8"72#L-80 31 -110 1- 0 Surface None None None '. e None None Intermediate None None None None None None Production 11160 7"26#L-80 37-11197 37-4398.54 7240 5410 Liner 456 4-1/2"12.6#L-80 9963-10419 / 4187.63-4303.32 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: - Tubing Grade: Tubing MD(tt): 11197-12210 4398.54-4437.93 2-7/8"6.5#L-80 L-80 21-9859 Packers and SSSV Type: 5"Baker ZXP Top Packer • •:c • and SSSV MD(ft)and ND(ft): . 9963,4187.63 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 3.Well Class after proposed work: Detailed Operations Program 2. BOP Sketch ❑ • Exploratory ❑ Development ❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑r GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the b- t of my knowledge. Contact Jessie Chmielowski I Email Jessie.Chmielowski@BP.Com Printed Name Jessie Chmielows Title Production Engineer Signaturer one 564-5015 Date / / f Prepared by Garry Catron 564-4424 jell/k. ° ./ COMMISSION USE ONLY Conditions of approval: Notify Commission .that a representative may witness Sundry Number: \Lk^ Q `t I Plug Integrity ❑ BOP T-.t ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCANNED AUG 0 6 2014 RBDMS MAY 10 2014 Spacing Exception Req •ed? Yes ❑ No W Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0 �G� � 714,month ' Form 10-40 Revised 10/2012 r I slid for 12 months from the date of approval. Submit Form and Attachments in Duplicate /$19 Milne Point C-41 (PTD 201-079 & 201-122) Current Status The Milne Point well C-41 was drilled and completed as a Schrader Bluff formation producer in January 2001. The well has been shut in due to a failed ESP. MPC-41 was last online in 2009, and the well tested at 120 bopd, 20% WC and 1140 scf/stbo GOR. MPC-41 has no known casing problems. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert well MPC-41 to an OA sand injector in the Schrader Bluff pool. The conversion will increase injection capacity in the hydraulic unit, establish new streamlines betty n wells and better su p rt producer M E-20A. p p � yr c�( cf+�// / pQ W 4 S caw/'. �o v�noA � R � il`% /CO !1�.'�'' / Completion 301.9p. Mfg ,ost 4 c ;err Proarvre►- Ave- does 40r 44 'C4 tn4ICte04 rife ro"-• (auvlYf/AO 14,Y £•e// 70 9.1 j eclat• .5404,/, Well MPC-41 (Permit# 201-078) was completed in July 2001 with two laterals ,.O'0.0-1 /4o. MPC-41L1 (Permit# 201-079) and MPC-41L2 (Permit# 201-122) as a Schrader lova 41 Bluff producer. Both laterals are completed in the Schrader Bluff OA sand. A 13- ffrnal of Tie 3/8" casing was run to 110' and cemented with 260 sacks of Arctic set cement. A pv, 7" production casing was run to 11,197' MD and cemented in place with 1456 ,0c71 sacks of 10.7 ppg Arctic Set II cement followed by 792 sacks of 15.7 ppg Class G cement. During the cement job full returns were observed at the surface, approximately 500 bbls of cement. Following the cement job the casing was tested to 3500 psi for 30 minutes. Although no cement bond log was run after the cementing operation, we are confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well is completed with slotted liner in the Schrader Bluff OA sand. Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Perform rig workover to remove ESP and complete well for injection service 3) Complete water injection header tie-in 4) Place well on water injection (confirm AOGCC approval prior to injection) 5) AOGCC witnessed MITIA once injection has stabilized Area of Review — Milne Point C-41 (PTD 201-079 & 201-122) This Area of Review is required prior to the conversion of well MPC-41 from a producer to a water injector. This AOR discusses wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of MPC-41 well bore completion. Four other wellbores, MPA-01, MPA-03, MPE-20AL1 and MPG-03A, enter the Schrader Bluff formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPC-41, completion details, and annulus integrity/cement conditions based on in-depth review of each well. Distance Well Name PTD (feet) Annulus Inte•rit MPC-41 201-079 0 TOC estimated at surface MPA-01 179-040 420 TOC at surface; well is P&A'd MPA-03 183-001 250 TOC at surface; well is P&A'd MPE-20A 204-054 580 TOC unknown MPG-03A 204-219 1210 TOC unknown Table 1: Table showing distance&annulus integrity of wells within AOR Hole Vol. of Well Name Casing Size Cement Schrader depth (MD) Schrader depth(TVDss) MPC-41 7" 8-1/2" 500 bbls 9816' -4105 MPA-01 9-5/8" 12-1/4" 400 bbls 4210' -4168 MPA-03 9-5/8" 12-1/4" 246 bbls 4504' -4168 MPE-20A 7-5/8" 9-7/8" 107 bbls 5320' -4236 MPG-03A 7" 8-1/2" 68 bbls 5871' -4080 Table 2: Completion Detail Well MPA-01 (Permit # 179-040) was completed in 1980. MPA-01 was drilled as an exploration well and the wellbore crossed the Prince Creek, Kuparuk, Sag and Sadlerochit formations. A 13-3/8" surface casing was run to 2766' MD and cemented to surface with 614 bbls of Howco Permafrost cement. A 9-5/8" production casing was run to 9719' MD and cemented in place with 328 bbls of Class G cement and 72 bbls of Permafrost 'C' cement. The well was plugged and abandoned in April 2008. Well MPA-03 (Permit # 183-001) was completed in 1983. MPA-03 was drilled as an exploration well and the wellbore crossed the Schrader Bluff formation in the N and 0 sands. A 13-3/8" casing was run to 2500' MD and cemented to surface with 410 bbls of Arco Fondu cement and 102 bbls of Permafrost 'C' cement. A 9- 5/8" production casing was run to 5095' MD and cemented in place with 195 bbls of Class G cement, 51 bbls of Permafrost 'C' cement and 130 bbls of Arctic Pac. The well was plugged and abandoned in December 2005. Well MPE-20A (Permit # 204-054), including lateral MPE-20AL1 (Permit # 204- 055), was completed in 2004. Producer MPE-20A's main wellbore is completed in the Schrader Bluff OA sand, and the MPE-20AL1 lateral is completed in the Schrader Bluff N sand. The well was sidetracked in May 2004 after abandoning the parent well MPE-20 (Permit # 195-071) with a EZSV set in the 9-5/8" casing at 4220' MD and pumping 30 bbls of Class "G" cement under while leaving 5 bbls of Class "G" cement on top of the EZSV. An EZ-BP (CIBP) was set in the 9-5/8" casing at 2700' MD, and the casing and plug were pressure tested to 1500 psi for 30 minutes. The 9-5/8" casing was cut at 2520' MD and pulled out of the well. 27 bbls of Arctic Set 1 cement was placed on top of the EZ-BP between 2700' MD and 2510' MD. A CIBP was set in the 13-3/8" casing at 2489' MD and pressure tested at 1500 psi for 30 minutes. In May 2004, after the parent wellbore was isolated, a window in the 13-3/8" casing was milled at 2457' MD and 7-5/8" casing was run and set to 5989' MD and cemented with 107 bbls of Class `G' cement. The 7-5/8" casing was pressure tested to 3500 psi for 30 minutes. During construction of the parent well, MPE-20 (Permit # 195-071), 13-3/8" surface casing was run to 2587' and cemented with 161 bbls of Permafrost `E' cement, 51 bbls of Class G cement and 31 bbls of Permafrost `E' cement. 9-5/8" casing was run to 4681' MD and cemented with 77 bbls of Class `G' cement. Well MPG-03A (Permit # 204-219) was completed in 2004. The well is completed as an injector in the Schrader Bluff N, OA, and OB sands. The well was sidetracked in September 2004 after abandoning the parent well MPG-03 (Permit # 189-046) with a EZSV set in the 7" casing at 4899' MD and pumping 38 bbls of Class `G' cement under while leaving 10 bbls of Class `G' cement on top of the EZSV. The rig performed a pressure test to 1500 psi for 30 minutes. A second EZSV was set in the 7" casing at 3201' DPM and pressure tested to 1500 psi while monitoring the OA (no indication of flow or communication was noted) prior to cutting the 7" casing at 1987'. A second EZSV cement retainer was set in the 7" casing at 1985' MD and 53 bbls of Arctic Set 1 cement was pumped below. In November 2004, after the parent wellbore was isolated, a window in the 9-5/8" casing was milled at 1981' MD and 7" casing was run and set to 6536' MD and cemented with 68 bbls of Class `G' cement. The 7" casing was pressure tested to 3000 psi for 30 minutes. During construction of the parent well, MPG- 03 (Permit # 189-046), 13-3/8" surface casing was run to 110' and cemented to surface using Arctic Set cement, 9-5/8" casing was run to 2931' MD and cemented with 181 bbls of Type `E' cement and 138 bbls of Class `G' cement. c N MPE-03 t i l MPB-23 M- 1PB1 MPB-25 MPE- 3APB2 MPB-04A MPC-41L2 WE-13 NPE-33 1\A&-- ..-47—;----3 MPA-01 • -1 NPB-09 - -A-02A MP •1 NPE-18 MPC-41P: • III MPE-20AL1 APE-19 4 -20A \', :1 l MPG07 // 1412C-411.1 MPG-03 ' -.I • MPG-19 woo / o 1000 2000 3000 i „..,..--- 14/PG11 , 111=1;411:1111:1111=1111111111111.1111111-- Legend Wellbore with bottom hole symbol Intersection of wellbore with Schrader Bluff Formation Q.... 0 % mile distance from wellbore (NA intercept to TD) Figure 1: Map showing wells within 0.25 mi radius from MPC-41. Tree: 2 9/16", 5M MP C-41 KB elev. =30.10' Wellhead: FMC 11"x 11", 5M, Gen. 5 DF elev. =45.17' ' and 11"x 2 7/8" FMC Tbg. Hnr. w/ - GL elev. = 16.50' 8 rd EUE threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 Casing 115' Camco 2-7/8"x 1" 136' sidepocket KBMM GLM Tam port collar @ 1045' 0 7"26 ppf,L-80,Btrc.production casing drift ID=6.151",cap. Camco 2-7/8"x 1" ( =0.0383 bpf) sidepocket KBMM GLM 9,739 4.5"12.64 L-80 IBT-M tubing 9,849' (ID=3.958",cap=.0152 BPF) 4 Hes XN-Nipple(2.205"id) Tandem Pump,Upper 214 Stg. 9,871' 2 7/8"6.5 ppf,L-80 8 rd EUE tubing FC925 FPMTAR 1:1,Lower (drift ID=2.347",cap=0.00592 bpf) 16 Stg.GCNSPH,GPBMTAR 1:1 Tandem Gas Separator 9,897' SE5798GA Tandem Seal Section 9,902' KOP @ 300' - gsb3dbabhsnpfsa/gsb3dbltabhsnfsa Motor,95 HP, 1330 volt, 9,915' . Max wellbore Angle:75°@ 3300'-10,050'MD '-5 44 amp,Model KMH g 925` Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 7"x5"Baker SLZXP Liner top pkr. 9,962' gm an Sleeve closed during RWO .101Upper Window 10,091'- 10,103' 4.5"Baker CMD Sliding sleeve 10,041' ••• L2: 4.5"HES XXN Nipple(3.725"No-Go) 10,398' ::C:::.::::•::: }::;;};};,.;};;;;;;;:.:•:.X:., ,,, I ' 45"12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' 14 jts. of solid liner(10,109'- 10,696') - 74 jts. of Slotted Liner(10,695'- 13,623') Lower Window(10,505'- 10,518') [ = Baker float shoe @ 13,668' �., Baker packoff bushing @ 13,623' L11 I •••••••••..••••...•................•••,• Baker HMC liner hanger��.�' �� / Baker HR setting sleeve 10,405' 9 10,421' A 83jts of slotted liner 10,515`-13,765' ( ) EZSV Bridge Plug#2 10,523' 4.5"12.6# L-80 IBT tubing (Above Abandoned Lateral) Baker Guide Shoe @ 13,810' Halliburton float collar 11,113' Baker Packoff Bushing @ 13,765' _ _ EZSV Bridge Plug#1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer(13,954'- 13,977') 3 jts 4.5"12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open-Hole OB Lateral to 12,205' MD 4.5"Halliburton Float Shoe 14,141' 7.5 bbls (493') cement(13,977'- 14,470) 4-1/2"SLOTTED INTERVALS OA L2- 10,515'- 13,765'MD 4,324'-4,345'TVD OA L1 - 10,695'- 13,623' MD 4,345`-4,348'TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled & Cased Nabors 22 e MILNE POINT UNIT 7/24/01 B. Hasebe ESP Completion Nabors 4ES WELL C-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone& ESP 4-ES BP EXPLORATION (AK) 12/12/05 MDO FCO L-01 liner&ESP Completion A • Ferguson, Victoria L (DOA) From: Chmielowski,Jessie <Jessie.Carr@bp.com> Sent: Tuesday, March 04, 2014 2:17 PM To: Ferguson, Victoria L(DOA) Cc: Lastufka,Joseph N Subject: RE: SBL MPC-41(PTD 201-078, Sundry 314-096), SBL MPC-41L1(PTD 201-079, Sundry 314-097), SBL MPC-41L2(PTD 201-122, Sundry 314-098) Please withdraw the 3 Sundries for well MPC-41 that were created by Garry Catron and signed by me,Jessie Chmielowski. These are to be replaced by 2 Sundries for well MPC-41 that were submitted by Joe Lastufka and signed by David Bjork. Thanks,Jessie From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent: Tuesday, March 04, 2014 2:01 PM To: Chmielowski, Jessie Cc: Lastufka, Joseph N Subject: SBL MPC-41(PTD 201-078, Sundry 314-096), SBL MPC-41L1(PTD 201-079, Sundry 314-097), SBL MPC- 41L2(PTD 201-122, Sundry 314-098) Please respond to this email with a request to withdraw the subject Sundries. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonalaska.gov 1 • STATE OF ALASKA .i 1\ j 1 7 ?',1,°,4 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Injectivity Test Q' 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc.- Exploratory El Development Q 201-078-0 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23014-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? SBL PC-41 /La-/-L2 °46 Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518 • MILNE POINT, •Q1113%, R BLFF OIL 11. PRESENT WELL CONDITION SUMMARY \ .J Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(meas -.): Junk(measured): 12087 • 4436 10523 , 4327 Attachmen None Casing Length Size MD . Burst Collapse Structural ' Conductor 79 13-3/8"72#L-80 31-110 • 10 Surface None None None `\ .ne /J None None / Intermediate None None None None / None None Production 11160 7"26#L-80 37-11197 7-4398. . 7240 5410 Liner See Attachment See Attachment See Attachment .-A r.. m- t See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: V ubi _`t = Tubing MD(R): See Attachment / See Attachment 2-7/8"6.5# -:• ,-� L-80 21-9859 Packers and SSSV Type: See Attachment for Packer Types q -rs and S D(ft) d TVD(It): See Attachment for Packer Depths No SSSV Installed No SSSV Installed- 12.Attachments: Description Summary of Proposal E, 111# 13.4 ell Cla . .fter proposed work: Detailed Operations Program ❑ BOP Sketch ❑ xp• at.t 0 Development ❑d • Service ❑ 14.Estimated Date for 1 _ 'tatus after proposed work: Commencing Operations: y •/ Ei • Gas EI WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: / J ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: / GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the be of my knowledge. Contact Alecia Wood Email Alecia.Wood©BP.Com Printed Name Alecia Wood Title Production Engineer Signature Ph. e 564-5492 Date Prepared by Garry Catron 564-4424 0�1 f/CUC 1 Ji-T/iH COMMISSION USE ONLY• [� Conditions of approval: Notify Commission so th- a representative may witness Sundry Number 71-1 O 1 Plug Integrity ❑ BOP Test /A Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCANNED MAY 1 6 2014 RBDMS MAY 0 9 2014 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 10/2012 QPRvfc6ofcti4aIfor 12 months from the date of approval. Submit Form and Attachments in Duplicate Perforation Attachment ADL0025518 Well Date MD Plug Type TVD MPC-41 12/23/2001 10523 EZSV Bridge Plug 4327 MPC-41 6/24/2001 11147 EZSV Bridge Plug 4396 a o 0 0 0 0 0 m co 00 0o OD 00 00 c) J J J J J J N O 0.• 0 O O O O CO mi 10 O Nr `- O O (o co Nr � co to O N N- U) N- N 0 o 0 0 C 0 0 L M M 0 M M 7 O) N O m oo I� co 0 N to N co O) — to O m O O O) CONrCO 'i Q M CO CO CO C1 0• 00 N- O CO MM N NI- NV' 03 00 CLU N O) 1- O)7.4 _O 00 lo CO UJ O OD mO0O0oco Q T- O T O Cl) Cl) p 2 C J Q HrLO LO Cl) N 0 0 U Q M CO M N O v.- c, O O O O O 00 00 0 00 00 J C) J J J N 4t CSO J Lo CD CD Cl) CO 0 N- M CV E N L O co to co CT O) 0 0 co O co O N O0) M M T- Z 0 O IAD QOW W U Q o Q Z Z Z Z W O m J O ZCe : '- N 0 J a F- J J Perforation Attachment ADL0025518 Well Date _ Perf Code MD Top MD Base _ TVD Top _ TVD Base MPC-41 7/24/01 BPS 11197 12210 4399 4438 MPC-41L1 7/13/01 SL 10515 13765 4325 4345 MPC-41L1 7/13/01 OH 13765 13954 4345 4343 MPC-41L2 7/13/01 SL 10695 13623 4329 4358 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0025518 Well _ Facility Type MD Top Description TVD Top MPC-41 PACKER 9963 5" Baker ZXP Top Packer 4188 MPC-41L1 PACKER 10405 7" Baker ZXP Top Packer 4300 Tree: 2 9/16", 5M MP C-41 . KB elev. =30.10' Wellhead: FMC 11"x 11",5M, Gen. 5 DF elev. =45.17' and 11"x 2 7/8" FMC Tbg. Hnr.w/ GL elev. =16.50' 8 rd EUE threads top and bottom and 2.5"CIW'H'BPV profile 13 3/8"72 ppf, L-80 Casing 115' Camco 2-7/8"x 1" 136' sidepocket KBMM GLM Tam port collar @ 1045' 0 7"26 ppf,L-80,Btrc.production casing Camco 2-7/8"x 1" (drift ID=6.151",cap.=0.0383 bpf) , sidepocket KBMM GLM 9,739 4.5"12.6#L-80 IBT-M tubing 9 849' (ID=3.958",cap=.0152 BPF) Hes XN-Nipple(2.205"id) 2 7/8"6.5f,L-80 8 rd EUE tubingTandem Pump,Upper 214 Stg. 9,$71' PP FC925 FPMTAR 1:1,Lower (drift ID=2.347",cap=0.00592 bpf) i 16 Stg.GCNSPH,GPBMTAR 1:1 Tandem Gas Separator 9,897' SE5798GA Tandem Seal Section 9,902' KOP @ 300' gsb3dbabhsnpfsa/gsb3dbltabhsnfsa Motor,95 HP, 1330 volt, 9,915' Max wellbore Angle:75°@ 3300'-10,050'MD - - 44 amp,Model KMH Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 9,925 7"x5"Baker SLZXP Liner top pkr. 9,962` Ili 111111Sleeve closed during RWO 4.5"Baker CMD Sliding sleeve 10,041' Upper Window 10 091 10 103' •• L2 4.5"HES XXN Nipple(3.725"No-Go) 10,398' ::ti:ti its 4.5"12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' 14 jts. of solid liner(10,109'- 10,696') 74 jts. of Slotted Liner(10,695'- 13,623') Lower Window(10,505'- 10,518') Baker float shoe @ 13,668' Baker packoff bushing @ 13,623' Baker HR setting sleeve 10,405' . .rBaker HMC liner hanger 10,421' A 83 jts of slotted liner ( 10,515`-13,765') EZSV Bridge Plug#2 10,523' 4.5"12.6#L-80 IBT tubing (Above Abandoned Lateral) Baker Guide Shoe @ 13,810' Halliburton float collar 11,113' Baker Packoff Bushing @ 13,765' EZSV Bridge Plug#1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer(13,954'- 13,977') 3 jts 4.5"12.6#L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open-Hole OB Lateral to 12,205'MD 4.5"Halliburton Float Shoe 14,141' 7.5 bbls(493')cement(13,977'- 14,470) 4-1/2"SLOTTED INTERVALS OA L2- 10,515'- 13,765'MD 4,324'-4,345'TVD OA L1 - 10,695'- 13,623'MD 4,345'-4,348'TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled &Cased Nabors 22 e MILNE POINT UNIT 7/24/01 B. Hasebe ESP Completion Nabors 4ES WELL C-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone&ESP 4-ES BP EXPLORATION (AK) 12/12/05 MDO FCO L-01 liner&ESP Completion by 0 Date: January 16, 2014 From: Jessie Chmielowski MPU Schrader Pad Engineer 907-564-5015 Subject: MPC-41 Injection Test MPC-41 is a candidate to convert from producer to injector. Before converting the well to injection, an injection test will be performed to ensure that the well does not have a Matrix Bypass Event (MBE) to offset producer MPE-20A. The plan for the injection test is to pump 500 barrels per day of produced water into MPC-41 for three days while monitoring offset well MPE-20A for any changes in watercut. Ferguson, Victoria L (DOA) From: Stone, Christopher <Christopher.Stone@bp.com> Sent: Friday, January 31, 2014 4:23 PM To: Ferguson, Victoria L(DOA) Subject: RE: MPC-41 (PTD 201-078, Sundry 313-048) Victoria, As per our phone conversation, please withdraw Sundry 313-048, PTD 201-078,SBL MPC-41/L1/L2. Thanks, Chris Stone BP Exploration(Alaska) Inc. Lead Petroleum Engineer-Milne Point Office:907.564.5518 From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday, January 31, 2014 3:42 PM To: Stone, Christopher Subject: RE: MPC-41 (PTD 201-078, Sundry 313-048) Chris, Please respond to this email withdrawing Sundry 313-048, PTD 201-078, SBL MPC-41/L1/L2. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonRalaska.gov From: Stone, Christopher [mailto:Christopher.Stone@bp.com] Sent: Friday, January 31, 2014 3:12 PM To: Ferguson, Victoria L(DOA) Cc: Jessie.Carr©bp.com Subject: MPC-41 Sundry Application Questions Victoria, I have pulled the well files for MPC-41 in hopes of addressing the questions that you had regarding MPC-41's 7" production casing integrity. A summary of the initial production casing cementing job from 2001 as well as 1 some highlights from the 2005 RWO highlight the integrity of the casing and provide verification that the upper L2 lateral is isolated. MPC-41 History Well MPC-41 was (Permit#201078) was completed in July 2001 with two laterals MPC-41L1 (Permit# 201079) and MPC-41L2 (Permit#201122) as a Schrader Bluff producer. A 13-3/8" casing was run to 110' and cemented with 260 sacks of Arctic set cement. A 7" production casing was run to 11,197' MD and cemented in place with 1456 sacks of 10.7 ppg Arctic Set Il cement followed by 792 sacks of 15.7 ppg Class G cement. During the cement job full returns were observed at the surface, approximately 500 bbls of cement. Following the cement job the casing was tested to 3500 psi for 30 minutes. The well is currently open to the MPC-41L1 lateral (Permit#201079). During the 2005 RWO the workover rig closed the sliding sleeve to isolate the upper L2 lateral from production. A plug was set in the 4-1/2" XXN Nipple at 10,398' and a successful pressure test was conducted to 2000 psi verifying the sleeve was closed and holding. Please feel free to contact me or Jessie Chmielowski with any other questions that you may have regarding this well. Thanks, Chris Stone BP Exploration(Alaska)Inc. Lead Petroleum Engineer-Milne Point Office:907.564.5518 2 • •,;..em u ,kx✓ Ati.:v r 1. .n : ., : .:i:: .rh. .. G. i w .r. a.. ( W • - - .: :r 1'X'?`.c,, • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ao l - M G - 4.1 Mr. Tom Maunder 0' Alaska Oil and Gas Conservation Commission '4. s iO 333 West 7 Avenue Anchorage, Alaska 99501 �4'.• • Subject: Corrosion Inhibitor Treatments of MPC -Pad y � Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -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 t W fl FEB 2 2 LtflL BPXA, Well Integrity Coordinator 0 0 I BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC-05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC -10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 -- P P ' MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC -43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 e e c~, ~:,,~" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfihn _ Marker. doc [Fwd: 4ES gas bubble] e e Subject: [Fwd: 4ES gas bubble] From: Jeff Jones <jeffjones@admin;state.ak.us> Date: Fri, 09 Dee 2005 11 :Oð:09 -0900 t~l?~es Regg<jim _regg@ådÌnin.statè~åk.us>'t '-' r.'7 '\ ~., I\Û ':> . ~í?I( (1 \ -Z I(; . ·:..·.F-;.;,:·:::·~ ," ". ·:.,-lC6 '\ ~O\'üVL\' Hi Jim, This incident was originally reported to me at 1830 hrs. yesterday as a 10 BBL kick taken on Nabors 4ES re-entering MPU well C-41. Thanks, Jeff gas Content-Type: message/rfe822 Content-Encoding: 7bit '(;'f A i'.It\ií:;:' <)~r~G'5f<'~cL) it:~:. \:.,;' 1 of 1 12/9/2005 1 :00 PM 4ES gas bubble e e Subject:4ES gas bubble . . From: "NSU, ADW Drlg Rig 4ES" <NSUADWDrlgRig4ES@}3P.com> Date:Fri"q~ Dee 200508:50:03 -0900 To: jeff jon'es@admin.state.alcus :.~:. . .~..: :~:::. As per our phone conversation, here is what happened. vOÎ~ ~O\ Jeff, Date of incident: 12/08/2005 Time: 17:50 hrs Location: Milne Pt C-41 Scenario: A Halliburton Storm Packer was set @ 2330' w/ approximately 7500' of 27/8" tubing hanging off below it. We went in to retrieve the Storm Packer. This is done by screwing into the packer and opening the storm valve which allowas us to pump thru the packer & on down the tubing. For some reason, (yet to be determined), the valve did not function properly. We were, however, able to screw into the packer with the retrieving tool, and successfully unseat the packer. The well was monitored for approximately 45 minutes. Residual gas, that was trapped under the packer, migrated up the hole and flow was noted. The annular preventor was closed at the remote station, but the solenoid actuator did not cause the valve at the accumulator to go all the way over to the closed position. As a result, the annular preventor did not close all the way. As a result, fluid sparyed above the rig floor 5' -6'... approximately 25 gallons. The problem was rectified, the annular closed & well shut in. No discernable pressure was seen on any of the gauges. We bled off the well thru the choke... very small amount of gas..and filled the hole and monitored. The well was stable, taking a small amount of fluid. No flow, no influx, just residual gas that had accumulated under the packer. Let me know if you need more. 4ES gas bubble 1 of! 12/9/2005 12:23 PM Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Beth Well MPC-41 MPG-05 MPL-33 P-06A DS 02-25 u.~. 09-10 B-20 Y-25 PSI-10 P-26 02-14A F-12 04-35 ~ 5-09A 15-09A 5-09A ". J-13 D.S. 09-29 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889195 10715440 11058514 11132061 10987525 11058237 10980591 10928605 10715447 10928634 11075901 NA 10889172 10889183 NA 10919942 10877750 10980596 5Cl\NNE{) OCT 3 1 2005 Log Description SBH SURVEY MPSP INJECTION PROFILE INJECTION PROFILE LDL INJECTION PROFILE INJECTION PROFILE 1>~\t~ ~ LDL MEM PPROF W/DEFT MPSP IPROF & WARMABACK MEM PPROF W/DEFT MEM PPROF & IPROF LDL SBHP SURVEY OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE OIL PHASE BOTTOM HOLE SAMPLE LDL PPROF WIDEFT c Oûl-~t)- Date 12/24/04 11/09/04 06/03/05 10/12/05 06/24/05 08/16/05 08/05/05 11/20/04 01/01/05 06/02/05 07/09/05 06/03/05 10/10/04 11/04/04 02/02/05 02/13/05 06/29/04 08/10/05 NO. 3503 10/18/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD -, ~/ Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503- 8 A TIN: Beth Received by: 'ðJ' ~, Áhl:~ u.'-rð; .ç;,~ Permit to Drill 2010780 DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. MILNE PT UNIT SB C-41 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23014-00-00 MD 12087 ,.._~ TVD 4391 .--- Completion Dat 6/14/2001 .J Completion Statu SQZED Current Status SQZED UIC N REQUIRED INFORMATION Log N__~o Sample No Directional Survey Mud DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media R Digital Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) Ver LIS Verification R R R R R R Cn See Notes Cn See Notes Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data Directional Data 1 FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL 75 75 75 12018 12087 8766 OH I Dataset CH Received Number Comments Open 12/28/2001 /.,,.~500 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 Open 1/17/2002 Directional Data MWD -Directional Data digital data Directional Data Directional Data digital data Directional Data PB1 MWD Directional DataPB1 digital data Directional Data PB1 Directional Data PB1 digital data Directional Data PB2 MWD Directional Data PB2 digital data' Directional Data PB2 Directional Data PB2 digital data ~1201~igital Well Log data: NOTE: No Paper copies were received MD AND TVD 11202 c45B 1 Digital Well Log data: NOTE: No Paper copies were received MD AND TVD Open 1/17/2002 Permit to Drill 2010780 DATA SUBMITTAL COMPLIANCE REPORT 718/2003 Well Name/No. MILNE PT UNIT SB C-41 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23014-00-00 MD 12087 TVD 4391 Completion Dat 6/14/2001 Completion Statu SQZED Current Status SQZED UIC N C Cn See Notes 75 12205 Open 1/17/2002 ~1'~203 PB 2 Digital Well Log data: NOTE: No Paper copies were received MD AND TVD Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~) Chips Received? ~ Analysis ~ RP.c~.ivecJ ? Daily History Received? Formation Tops ~ N Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITYAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-41, AK-MM-10166 December 15, 2001 MPC-41: iDigital Log Images: 50-029-23014-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANI) RETURNING THE ATTACH'I~'I)"cOPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP EXploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I RECEIVED JA ,I i 7 2O02 ,Alaska Oil & Oas Cons. Commission' Ancbo e I loho:¢ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPC-41 PB1, AK-MM-10166 December 15, 2001 1VIPC-41 PBI: Digital Log Images: 50-029-23014-70 1 CD .Rom PLEASE ACKNOWLEDGE RECEIPT iBY SIGNING AND iRETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 REC IvF..D Date: I.~.,~ __ Signed: ? /2002 Ala~a Oil & Oa~ Con~. ~~r, Anchorage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7a' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPC-41 PB2, AK-MM-10166 December 15, 2001 MPC-41 PB2: Digital Log Images: 50-029-23014-71 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: Jim Galvin 6900 Arctic Blvd. Anch~g6~)aVED99518 BP Exploration (Alaska) Inc. Petro-technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 JAN ? 7 2002 Date: ,~t~ka Oil & 6as Cons. CommjB~mn To-' WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 21,2001 RE: MWD Formation Evaluation Logs MPC-41, AK-MM-10166 1 LIS formatted Disc with verification listing. API#: 50-029-23014-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO TIlE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 iBP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 iE. iBenson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED DEC 2 8 2001 Aiaska Oil & Gas Oozes. Anchorage STATE OF ALASKA {"~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-078 301-163 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-00 , , 4. Location of well at surface .Z-/.~~~, .._ .------~. ~. .--.~;.~.-,~:~; r 9. Unit or Lease Name 694' NSL, 2298' WEL, SEC. 10, T13N, R10E, UM ~ ~!~ i.~'~""~~ Milne Point Unit At top of productive interval ', [~,.:?~.: 2862' SNL, 95' EWL, SEC. 23, T13N, R10E, UM ~;/,~_'~.~ .... ~/' ;;, ~u~ At total depth ~ ~.!~'~;~ ~ 10. Well Number 3795' SNL, 341' EWL, SEC. 23, T13N, R10E, UM '! :i ! - ": ~ MPC-41 i ........ , 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 45.17' ADL 025518 17. Total Depth (MD+TVD)I 18. Plug Back Depth (MD+TVD) 0. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 12087 4391 FTI 10523 4327 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20"x 13-3/8" 94# / 54.5# H-40 / J-55 Surface 110' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 37' 11197' 9-7/8" 1456 sx Arctic Set I I1~ 792 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. ' ' TUBING RECORD Bottom and interval, size and number) , SiZE ' DEPTH' SET ('MD) PACK,=R SET (MD) " None ...... N/A ....... MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11147' Set EZSV Bridge Plug #1 10523' Set EZSV Bridge Plug #2 10523' Set Whipstock on Bridge Plug #2 27. PRODUCTION TEST ' Date First Production Method of Operation (FloWing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ~1~__.(~/___ D AUG 2 $ Z001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 ORIGI ,,iAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Ugnu 8237' 3725' Top Ugnu M 9443' 4046' Schrader NA 9800' 4146' Schrader NB 9940' 4182' Schrader NC 10050' 4210' Schrader NE 10154' 4237' Schrader NF 10345' 4286' Top Schrader OA 10500' 4322' Base OA / TSBC 10715' 4359' To Schrader OB 11120' 4395' Base OB / SBA5 11197' 4399' 3ii LiSt of Attachmentsi summary of Daily Drilling Reports, Sun/eys ........................................................................................................................................... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble,,~~ ~ Title TechnicalAssistant Date (~%~,,,~)-~[ , MPC-41 201-078 301-163 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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 (DF, 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 Legal Name: MPC-41 Common Name: MPC-41 TestOate::: :: : : TestType ::i :i::: Test ~th(TUD): ' Test DePth ('l'VD) i:I ::::: : :AMW i i :i Surface Pressure Leak Off Pressure (BHP) EMW 6/12/2001 FIT 11,240.0 (ft) 4,400.0 (ft) 9.00 (ppg) 450 (psi) 2,507 (psi) 10.97 (ppg) Printed: 8/24/2001 10:23:31 AM ,, BP EXPLORATION Page 1 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From -To Hours Activity Code NPT Phase Description of Operations 5/26/2001 12:00 - 00:00 12.00 MOB P PRE Blow Down And Disconnect Steam, Water, And Mud Lines Then Disconnect Air Lines - Pick Up 21 1/4" Annular With Bridge Crane System - Disconnect And Pull Back Electrical Cables - Pick Up All Steps And Landings - Move And Load Pipe Shed Tioga Heater - Install Towing Tongue On Pipe Shed And Move To End Of "E" Pad - Jack Up And Move Motor Shed To Enterance Of E Pad - Remove Rock Washer From Pit Complex And Load - Install Towing Tongue On Second Pipe Shed And Back To End Of "E" Pad - Move Pit & Pump Complex To The Enterance Of "E" Pad - Pull Sub Base Off Of Hole And Position On "E" Pad For Removal Of Cattle Shoot. 5/27/2001 00:00 - 00:30 0.50 MOB ~ PRE Hold Pre-Job Safety Meeting With All Nabors Personal And Peak Equipment Operators 00:30 - 01:00 0.50 MOB P PRE Move Sub Base Off Of Well Slot No. E-29i & Position On Pad 01:00 - 03:00 2.00 MOB 3 PRE Move Motor Complex ,&nd Pit/Pump Room Complex From "E" Pad To "C" Pad ,&nd Stage - Remove Cattle Shoot From Sub Base ,&nd Load Out On Trailer - Move Both Sets Of Wheel Bolsters To The Inside Position For Traveling Down The Road. 03:00 - 04:00 1.00 MOB 3 PRE Hook Onto Pipe Sheds With Bed Trucks - Secure For Hauling To C-Pad 04:00 - 05:30 1.50 MOB P PRE Road Two Pipe Sheds ,&nd Sub Base From "E" Pad To "C" Pad 05:30 - 08:00 2.50 MOB P PRE Close Sub Base Doors - Move Both Sets Of Wheel Bolsters To The Outside Position For Getting Over Well Slot No. C-41 - Install & Pin Cattle Shoot On Sub Base - Set Sub Base Matting Boards ,&nd Lay Herculite 08:00 - 12:00 4.00 MOB P PRE Set Sub Base Over Well Slot No. C-41 - Set Mud Pit & Pump Complex 12:00 - 13:30 1.50 MOB P PRE Lay Matting Boards ,&nd Herculite FOr Rock Washer 13:30 - 14:30 1.00 MOB P PRE Move And Stage Matting Boards For Pipe Shed - Move Motor Complex Around 14:30 - 15:30 1.00 MOB P PRE Lay Matting Boards For 1st Pipe Shed ,&nd Set Unit - Remove i Towing Gooseneck 15:30 - 16:30 1.00 MOB P PRE I Lay Matting Boards For Motor Complex ,&nd Set Unit - Hook Up I Service Lines 16:30 - 17:00 0.50 MOB P PRE Lay Matting Boards For 2nd Pipe Shed And Set Unit - Remove Towing Gooseneck 17:00 - 18:00 1.00 MOB . P PRE Set Fuel Transfer Building & Spot Main Fuel Storage Tank - Spot Holding Tank For Cement Water 18:00 - 21:00 3.00 RIGU P PRE Nipple Up Diverter Spool With 16" Outlet & Knife Valve Reduced To 10 3/4" Diverter Line. *Note* The Diveter Line Is Run Between The Electrical Cable Tray's ,&nd Above The Production Flow Lines (Some Have 3500 Psi.) Then To The Open Pit Where ,& Targeted Tee Is Installed Heading Parallel With Production Flowlines To The Open End of The Pits. 21:00 - 21:30 0.50 RIGU P PRE Set 21 1/4" Annular On Diverter Spool - Install Bolts 21:30 - 00:00 2.50 RIGU P PRE Install Western Gear Pipe Master Lay Down Machine Track To Rig Floor - Continue To Nipple Up 21 1/4" Diverter System - Install Turnbuckles - Pick Up Tools ,&nd Cellar - Berm Around Rig - Continue To Dress Mud Pumps - Work On Drag Link For Cuttings Trough 5/28/2001 00:00 - 03:00 3.00 RIGU P PRE Hook Up Flow Line To Bell Nipple - Load Pipe Shed With 5" Drill Pipe Mix Spud Mud - Set Cuttings Tank - Work On Berm Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 2 of'19 Operations Summar Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of OperatiOns 5/28/2001 00:00 - 03:00 3.00 RIGU ~ PRE Around Rig - Spot Spare Parts Building - String Out Geronimo Line. 03:00 - 05:00 2.00 RIGU 3 PRE Torque Up Bolts On 21 1/4" Annular To 16" Diverter Spool - Function Test Diverter And Preform Accumulator Test - Witness Of Test Was Waived By AOGCC Representive's John Spaulding And Jeff Jones 05:00 - 11:30 6.50 DRILL 3 SURF Pick Up And Stand Back 5" Drill Pipe 11:30 - 12:30 1.00 DRILL ~ SURF Hold Pre-Spud Meeting With Drilling Crews And Support Personal 12:30 - 13:00 0.50 DRILL ~ SURF Continue To Pick Up 5" Drill Pipe And Stand Back In Mast 13:00 - 15:30 2.50 DRILL 3 SURF Pick Up 5" HWDP And Stand Back In Mast - Teflon Drift Tight Change Out Rabbit For Metal Drift - Remove Spacer Plate On Varco Top Drive Lift Cylinder 15:30 - 18:00 2.50 DRILL P SURF Pick Up New Drilling Assembly - Pick Up Sperry Sun Steerable Directional BHA Tools - Mud Motor, MWD Tool, Filter Sub, String Stab Change AKO Setting On Motor - Make Up Bit - Pick Up Hang Off Sub And Install MWD Sensor Tools - Make Up HOC And Talk To Tool - Rig Up Slick Line Sheave For Single Shot Survey's 18:00 - 21:00 3.00 DRILL N RREP SURF Work On Varco Top Drive - Trouble Shoot Electrical Problems With DC Power 21:00 - 21:30 0.50 DRILL P SURF Make Up UBHO Sub & Stand Back In Derrick 21:30 - 22:00 0.50 DRILL P SURF Pick Up 5" Drill Pipe From Pipe Shed And Stand Back In Mast 22:00 - 23:00 1.00 DRILL P SURF Electrical Problem Sorted Out (Plug In Hall Way) Make Up BHA From Derrick & Initialize MWD Tool 23:00 - 00:00 1.00 DRILL P SURF Spud Well At 23:05 Hours - Drill Ahead From 110' To 181' - Weight On Bit 5K To 15K - Pump Pressure @ 91 Strokes Or 381 GPM (Off Bottom 450 Psi. & On Bottom 550 Psi.) - Torque @ 80 RPM (Off Bottom 2K & On BOttom 3K) - String Rotating Weight @ 90K - With Pump On Drag Up @ 95K Drag Down @ 85K 5/29/2001 00:00 - 13:30 13.50 DRILL P SURF Drill 181-1808'. WOB 15-30k; 2500 fi lbs torque; 60rpms;1050/1300psi-off bottom and on bottom 13:30 - 15:30 2.00 DRILL P SURF Wiper trip to the collars. Pumped out 11 stands drill pipe and pulled 7 stands hwdp-no problems, no swabbing. 15:30 - 16:30 1.00 DRILL P SURF Trip in hole. No problems. 16:30 - 23:00 6.50 DRILL P SURF Drill 1808'-3029'. WOB 10-20k; 3000-4000 fi-lbs torque off-on btm.; 70 rpm; 1300/15000 psi off/on btm. 23:00 - 00:00 1.00 DRILL P SURF Pump 30 bbl viscous sweep & start short trip (planned to 1600'). 5/30/2001 00:00 - 01:30 1.50 DRILL P SURF Finish wiper trip 2500-1559'. 01:30 - 02:30 1.00 DRILL P SURF TIH 1559'-3029'. Ream last 60' to btm. 02:30 - 17:00 14.50 DRILL P SURF Drill 3029'- 4655' & hold angle at 76.5 degrees inclination, 161 degree azimuth. 15- 20k WOB, 140000 PUW, 125000 SOW, 130000 ROTW. 4500 ft-lbf torque on btm, 3000 fi-lbf torque off btm, 70 rpm top drive. 1650 psi on btm, 1400 psi off btm, at 530 gpm. 17:00 - 21:00 4.00 DRILL P SURF Circulate btms up & start wiper trip to 1775'. Pulled total 32 stands. Pumped out at 400 gpm w/the 1st 18 stands and pulled 14 add. stands to 1580'. 21:00 - 22:30 1.50 DRILL P SURF Trip back to bottom at 4655. Hole tight going back in at 2989-3079 fi. 22:30 - 00:00 1.50 DRILL P SURF Drill 4655-4843'. 530 gpm, 1650/1400 psi on/off btm, Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 3 of 1:9 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 5/30/2001 22:30 - 00:00 1.50 DRILL P SURF 4500/3000 ft-lbf on/off btm, 140k PUW, 125k SOW, 130k ROTW. 5/31/2001 00:00 - 08:00 8.00 DRILL P SURF Drill 4843'-6047'. Total drilling hrs (26.25); 19.75 Rot hrs; 6.5 sliding hrs; 550 gpm, 1900/1750 psi on/off btm, 8-1 Ok/7 ft-lbf on/off btm, 170k PUW, 115k SOW, 135k ROTW. 08:00 - 09:00 1.00 DRILL P SURF Pump sweep and circulate hole clean 09:00 - 13:00 4.00 DRILL ~ SURF Pump out 15 stands at 400 gpm with 1000 psi. Pull 5 stands-no swabbing. Pump dry job and pooh to bha. No problems 13:00 - 15:00 2.00 DRILL ~ SURF L/d hang off sub and Iwd and bit. Clear rig floor. 15:00 - 16:00 1.00 DRILL ~ SURF MU 9 7/8" Smith FGS+CT bit & BHA No.2. 16:00 - 17:00 1.00 DRILL 3 SURF Load MWD. RIH w/HWDP & 5 in DP. Pulse test MVVD. 17:00 - 23:00 6.00 DRILL ~ SURF TIH w/5" DP picking up singles from pipe shed. Pipe stacking out at 2400' -2800'(through the build section). Worked through section without pumps. Fill DP w/mud. TIH w/total 162 singles to 5876'. Wash down to 6047' no fill. 23:00-00:00 1.00 DRILL ~ SURF Dri116047-6065'. PUW 175K. SOW 100k. ROTW 135K. PSI on/off btm 1800/1600 at 525 GPM. SFC RPM 80. BTM RPM 249. Torque 10K/8K on bottom/off bottom. 6/1/2001 00:00-13:00 13.00 DRILL 3 SURF Dri116065'-7722'. PUW 175K. SOW l00k. ROTW135K. PSI on/off btm 1800/1600 at 525 GPM. SFC RPM 80. BTM RPM 249. Torque 10K/8K on bottom/off bottom. 13:00 - 14:00 1.00 DRILL P SURF Pump sweep and circulate hole clean. 14:00 - 16:30 2.50 DRILL P SURF Wiper trip to 5900'. Pulled 8 stds without problems. Hole started swabbing on stand #9. Pumped out stands 9-18 with 400 gpm with 1200 psi. Pulled stands 19 and 20 without 3umps, no problems-no swabbing, 16:30 - 18:00 1.50 DRILL P SURF TIH. Hole taking weight. Had to work through tight spots from 7002-7342. Pumped from 7342-7437. Ran the last 3 stands in. Wash and ream last stand down. 18:00 - 18:30 0.50 DRILL P SURF Wash down 7340-7471'. TIH to 7722'. 18:30 - 00:00 5.50 DRILL P SURF Drill 7722-8314'. PUW 195k, SOW 105k, RO'DW 142k, Torque on/off btm 14,000/10,000 ft-lbf. Pump on/off btm 2350~2050 psi. 10-30k WeB. 90 rpm surface. 270 rpm btm hole. (.33 rpm/gpm). 6/2/2001 00:00 - 07:00 7.00 DRILL P SURF Drill 8314'-8766. PUW 195k, SOW 105k, RO'FW 142k, I Torque on/off btm 14,000/10,000 ft-lbf. 550gpm,Pump on/off btm 2350~2050 psi. 10-30k WeB. 90 rpm surface. 270 rpm btm hole. We made a connection at 8689'. Several sections drilled from 20-50 fph. At 8766' the bit stopped drilling there was a pressure spike from 2400-2700 psi. Then there was a 200-300 pressure drop. We tried all options but none worked. The psi would drop off immediately when you picked up. 07:00 - 15:00 8.00 DRILL N DFAL SURF Pumped out 16 stands from 8766'-7266'. Pulled 5 stands and pumped the dry job. Stood the bha back in derrick. The bit, bit sub. and 7-1/2 inches of the 4" drive shaft were left in the hole. Total length of fish left in hole was 2-1/2 feet. Decision was made to do an open hole sidetrack. 15:00 - 16:00 1.00 DRILL N DFAL SURF Service top drive. 16:00 - 18:00 2.00 DRILL N DFAL SURF Cut & slip 106' of drilling line. 18:00 - 20:00 2.00 DRILL N DFAL SURF MU 36 jts 3 1/2" 15.5# DP. 20:00 - 21:00 1.00 DRILL N DFAL SURF MU 9 7~8" MXCl bit, 1.5 deg bend motor 8", MWD, DC's, jars, 20 jts HWDP. Printed: 7/23/2001 11:49:12 AM BP ExpLORATION Page 4 of 19 Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations .... 6/2/20Ol 21:o0- 21:30 0.50 DRILL N DFAL SURF Align MWD. 21:30 - 00:00 2.50 DRILL N DFAL SURF TIH w/5" DP to 4660'. 6/3/2001 00:00 - 06:00 6.00 DRILL N DFAL SURF Continue tripping in hole to 5600'. Stacking out weight and could not get down. Wash and ream from 5600'-8600'. 06:00 - 12:00 6.00 STKOH N DFAL SURF Start sidetracking and cutting a trough. Tagged old fish at 8625'. Pooh one stand to 8506'. Start sidetraking again. Well was sidetracked at 8550'. Continue drilling to 8766'. 12:00 - 22:30 10.50 STKOH ~ SURF Drill 8766'-9915. Wob 20-25K; 550 gpm; 2000 psi; Torque-15K/13k-on/off bottom. 22:30 - 00:00 1.50 STKOH = SURF Circulate sweep bottoms up. Pump out of hole 9915-9540. 6/4/2001 00:00 - 01:30 1.50 STKOH ~ SURF Continue pumping out of hole 9540-8506. 01:30 - 02:00 0.50 STKOH ~ SURF POOH 8506-8038' with no hole problems. 02:00 - 03:00 1.00 STKOH ~ SURF TIH 8038-9915 no fill. Took 20k down weight. Wash & ream last stand to btm. 03:00- 20:00 17.00 STKOH ~ SURF Drill 9915-10493'. Control drill 100 fph 10943-10572'. Top of OA sand drilled at 10215'. Drill 10572-11210 section TD. PUW 235K, SOW 105K, ROTW 105K. 20-40K WOB. Torque on/off btm 17000/15000. SPP on/off btm 2150/1950 at 550 GPM. ECD from PWD tool measuring 10.4 ppg. Acoustic caliper shows the average hole diameter at 10.24" for an overall 4% increase over gauge hole. 20:00- 00:00 4.00 STKOH P SURF Circulate bottoms up. Pump high viscosity sweep. Pump & back ream out of hole to 9071. Continue TOOH to 8883' with no hole problems. 6/5/2001 00:00 - 05:00 5.00 STKOH P SURF POOH to HWDP wiper trip/f/8883-810'. Clear rig floor. 05:00 - 11:00 6.00 STKOH P SURF RIH 810' - 11210' Fill pipe every 11 stands. Hit ledge at 7130'. 11:00 - 18:00 7.00 STKOH P SURF Circulate & condition mud to 18 Ib/100ft^2 yield point, 4 mi water loss(APl-30). Lubricant concentration raised to 5.5% (Lube-tex & Drill'nSlide). 18:00 - 00:00 6.00 STKOH P SURF POOH, Steel Line Measure (SLM). Record PUW, SOW, ROTW, ROT Torque(50 rpm) every 5 stands. Hole in excellent condition & pump-out was not required. 6/6/2001 00:00 - 01:30 1.50 CASE P SURF Continue POOH from 2592'. SLM DP measurement. Record .PUW, SOW, ROTW, TQ, every 5 stands. 01:30 - 06:00 4.50 CASE P SURF Lay down HWDP 20 its. LD BHA 3 flex DC's. Drain mud motor, break out drill bit. Download MWD. Laydown XO, stabilizer, float sub, motor,& MWD. Clear floor. 06:00 - 07:00 1.00 CASE P SURF Service top drive. 07:00 ~ 08:30 1.50 CASE P SURF RU casing running tools, change out elevator bails. RU fill-up line. 08:30 - 09:00 0.50 CASE P SURF Safety & planning meeting held on running and rotating 7" casing. 09:00 - 18:30 9.50 CASE P SURF RIH w/7", 26#, Hydril 521, IJ casing 140 jts 5880 ft. approx. Check floats, install straight blade centralizers on first 40 joints. 18:30 - 19:00 0.50 CASE P SURF Safety & planning meeting held on rig floor activities, organization, personnel positioning, drive sub handling, skate operations. Prepare crew for casing rotation/circulation w/ top drive operations. Kept pipe moving during safety meeting. 19:00 - 00:00 5.00 CASE P SURF RIH w/7" casing. Circulate 5 bpm, 150 psi, & rotate 1st ten jts then every 10th joint down starting at jt 140. Relief crew came Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 5 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/6/2001 19:00 - 00:00 5.00 CASE P SURF on tour at 11 pm and held tech limits meeting "Observing Ongoing Casing Running/Rotating Operations" of crew on tour. 6/7/2001 00:00 - 06:30 6.50 CASE P SURF Continue running in hole w/7" 26#, L80, 521 IJ casing. Casing started to "stack-out" at joint 205 approximately 8800 ft. MU drive sub and screwed in w/top drive. Establish circulation at 75 spin, 7.5 bpm, 300 psi. Keeping pipe moving. Circulate bottoms up in 67 minutes. Continue TIH breaking circulation and rotating down every 10th joint and as necessary. 06:30 - 10:00 3.50 CASE P SURF Install 7" TAM port collar between joints 258 & 259. Layed out and replaced 1 damaged jt (270) of casing. Casing would not go without rotating and circulating final 21 joints to bottom. Unable to reach TD on last joint using landing joint and mandrel hanger. Pick up one additional joint. Circulate and rotate final joint of casing into hole. Recorded PUW, ROTVV, SOW, & Torque values every 10 jts to TD for drag plot modeling. ;10:00 - 20:00 10.00 CASE ~ SURF Circulate & condition mud lowering rheology to less than 10 YP, adding water and thinner as necessary. Continue rotating pipe down while reciprocating approximately 15' strokes. Pump 80 bbl bicarbonate treated mud ahead of cement job.(prevent flowline plugging). 20:00 - 20:30 0.50 CASE 3 , SURF PJSM- Upcoming cementing operations and safety review with all personnel on rig. Written cementing & contingency plans forward prepared and reviewed. 20:30 - 23:30 3.00 CASE 3 SURF :Start pumping cement job: Schlumberger pumped 5 bbls CW100, Pressure test lines to 4500 psi. Pump 45 bbls CWl00 at 5 bpm. Pump 75 bbls mud push(w/red dye) spacer at 5 bpm. SD & drop btm wiper plug. Pump lead cement 1092 bbl ASIII cement mixed at 10.7 ppg, 4.44 cf/sk at 6.8 bpm. Pump tail cement 158 bbls CIG 15.8 ppg, 1.17 cf/sk at 5.8 bpm. SD & drop top wiper plug. Pump 10 bbls water spacer. SD & flush cmt lines. 23:30 - 00:00 0.50 CASE P SURF Switch to rig pumps & begin pumping displacement w/9.3 ppg mud at 8 bpm. Good mud returns. Cement to surface estimated at 500 bbls. Supersuckers & vac trucks loading out mud & cement returns to disposal site. 6/8/2001 00:00 - 02:00 2.00 CASE P SURF Continue displacing cement with rig pumps. Bump plug at 0100 hrs, 4175 strokes, 2500 psi. Release pressure, check floats, and holding ok. Final circulating pressure at 5 bpm 1300 psi. Recovered approximately 500 bbls cement to surface. LD cmt head. 02:00 - 03:00 1.00 BOPSUF:P SURF ND diverter stack & flowline. Disconnect lines from 20" riser. Drain stack of cement debris. Clean cellar w/supersucker. 03:00 - 05:00 2.00 BOPSUF:P SURF PU on 20" Hydril diverter & set emergency slips. Cut & drain 7" casing joint & LD same. Pulled 50,000 Ibf tension & set slips. 05:00 - 08:00 3.00 BOPSUFiP SURF ND 20" riser. Finish cut on 7" csg. ND knife valve to flow-line & mud cross. 08:00 - 15:30 7.50 BOPSUF'~P SURF Weld on casing head adaptor & allow to cool. Small leak in weld. Repair weld. Test w/N2 to 1000 psi for 10 mins 15:30 - 21:30 6.00 BOPSUF P SURF NU csg head, DSA, & BOP stack. Tighten locking ring to FMC head. Test to 1250 psi f/10 rains. Contact AOGCC w/3 hrs Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 6 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours ActivityCode NPT Phase Description of Operations 6/8/2001 15:30 - 21:30 6.00 BOPSUF:P SURF notice of pending BOP test. Torque up BOP stack bolts. RU choke & kill lines. RU turnbuckles & align stack. RU flow nipple, flowline, hole fill & bleeder lines. 21:30 - 00:00 2.50! BOPSUFi P SURF Change out saver sub on top drive. 6/9/2001 00:00 - 02:30 2.50 BOPSUF:P SURF Change-out top drive gripper dies & pipe guide for 3 1/2" DP. RU test equipment & install 2nd annulus valve. 02:30 - 03:30 1.00 BOPSUF N RREP SURF Fill stack & choke manifold w/water. Notice leak in flow-line below btm rams. Re-torque bolts on drilling spool-still leaking. 03:30 - 06:30 3.00 BOPSUF N RREP SURF ND BOP & replace ring gasket. NU BOP. 06:30 - 12:00 5.50 BOPSUF N RREP SURF Install test joint & plug. Fill stack & test BOPE to 250 psi Iow and 2500 psi high f/10 mins. Valve 15 on the choke manifold did not test. Test plug leaked during Annular test. Pull test plug, replace seal. Re-install test plug & continue testing. 12:00 - 18:00 6.00 BOPSUR P SURF Fill stack with water. Test Hydril bag, accumulator, blind rams, lower IBOP, Lower pipe rams, manifold valve to choke, HCR on choke, dart valve. NOTE: John Crisp of AOGCC witnessed BOP test. 18:00 - 00:00 6.00 BOPSUR N RREP SURF Inside BOP on Top Drive leaking. Remove pipe handler on top drive. Replace IBOP. Re-install pipe handler. 6/10/2001 00:00 - 02:00 2.00 BOPSUR N RREP SURF Re-assemble pipe handler after changing out IBOP. 02:00 - 04:00 2.00 BOPSUR P SURF Test choke valve #15 & upper IBOP 250 psi & 2500 psi OK. Blowdown choke & kill lines. Rig -up bails. 04:00 - 13:00 9.00 P PROD1 LD 5" DP in mouse hole. 5000' left standing in derrick. 13:00 - 18:30 5.50 DRILL P PROD1 Change jaws on iron roughneck. PU, rabbit, & RIH w/99its. POOH & stand back 3 1/2" DP. 18:30 - 00:00 5.50 DRILL P PROD1 MU bit, DGR/EWR/DM/PWD/UBHO BHA. Adjust motor to 1.5 deg bend. Orient offset. Initialize MVVD. 6/11/2001 00:00 - 00:30 0.50 DRILL P PROD1 Surface test MWD at 5 bpm, 900 psi. OK 00:30 - 13:00 12.50 DRILL P PROD1 Blowdown top drive. PU 3 1/2" drillpipe in singles from pipe shed and RIH to 10728'. Circulate mud system. 13:00 - 14:30 1.50 DRILL P PROD1 Slip & cut 91' of drilling line. 14:30 - 15:30 1.00 DRILL P PROD1 Change bails. 15:30 - 16:30 1.00 DRILL P PROD1 RIH tag float collar at 11113'. Test casing to 3500 psi for 30 minutes. 16:30- 18:00 1.50 DRILL P PROD1 Drill FC, cmt, FS & clean-out to 11210'. 18:00 - 23:00 5.00 DRILL P PROD1 Move-in vac trucks & super sucker. Circulate mud system drawing down pit 8. Shut-down & clean pit suction. Mix & pump 30 bbl Iow vis & 30 bbl weighted hi-vis spacer. 123:00 - 00:00 1.00 DRILL P PROD1 Start displacing old mud w/new BARADRILn mud system at 60 spm, 6 bpm, 2700 psi. 6/12/2001 00:00 - 01:00 1.00 DRILL P PROD1 Continue Fluid Displacement And Clean Out Mud Trough's In Pit System 01:00 - 01:30 0.50 DRILL P PROD1 Circulate And Build Volume 01:30 - 02:00 0.50 DRILL P PROD1 Drill Ahead From 11,210' To 11,240' 02:00 - 03:00 1.00 DRILL P PROD1 Pull Back Into 7" Casing Shoe At 11,194' And Circulate Bottoms Up 03:00 - 03:30 0.50 DRILL P PROD1 Preform Formation Integrity Test To 11.0 PPG @ 450 Psi. With 9.1 PPG Mud 03:30 - 18:30 15.00 DRILL P PROD1 Directional Drill Ahead From 11,240' To 11,900' 18:30 - 20:00 1.50 DRILL N DFAL PROD1 Circulate And Condition Mud - Consult With Steve Schultz & Larry Vendal For Decision On Drilling Ahead 20:00 - 00:00 4.00 DRILL P PROD1 Directional Drill Ahead From 11,900' To 12,090' 6/13/2001 00:00 - 01:00 1.00 DRILL P PROD1 Continue To Drill Ahead From 12,090' To 12,205' Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 7 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/13/2001 01:00 - 02:00 1.00 DRILL N PROD1 Pump Up Survey - Circulate And Consult With Steve Schultz, Larry Vendal & Mik Triolo For Decision On Drilling Ahead 02:00 - 02:30 0.50 DRILL C PROD1 POH To 11,730' 02:30 - 04:00 1.50 DRILL C PROD1 Open Hole Side Track (Trough Ahead Under Cut Low Side Of Hole) Directional Drill Ahead From 11,730' To 11,790' 04:00 - 10:00 6.00 DRILL C PROD1 Continue To Directional Drill Ahead From 11,790' To 12,087' 10:00 - 10:30 0.50 DRILL C PROD1 Circulate & Condition Mud 10:30 - 11:30 1.00 DRILL C PROD1 POH To 7" Casing Shoe To 11,198' 11:30 - 13:30 2.00 DRILL C PROD1 Circulate And Pump Hi-Vis Sweep Around - Pump Dry Job 13:30 - 14:00 0.50 DRILL C PROD1 Blow Down Varco Top Drive & Surface Circulating System 14:00 - 18:00 4.00 DRILL C PROD1 POH With 3 1/2" Drill Pipe Stand Back In Mast 18:00 - 19:00 1.00 DRILL C PROD1 Lay Down Drilling Jars, (3) Flex Drill Collars, And Float Sub 19:00 - 20:30 1.50 DRILL C PROD1 Retrieve Data From Sperry Sun Logging Tools 20:30 - 21:30 1.00 DRILL C PROD1 Continue To Lay Down BHA - Drain Mud Motor - Break Off Bit - Lay Down Hang Off Sub, MWD Tool, LWD Tool, Mud Motor 21:30 - 22:00 0.50 DRILL C PROD1 Clear Off Rig Floor Of Sperry Sun Logging Tools & BHA - Bring Haliburton Packers To Rig Floor With Running Tool 22:00 - 22:30 0.50 DRILL C PROD1 Hold Pre Job Safety Meeting - Make Up Haliburton Running Tool Pick Up EZSV Bridge Plug And Make Up To Running Tool :22:30 - 00:00 1.50 DRILL C PROD1 RIH With EZSV Bridge Plug On 3 1/2" Drill Pipe (SLM) 6/14/2001 :00:00 - 05:00 5.00 DRILL C PROD1 RIH With EZSV Bridge Plug On 3 1/2" Drill Pipe (SLM) To 11,147' 05:00 - 05:30 0.50 DRILL C PROD1 Break Circulation Wash And Clean EZSV Bridge Plug Setting Area - Apply 35 Turns To The Right - Apply An Additional 5 Turns To The Right - Release Torque From String - Pick Up And Verify That EZSV Is Set @ 11,147' To 25K Above Normal Upward Drag - Shear Off From EZSV With 45K @ 195K - Pick String Up To 11,137' - Apply 30 Turns To The Right And Release Torque - Sit Down And Tag EZSV With 30K - Pick Up String And Test EZSV To 3,500 Psi. For 10 Minutes - Bleed Off Pressure 05:30 - 06:00 0.50 DRILL C PROD1 Pump Dry Job - Blow Down Top Drive And Circulating System 06:00 - 12:00 6.00 DRILL C PROD1 POH With Bridge Plug Running Tool (SLM) 12:00 - 12:30 0.50 DRILL C PROD1 Change Out Haliburton EZSV Running Tool And Make Up Second EZSV Bridge Plug 12:30 - 13:00 0.50 DRILL C PROD1 Service Varco Top Drive, Traveling Blocks, And Crown Sheaves 13:00 - 19:00 6.00 DRILL C PROD1 RIH With Second EZSV Bridge Plug On 3 1/2 Drill Pipe To 10,523' (SLM) 19:00 - 20:00 1.00 DRILL C PROD1 Break Circulation Wash And Clean EZSV Bridge Plug Setting Area - Apply 35 Turns To The Right - Apply An Additional 5 Turns To The Right - Release Torque From String - Pick Up And Verify That EZSV Is Set @ 10,523' To 25K Above Normal Upward Drag - Shear Off From EZSV With 45K @ 195K - Pick String Up To 10,513' - Apply 30 Turns To The Right And Release Torque - Sit Down And Tag EZSV With 30K - Pick Up String And Test EZSV To 3,500 Psi. For 10 Minutes - Bleed Off Pressure 20:00 - 20:30 0.50 DRILL C PROD1 Pump Dry Job - Blow Down Top Drive And Circulating System Install Safety Wire On Varco Top Drive 20:30 - 00:00 3.50 DRILL C PROD1 POH With Haliburton Bridge Plug Running Tool 6/15/2001 00:00 - 00:30 0.50 P PROD2 Clear Rig Floor - Lay Down Haliburton EZSV Bridge Plug Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 8 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/15/2001 00:00 - 00:30 0.50 P PROD2 Running Tool - Bring Baker Oil Tools Mills & Cross Over Subs To Rig Floor. 00:30 - 04:00 3.50 STWHIP P PROD2 Pick Up Baker Oil Tools Window Master Whipstock & Milling Assembly - Orient MWD Tool - Down Load Data - Pick Up (1) 4 3/4" Drill Collar - Surface Test MWD Tool 04:00 - 05:30 1.50 STWHIP P PROD2 Pick Up 4 3/4" Drill Collars And 3 1/2" HWDP 05:30 - 12:00 6.50 STWHIP P PROD2 RIH With Whipstock & 3 1/2" Drill Pipe Out Of Mast To 10,518' 12:00 - 13:00 1.00 STWHIP P PROD2 Hold Pre Job Safety Meeting - Make Up Top Drive & Break Circulation - Establish Working Parameters - Survey And Orient Direction Of Whipstock To High Side For Kick Off - Strap In Whipstock To Top Of EZSV @ 10,523' And Set Down On Bridge Plug And Set Same - Shear Window Mill Shear Release Bolt 13:00 - 19:30 6.50 STWHIP P PROD2 Mill Window From 10,505' To 10,518' - Continue To Drill Formation To 10,538' 19:30 - 20:30 1.00 STWHIP P PROD2 Circulate Sweep Around While Working In And Out Of Window Monitor Well (Static) - Mix And Pump Dry Job - Blow Down Top Drive And Surface Circulating System 20:30 - 00:00 3.50 STVVHIP P PROD2 POH With 3 1/2" Drill Pipe And Stand Back In Mast 6/16/2001 00:00 - 00:30 0.50 P PROD2 Continue To POH - Stand Back 3 1/2" HWDP 00:30 - 02:00 1.50 STWHIP P PROD2 Lay Down 4 3/4" Drill Collars And Window Master Milling Assembly 02:00 - 02:30 0.50 DRILL P PROD2 Make Up Mud Motor To MWD Tool And Stand Back In Mast 02:30 - 03:00 0.50 DRILL P PROD2 Pull FMC Wear Bushing 03:00 - 04:00 1.00 DRILL P PROD2 Pick Up BOP Stack Flushing Tool And Wash Out Stack - Lay Down Flushing Tool And Baker Oil Tools Mills 04:00 - 05:00 1.00 DRILL P PROD2 Hold Pre-Job Safety Meeting - Make Up Test Plug And Seat In Well Head Profile - Rig Up Test Equipment To Choke Manifold And Test Joint - Open Annulus Valve 05:00 - 09:00 4.00 DRILL P PROD2 Weekly BOP Test Witness Waived By AOGCC Representive John Spaulding - Test All Choke Valves, Upper And Lower Pipe Rams, Blind Rams, HCR Valves, Manual Valves On Choke And Kill Line, Upper And Lower IBOP Valves On Top Drive, Dart Valve, And Full Opening Safety Valve At 250 Psi. Low Pressure For 5 Minutes And 2500 Psi. High Pressure For 10 Minutes. Rig Down All Test Equipment 09:00 - 09:30 0.50 DRILL P PROD2 Install Wear Bushing - Blow Down All Surface Lines 09:30 - 11:00 1.50 DRILL P PROD2 Hold Pre-Job Safety Meeting - Pick Up And Make Up BHA (At Bit Inclination On Motor Would Not Turn On) - Lay Down Motor And Shuffle 3 1/2" HWDP In Mast 11:00 - 12:00 1.00 DRILL P PROD2 Pick Up Second Mud Motor - Make Up Bit And Orient With MWD Tool 12:00 - 13:00 1.00 DRILL P PROD2 Initialize MWD Tool 13:00 - 14:00 1.00 DRILL P PROD2 Make Up (3) Flex Drill Collars, Jars, And (5) 3 1/2" HWDP 14:00 - 14:30 0.50 DRILL P PROD2 Break Circulation And Surface Test MWD Tool 14:30 - 18:00 3.50 DRILL P PROD2 RIH With (96) Stands Of 3 1/2" Drill Pipe And (24) Joints Of 3 1/2" HWDP And (7) Stands Of 3 1/2" Drill Pipe To 10,501' 18:00 - 18:30 0.50 DRILL P PROD2 Break Circulation And Orient Mud Motor To High Side - Work Thru Window (NO Problems) Wash To 10,538' 18:30 - 00:00 5.50 DRILL P PROD2 Directional Drill Ahead From 10,538' To 10,900' - Weight On Bit 5K To 15K - Pump Pressure @ 62 Strokes Or 260 GPM (Off Bottom 2300 Psi. & On Bottom 2650 Psi.) - Torque @ 80 RPM (Off Bottom 2K & On Bottom 5K) String Rotating Weight Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page9 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/16/2001 18:30 - 00:00 5.50 DRILL P PROD2 @ 128K - With Pump On Drag Up @ 155K Drag Down @ 105K 6/17/2001 00:00 - 09:30 9.50 DRILL P PROD2 Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 10,900' To 11,438' -Weight On Bit 5K To 15K - Pump Rate @ 65 Strokes Or 275 GPM (Off Bottom Pressure At 3000 Psi. & On Bottom Pressure At 3200 Psi.) - Top Drive At 80 RPM (Off Bottom Torque At 2K & On Bottom Torque At 5K) String Rotating Weight At 118K - With Pump On Drag Up At 147K And Drag Down At 107K 09:30 - 12:30 3.00 DRILL N DFAL PROD2 MWD Tool Recieving Poor Signal After Swaping Out Mud While Drilling - Mud Appears To Have Aired Up -Pump 30 Barrel Lo-Vis Sweep - Circulate And Condition Mud Also Work Pipe And Check Out Sperry Sun Surface Sensors And Equipment - While Attempting To Get A Good Detection Signal 12:30 - 14:30 2.00 DRILL P PROD2 Drill Ahead From 11,438' To 11,519' 14:30 - 15:00 0.50 DRILL N DFAL I PROD2 Attempt To Regain Detection Signal For Sperry Sun Tools 15:00- 18:30 3.50 DRILL P IpROD2 Drill Ahead From 11,519' To 11,680' 18:30 - 20:00 1.50 DRILL N DFAL PROD2 Circulate And Work Pipe While Attempting To Regain Detection Signal For Sperry Sun Tools - Charge Pulsation Dampners On Mud Pumps From 750 Psi. To 1,000 Psi. - Transfer 175 Barrels Into Active System From Trip Tank To Raise Pit Volume To Allow More Time For Air To Break Out Of The Mud - Change Flow Path Of Fluid In Mud System From Pits 5 Thru 8 To Flow Thru Pits 1 Thru 8 Using All Pits - Change Sperry Sun Sensor Placement On Stand Pipe - Add Drilling Slide To Mud *Note* Both Mud Engineers, Directional Drillers, Companyman, And Toolpushers Working To Solve Problem - After Making Above Changes We Were Able To Drill Ahead With A Workable Signal. 20:00 - 00:00 4.00 DRILL P PROD2 Drill Ahead Thru Schrader Bluff "OA" Sand From 11,680' To 11,990' - Weight On Bit 2K To 5K With Pump Rate At 66 Strokes Or 277 GPM - (Off Bottom Pressure At 2950 Psi. & On Bottom Pressure At 3175 Psi.) - Top Drive RPM At 30 To 65 - (Off Bottom Torque At 2K & On Bottom Torque At 5K) String Rotating Weight At 118K - With Pump On Drag Up At 143K And Drag Down At 102K 6/18/2001 00:00 - 02:30 2.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,000' To 12,075' - Weight On Bit 2K To 5K With Pump Rate At 66 Strokes Or 277 GPM - Off Bottom Pump Pressure At 2950 Psi. & On Bottom Pump Pressure At 3175 Psi. - Top Drive RPM At 30 To 65 - Off Bottom Torque At 2K & On Bottom Torque At 5K String Rotating Weight At 118K - With Pump On Drag Up At 143K And Drag Down At 102K 02:30 - 03:00 0.50 DRILL N DFAL PROD2 Poor Signal Detection With Sperry Sun Equipment- Change Out (2) Transducer's On Stand Pipe Manifold 03:00 - 04:00 1.00 DRILL P PROD2 Drill Ahead From 12,075' To 12,123' 04:00 - 04:30 0.50 DRILL N DFAL PROD2 Signal Failure - Attempting To Regain Detection Signal For Sperry Sun Tools 04:30 - 06:30 2.00 DRILL P PROD2 ECD At 11.6 PPG Pump Out Of The Hole Thru Schrader Bluff "OA" Sand Formation To Whipstock Window In Order Clean Open Hole Section For Reducing ECD's 06:30 - 08:30 2.00 DRILL P PROD2 Pump Sweep And Circulate Hole Clean - Monitor Well Bore Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1:0 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activityl Code NPT Phase Description of Operations 6/18/2001 06:30 - 08:30 2.00 DRILL P PROD2 (Static) - Change Sperry Sun Sensor Placement And Recheck Signal (NO GOOD) - Pump Dry Job - Blow Down Top Drive And Circulating System 08:30 - 12:30 4.00 DRILL N DFAL PROD2 POH To 365' With 3 1/2" Drill Pipe And HWDP 12:30 - 13:00 0.50 DRILL N DFAL PROD2 Surface Test MWD Tool - Blow Down Top Drive 13:00 - 13:30 0.50 DRILL N DFAL PROD2 Continue To POH To BHA 13:30 - 14:30 1.00 DRILL N DFAL PROD2 Adjust AKO Setting On Mud Motor To 1.5 And Orient To MWD Tool- Lay Down Pulser And Hang Off Sub 14:30 - 16:00 1.50 DRILL N DFAL PROD2 Down Load MWD Data - Inspect Pulser 16:00 - 17:30 1.50 DRILL N DFAL PROD2 Make Up Hang Off Sub And Install Pulser- Initalize MWD Tool 17:30 - 18:30 1.00 DRILL N DFAL PROD2 RIH With BHA To 365' - Surface Test Sperry Sun MWD Tool - Well Appeared To Be Flowing (Shut In At Surface) - Notify Nabors Toolpusher And BP Drilling Supervisor - NO PRESSURE - After Investigating Air From Filling BHA Came To Surface - Open Choke - Check For Flow At Shakers (NO FLOW) - Open Up Well And Monitor Well Bore For Ten Minutes For A NO FLOW - Talk With Rig Personal About Good Job Shuting In Well And Following BP Shut In Procedures - Continue On With Operation Blow Down Top Drive 18:30 - 19:30 1.00 DRILL N PROD2 Safety Meeting With Nabors Alaska Drilling Manager Mr. Jim Denny And Rig Personal 19:30 - 23:00 3.50 DRILL N DFAL PROD2 RIH With 3 1/2" Drill Pipe From Mast To 10,484' 23:00 - 00:00 1.00 DRILL P PROD2 Service Varco Top Drive - Install New Grease Zerts In Guide Rollers 6/19/2001 00:00 - 03:30 3.50 DRILL N RREP PROD2 Continue To Change Out Guide Roller On Varco Top Drive 03:30 - 05:00 1.50 DRILL P PROD2 Slip And Cut 110' Of 1 3/8" Drilling Line And Adjust Draworks Mechanical Brakes 05:00 - 07:30 2.50 DRILL P PROD2 RIH From Top Of Whipstock Window Take Check Shot At 11,392' And 11,800' - Continue To RIH To 12,094' Wash And Ream To Bottom At 12,123' 07:30 - 00:00 16.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,123' To 12,863'- Drill From 1930 Hours To 2300 Hours At High Side From 12,863' To 12905' Per Geologist - Drill From 2300 Hours To 00:00 Hours Straight Down From 12,905' To 12,,915'-Weight On Bit 2K To 10K With Pump Rate At 55 Strokes Or 233 GPM Off Bottom Pump Pressure At 2300 Psi. & On Bottom Pump Pressure At 2425 Psi. - Top Drive RPM At 0 To 70 - Off Bottom Torque At 2K & On Bottom Torque At 5K String Rotating Weight At 120K - With Pump On Drag Up At 138K And Drag Down At 100K *NOTE* Having A Problem Getting Weight Transfered To Bit At Present Time There Is 3.75 Percent Lube Tex In Mud System And We Are Using All Drill String Weight Toward Bit, We Are Able To Get Good Differential On Initial Slack Off Then Have To Pick Up String And Lower Again To Get Another Bite Of Formation. May Consider POH Fora Wiper Trip And Adding 3 1/2 HWDP To String If Sliding Operation Doesn't Improve. 6/20/2001 00:00 - 13:00 13.00 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,905' To 13,340' - Weight On Bit 2K To 1 OK With Pump Rate At 55 Strokes Or 233 GPM - Off Bottom Pump Pressure At 2325 Psi. & On Bottom Pump Pressure At Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1:1 of 19 Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/20/2001 00:00 - 13:00 13.00 DRILL P PROD2 2600 Psi. Top Drive RPM At 30 To 70 Off Bottom Torque At 5K & On Bottom Torque At 7K String Rotating Weight At 128K - With Pump On Drag Up At 150K And Drag Down At 85K 13:00 - 14:00 1.00 DRILL P PROD2 Circulate Bottoms Up For WiperTrip 14:00 - 15:00 1.00 DRILL P PROD2 POH (15 Stands) 12,052'-Wiper Trip (No Pumps, No Problems) 15:00 - 15:30 0.50 DRILL P PROD2 RIH To 13,247' (No Problems) 15:30 - 16:00 0.50 DRILL P PROD2 Break Circulation - Wash And Ream From 13,247' To 13,340' Swap Out Mud System Due To MBT's Above 3 Per Well Plan 16:00 - 00:00 8.00 DRILL P PROD2 Directional Drill Ahead From 13,340' To 13,712' 6/21/2001 00:00 - 06:30 6.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 13,712' To 14,148'- Weight On Bit 2K To 1OK With Pump Rate At 55 Strokes Or 233 GPM - Off Bottom Pump Pressure At 2325 Psi. & On Bottom Pump Pressure At 2600 Psi. Top Drive RPM At 30 To 70 Off Bottom Torque At 6K & On Bottom Torque At 10K String Rotating Weight At 128K - With Pump On Drag Up At 155K And Drag Down At 85K 06:30 - 08:30 2.00 DRILL P PROD2 Circulate And Condition Hole - Geologist Confirmed Fault Crossed And TD On Lateral Section At 14,148' 08:30 - 13:30 5.00 DRILL P PROD2 Pump Out Of The Hole To Whipstock Window - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Circulating System Wash Off Rig Floor Due To Pulling Pipe Wet. 13:30 - 19:00 5.50 DRILL P PROD2 Continue To POH (Slow) Due To Swabbing - Increase Pulling Speed As Hole Permitted 19:00 - 20:30 1.50 DRILL P PROD2 Monitor Well Bore (Static) - Work BH^ - Down Load Data From Sperry Sun Tools - Remove Pulser - Lay Down Hang Off Sub, PWD Tool, Gamma/Resistivity Float Sub, Mud Motor, & 6 1/8" Bit Clean Up And Clear Rig Floor Of Sperry Sun Tools 20:30 - 21:30 1.00 DRILL P PROD2 Hold Pre Job Safety Meeting - Drain BOP Stack - Make Up Bushing Puller And Pull Wear Ring - Install Test Plug And Test Joint - Rig Up Test Equipment 21:30 - 00:00 2.50 DRILL P PROD2 Test BOP And Related Equipment - Witness Of Test Waived By AOGCC Inspector Chuck Sheave - Test All Manual Valves On Choke Manifold And Super Choke, 13 5/8 Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valve's On Choke And Kill Line, Upper And Lower Top Drive IBOP Valves, Dart Valve And Full Opening Safety Valve At 250 Psi. Low Pressure For 5 Minutes And 2,500 Psi. High Pressure For 10 Minutes. 6/22/2001 00:00 - 02:30 2.50 DRILL P PROD2 Continue To Test BOP And Related Equipment 02:30 - 03:30 1.00 DRILL P PROD2 Rig Down Testing Equipment - Pull Test Plug - Install Wear Ring And Energize 4 Lock Down Studs - Blow Down Top Drive, Choke Manifold, Choke And Kill Lines - Clear Rig Floor 03:30 - 05:00 1.50 DRILL P PROD2 Pick Up 6 1/8" Hole Opener, (3) Stabilizer's, Float Sub, And Pony Collar 05:00 - 10:30 5.50 DRILL P PROD2 Continue To RIH With 3 1/2" Drill Pipe From Mast To 10,522' 10:30 - 00:00 13.50 DRILL P PROD2 Ream Schrader Bluff "O^" Sand Lateral Section From 10,522' To 14,148' (NO FILL) ~ Weight On Hole Opener 2K To 5K With Pump Rate At 66 Strokes Or 275 GPM - Pump Pressure At 2325 Psi. - Top Drive RPM At 100 Torque At 3K To 5K String Rotating Weight At 128K - With Pump On Drag Up At 155K And Drag Down At 85K '6/23/2001 00:00 - 01:30 1.50 DRILL P PROD2 Hold Pre Job Safety Meeting With New Crew Coming From Printed: 7/23/2001 11:49:12AM BP EXPLORATION Page 12 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E I~ate From - To Hours Activity Code NPT Phase Description of Operations 6/23/2001 00:00 - 01:30 1.50 DRILL P PROD2 Day's Off Circulate And Condition Mud At 14,148' 01:30 - 07:00 5.50 DRILL P PROD2 Monitor Well Bore (Static) - Drop Rabbit - Attempt To POH With Hole Opener (Well Swabbing) Pump Out Of The Hole - Attempt To Pull Pipe After Every Row Stood Back In Mast - SLM And Get Up And Down Weight's In Open Hole Every 500' In Open Hole With Pump Off. 07:00 - 09:00 2.00 DRILL P PROD2 Circulate And Spot 2% EP Mud Lube In Casing 09:00 - 14:30 5.50 DRILL P PROD2 Continue To POH Slow Due To Swabbing At Higher Speed 14:30 - 16:00 1.50 DRILL P PROD2 Monitor Well Bore (Static) - Lay Down BHA - Clear Rig Floor 16:00 - 17:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up To Run Baker P & A Kit 17:30 - 18:30 1.00 CASE P PROD2 Pick Up And RIH With Baker Oil Tools Plug And Abandon Kit Per Procedure - Change Elevators - RIH With One Stand Of 3 1/2" Drill Pipe From Mast And Check Float Equipment. 18:30 - 00:00 5.50 CASE P PROD2 Continue To RIH With 3 1/2" Drill Pipe From Mast To 7,907' - Fill Pipe Every 20 Stands Verify Correct Displacement. 6/24/2001 00:00 - 02:30 2.50 CASE C PROD2 RIH With Baker Oil Tools Plug And Abandon Kit Per Procedure With 3 1/2" Drill Pipe From Mast To 10,405'- Fill Pipe Every 20 Stands Verify Correct Displacement. 02:30 - 03:30 1.00 CASE C PROD2 Circulate Drill Pipe And Liner Volume - Change Out Bales To Longer Set To Facilitate Installation Of Swing, Head Pin, And Full Opening Safety Valve Under Top Drive Pipe Handler. 03:30 - 06:00 2.50 CASE C PROD2 Continue To RIH Thru Schrader Bluff "OA" Sand Open Hole Section To Float Shoe Depth At 14,141' - Top Of LSV^t 13,953' - Position Baker Payzone Open Hole Packer Element Across Following Depth Top At 13,955' And Bottom At 13'975' 06:00 - 06:30 0.50 CASE C PROD2 Pick Up And Make Up Head Pin And Cement Hose 06:30 - 07:00 0.50 CASE C PROD2 Circulate And Condition Mud At 5 Barrel Per Minute With 1200 Psi. Hold Pre Job Meeting With All Personal On Up Coming Cement And Displacement Operation 07:00 - 09:00 2.00 REMCM'I'C PROD2 Pump 5 Barrels Of 6% KCL Water - Test Lines And Surface Equipment At 4000 Psi. (Good Test) - Pump 5 Barrels Of 6% KCL Water- Mix And Pump 7 1/2 Barrels (37 Sacks) Of 15.8 PPG Cement At 3 BPM w/1050 Psi. - Drop Drill Pipe Wiper Dart Pump 5 Barrel Water - Drop Foam Plug - Start Displacement At 4.1 BPM w/1450 Psi. 90 Barrels Away Slow Rate To Bump Plug - Bump Plug w/97 3/4 Barrels Away At 500 Psi. To 900 Psi. - Increase Pressure In 200 Psi. Increments "LS" Valve Opened On Packer At 2500 Psi. - Shut Down Pump Pressure Stablized At 1600 Psi. Hold For 2 To 3 Minutes To Square Off Element - Bleed Off Pressure To 650 Psi. To Check Volume Of Inflation Fluid (1/4 Barrel To Inflate) - Bleed Pressure To 0 Psi. Verify Packer Set By Slacking Off 5K Pounds - Pressure Up To 3000 Psi. To Shear Hydraulic Disconnect - Bleed To 0 Psi. - Pick Up To Verify Disconnected - Pull One Stand 09:00 - 11:00 2.00 REMCM' 'C PROD2 Circulate Out Cement And Spot New Mud Thru "OA" Sand Open Hole Section 11:00 - 14:00 3.00 REMCM' 'C PROD2 Monitor Well Bore (Static) - POH To 10,200' Slow To Prevent Swabbing With 3 1/2" Drill Pipe Stand Back In Mast 14:00 - 18:30 4.50 REMCM' 'C PROD2 Monitor Well - Pump Dry Job - Blow Down Top Drive And Circulating System - Continue To POH 18:30 - 19:00 0.50 REMCM' 'C PROD2 Lay Down Baker Hydraulic Disconnect Running Tool - Clear Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1,:,3 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours ActivityCode NPT Phase Description of Operations 6/24/2001 18:30- 19:00 0.50 REMCM;'C PROD2 Rig Floor 19:00 - 20:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up Casing Tools And Equipment To Run 4 1/2" Slotted Liner 20:30 - 00:00 3.50 CASE P PROD2 RIH With 4 1/2" L-80 IBT 12.6 lb. Slotted Liner 6/25/2001 00:00 - 01:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up Equipment To Run Inner String Of 2 7~8" Fox Tubing 01:30 - 06:00 4.50 CASE P PROD2 Pick Up Slick Stick, Crossover, 106 Joints 2 7~8" Fox Tubing, 4 Foot Pup Joint For Space Out, Crossover, To Complete Inner String And Run Inside 4 1/2" Slotted Liner 06:00 - 06:30 0.50 CASE P PROD2 Change Out Elevators For 3 1/2 Drill Pipe - Pick Up Baker 7" X 5" HMC Hydraulic Liner Hanger And ZXP Mechanical Set Packer - Make Up Crossover To 2 7~8" Inner String And Make Up To 4 1/2" Slotted Liner. 06:30 - 07:00 0.50 CASE P PROD2 Rig Down 2 7/8" Equipment And Clear Rig Floor - Dress Hanger And Fill With PAL Mix 07:00 - 07:30 0.50 CASE P PROD2 Circulate 2 7/8 Inner String And Bushing To Guide Shoe Volume 07:30 - 15:30 8.00 CASE P PROD2 RIH With 4 1/2" L-80 IBT 12.6 lb. Slotted Liner With 112 Stands Of 3 1/2" Drill Pipe From Mast To Window - Record Weight's Up And Down Per Engineer - Continue To RIH With Slotted Liner Thru Schrader Bluff "OA" Sand - Top Of Baker ZXP Packer At 10,405' And Baker Guide Shoe At 13,810' 15:30 - 16:30 1.00 CASE P PROD2 Drop 29~32" Ball - Circulate At 4 BPM w/1200 Psi. To Get Ball On Seat - Calculated Volume To Seat Ball 960 Strokes - Ball On Seat At 827 Strokes - Pressure Up To 1900 Psi To Set Baker 7"X5" HMC Hydraulic Liner Hanger - Slack Off String Weight 25K For Verification Of Hanger Setting - Pressure Up To 3,300 Psi. To Release HR Tool Shear Ball Seat Pressure At 0 Psi. - Pick Up Check Weight Reduction Lost 12,000 lbs. Continue To Pick Up 5 To 6 Feet To Expose Packer Setting Dog Sub - Slack Off 30,000 lbs. To Set Packer - Repeat 3 Times - Tag Liner Top At Proper Depth 10,405' 16:30 - 22:30 6.00 CASE P PROD2 Stand Back 2 Stands - Monitor Well - Pump Dry Job - POH With Baker Liner Running Tool And 2 7/8" Inner String 22:30 - 23:30 1.00 CASE P PROD2 Rig Up Tubing Tongs - Break Out And Lay Down Baker Liner Running Tools And Crossovers - Change Out Elevators And Clear Rig Floor 23:30 - 00:00 0.50 CASE P PROD2 Lay Down 2 7/8" Inner String 6/26/2001 00:00 - 06:30 6.50 STWHIP P PROD2 Continue LD 2 7~8" tubing (106 jts). Clear floor, LD handling tools. PU 3 1/2" single & MU to top drive. 06:30 - 11:00 4.50 STWHIP P PROD2 Cut & slip 106' of drilling line. Weld hand rail at derrick board. Service top drive. Inspect & measure bridle lines. 11:00 - 17:00 6.00 STVVHIP P PROD3 MU milling BHA & whipstock w/Iocator seal assembly. Load MWD. RIH w/9- 4 3/4" DC's, & 2 stands HWDP. Test MWD. 17:00 - 00:00 7.00 STWHIP P PROD3 TIH w/whipstock assembly to TOL. 6/27/2001 00:00 - 04:30 4.50 P PROD3 Set whipstock anchor w/20K Ibf weight and pull 15K to check anchor. Set 35K Ibfweight 3x and shear lug bolt. Mill window 10091-10103. Drill/mill formation to 10119'. 04:30 - 14:00 9.50 S'I'WHIP P PROD3 Pump hi vis sweep. Monitor well and POOH 10119-9730'. Continue POH and LD BHA and 4 3/4" DC's. Download MWD. PU motor, MU to MWD, and stand-back. LD mill assembly. 14:00 - 15:30 1.50 STWHIP P PROD3 Clear floor, pull wear ring. Grease crown. 15:30 - 21:00 5.50 S'I'WHIP P PROD3 Flush stack, kill HCR, & choke HCR. MU test assy & install Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 14 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/27/2001 15:30 - 21:00 5.50 STWHIP P PROD3 test plug. Conduct BOP test of all rams, annular, HCR's, choke valves, floor valves, floor valves, top drive IBOP's, to 250 psi Iow for 5 rains and 2500 psi high for 10 mins. Koomey test. BOP test witnessing waived by Lou Grimaldi of AOGCC. 21:00 - 22:00 1.00 DRILL P PROD3 MU BHA, orient motor, and load MWD. 22:00 - 00:00 2.00 DRILL P PROD3 TIH w/6 1/8" bit, 1.5 deg bend motor & BHA to 4166'. PUW 120K, SOW 100K. 6/28/2001 00:00 - 03:00 3.00 DRILL P PROD3 Continue TIH 4966-10119'. 03:00 - 00:00 21.00 DRILL P PROD3 Break circulation & drilling. Shaker screens blinding off. Change-out screens. Directionally drill, building angle and making azimuth change for L-2 lateral. Base of OA sand at 4360'. Received & changed out 900 bbls fresh BaradrilN mud from plant. Drill 10119 to 11027 fi at midnight report time. PUW 130K, SOW 100K, RO'RN 115K, TQON 3K, TQOFF 2K, RPM 70, WOB 6k, SPP 2400 psi, 55 SPM, 232 GPM. SPR at 20 SPM = 670 psi, SPR at 30 SPM = 860 psi. 6/29/2001 00:00 - 16:30 16.50 DRILL P PROD3 Drilling 11027-11955'. PUW 130, SOW 98, ROTVV 115, TQ on/off 3k fi-lbf. 16:30 - 17:30 1.00 DRILL P PROD3 Circulate bottoms up. 17:30 - 20:30 3.00 DRILL P PROD3 POH w/pumps on to 10021. Monitor well for 10 mins. Pull BHA through window and into casing. Serviced top drive. 20:30 - 21:30 1.00 DRILL P PROD3 Trip back in hole, break circulation and back on bottom drilling. Offloading 600 bbls "old" mud to vac trucks and preparing to take on 600 bbls "new" Baradriln mud. 21:30 - 00:00 2.50 DRILL P PROD3 Drilling ahead in OA lateral L-2 to 12139'. 10.85 ECD, 56 spin, 236 gpm, 2650 psi SPP on btm, 2450 psi SPP off btm, 4k ft-lbf TQ on btm, 3k fi-lbf off btm, 132K PUW, 98K SOW, 123K ROTW, 2-10K WOB, 60 RPM. 6/30/2001 00:00 - 0.00 DRILL P PROD3 Drill 12138-13543' in OA lateral L-2.70 rpm, 5-10K WOB, 55 spm, 233 gpm, 3000 psi SPP on btm, 2650 psi SPP of btm, 4K TQ on, 3K TQ off btm. 11.7 ppg avg ECD per PWD. Added 600 bbls fresh BaradrilN mud at 12200'. 7/1/2001 00:00 - 06:00 6.00 DRILL P PROD3 Drill ahead 13543 to 13850 TD OA lateral L-2 per wellsite geologist. Add 300 bbls new BaradrilN mud AT~ 13600'. 140k PUW, 85k SOW, 112 ROTW, TQ on/off 5k/3k ft-lbf, 54 spm, 230 gpm, 2-10k WOB. 06:00 - 07:30 1.50 DRILL P PROD3 Pump weighted, hi-vis sweep. 07:30 - 21:00 13.50 DRILL P PROD3 POOH, pumping out, 13850-9929'. LD MWD, PWD, Gamma, RES, float sub, motor, & bit. 20:00 - 21:00 1.00 DRILL P PROD3 MU 6 1/8" hole opener, stabilizer, DC, stabilizer, 2-DC, 2-HWDP BHA. 21:00 - 23:30 2.50 DRILL P PROD3 TIH w/BHA on 3 1/2" DP. 23:30- 00:00 0.50 DRILL P PROD3 Ream 10149-10424. 130 PUW, 102 SOW, 112 ROTW, 63 spm, 255 gpm, 100 rpm, 2100 psi SPP, 3K ft-lbf rotary torque. 71212001 00:00 - 12:30 12.50 DRILL P PROD3 Ream w/6 1/8" hole opener assembly 10424'-13850'. 130k PUW, 90K SOW, 115K RoTW, 3K fi-lbf torque. At 12056, 12848, 13436 torque increased to 5K. 12:30 - 14:30 2.00 DRILL P PROD3 Circ & condition mud. Monitor well for 10 mins. Spot 300 bbls new 9.1 ppg BaradrilN w/7 % lubricant on btm. 14:30 - 17:30 3.00 DRILL P PROD3 Pump out of hole through window to 10059'. Circulate 2% EP mud lube into system. 17:30 - 19:00 1.50 DRILL P PROD3 Circ & condition mud. Monitor well for 10 mins. 19:00 - 00:00 5.00 DRILL P PROD3 Pump out of hole 10 stands, check for swabbing-OK, pump dry Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1'5 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/2/2001 19:00 - 00:00 5.00 DRILL P PROD3 job, & TOOH. Log PU & SOW every 1000'. POOH to 2700' at midnight report time. 7/3/2001 00:00 - 05:00 5.00 DRILL P PROD3 POOH slowly to BHA. Monitor well for 10 mins. LD hole opener BHA. Clear floor, MU whipstock retrieval BHA. 05:00 - 09:30 4.50 DRILL P PROD3 RIH w/whipstock retrieving BHA, 4 stds HWDP, and 3 112" DP to 10038'. 109:30 - 11:30 2.00 DRILL P PROD3 Slip & cut 96' of drillling line. Service top drive. 11:30 - 12:00 0.50 DRILL P PROD3 Orient hook to Iow-side of hole w/Sperry MWD 12:00 - 21:00 9.00 DRILL P PROD3 Latch onto whipstock slot w/hook retrieving tool. Pull and jar. Whipstock came free w/70K pull over string weight. POOH 'slowly w/whipstock. LD 12 jts HVVDP, jars, bumper sub, collar. 21:00 - 22:30 1.50 DRILL P PROD3 Download MWD, LD MWD, .PWD, FS, 1 jt HWDP, retrieving hook, whipstock, subs, 9 jts of 3 1/2" DP. 22:30 - 23:30 1.00 DRILL P PROD3 Clear rig floor rig up casing running equipment. Function test blind rams. 23:30 - 00:00 0.50 DRILL P PROD3 Pre-job safety & planning meeting w/rig crew and service personnel. 7/4/2001 00:00 - 07:30 7.50 CASE P PROD3 RIH w/4 1/2" guide shoe, shoe jt, pack-off bushing, 75 jts 4 1/2", 12.6#, L80 slotted liner, 14 jts solid liner. Set casing on elevators on rotary table. 07:30 - 14:00 6.50 CASE P PROD3 Rig up slip bowl assembly & RIH inside 4 1/2" liner assembly w/stinger & 112 jts inner string( 2 7/8" FOX). Space out inner sting to bushing. MU Baker hook-wall hanger assembly w/ tension lock swivel. 14:00 - 16:30 2.50 CASE P PROD3 RIH to 10098 top of 7" casing window for O^ lateral L-2. (Window depth 10091-10103'). 16:30 - 23:00 6.50 CASE N DPRB PROD3 Attempt to exit window with bent shoe joint (10" offset from axis, bend in mid-jt). Set down at liner top 10420' (OA L1 lateral). Stood back 4 stands and made 20 attempts to exit using tension lock swivel to effect rotation of liner shoe joint in 15 degree increments. Attempted rotation & torque monitoring at mid-window depth while lowering assembly through window depth and set down at lower liner top each attempt at 10420'. (Top sleeve allows ~6' of travel to guide shoe). 23:00 - 00:00 1.00 CASE N DPRB PROD3 CBU & review options w/ODE Campbell. 7/5/2001 00:00 - 00:30 0.50 CASE N DPRB PROD3 Circulate bottoms up. Crew change- pre-job safety and planning meeting. Monitor well. 00:30 - 05:00 4.50 CASE N DPRB PROD3 Pull 5 stands above window. Lowered guide shoe and bent joint to window depth and attempted to exit. 5 attempts and each time set back down on previous liner top at 10420'. 130K PUW, 110 SOW. 05:00 - 06:30 1.50 CASE N DPRB PROD3 CBU & monitor well for 10 mins. 06:30 - 10:30 4.00 CASE N DPRB PROD3 POOH 10050' to 7786' slowly due to swabbing. 10:30 - 11:00 0.50 CASE N DPRB PROD3 Circulate bottoms up. 11:00 - 16:00 5.00 CASE N DPRB PROD3 POOH rom 7786' to liner hanger assembly. LD Tension lock swivel. 16:00 - 16:30 0.50 CASE N DPRB PROD3 Service top drive & grease crown. 16:30 - 00:00 7.50 CASE N DPRB PROD3 RIH w/liner hanger assy. Rotate incremental 1/2 turns at surface, work out torque down drill string, and make 16 attempts to exit window w/guide shoe and 4 1/2" bent joint Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 16 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours !Activity Code NPT Phase Description of Operations 7/5/2001 16:30 - 00:00 7.50 CASE N DPRB PROD3 liner. Make one attempt by pulling assy up slowly across window depth at 8 RPM and attempt to "catch" window while observing torque. 2500-3500 fi-lb "bobble" on torque indicator. Lower assembly & tag top of previous liner. PU 1 stand off 3revious liner and conduct "base-line" torque reading test at 8 rpm surface rotation-2500 ft-lbf. Pull 4 stands (1 stand above window depth) & make multiple attempts by rotating 1 1/2 turns drillpipe at surface. Work torque down drillstring & liner & attempt to lower through window. All attempts resulted in setting down at 10420' prior liner top on the 4th stand of pipe. 7/6/2001 00:00 - 08:00 8.00 CASE N DPRB PROD3 Attempt to work 4 1/2" liner through 7" casing window. Multiple trips from 10088' to 10420' orienting, rotating 1/2 turn at sfc on each attempt and working torque down the drill string. Increased rotations to 1 1/2 times. Attempted to rotate 8 rpms at surface while lowering guide shoe/bent jt assy past casing window. Saw torque increase from 2500 up to 3500 fi-lbs at window depth. After several attempts this torque indication ceased. 08:00 - 10:00 2.00 CASE N DPRB PROD3 Circulate bottoms up & monitor well for 10 rains. 10:00 - 11:00 1.00 CASE N DPRB PROD3 POOH 5 stands. Monitor well for 10 rains. Pump "dry job", blow-down top drive & mud line. 11:00 - 15:00 4.00 CASE N DPRB PROD3 POOH w/3 1/2" DP to hookwall liner hanger assy. Monitor well for effects of swabbing. 15:00 - 17:00 2.00 CASE N DPRB PROD3 Change out bales. Lay-down liner hanger assy. 17:00 - 23:30 6.50 CASE N DPRB PROD3 Lay down 70 joints 2 7/8" FOX inner string, xo's, ball seat, catcher, & slick stinger. 23:30 - 00:00 0.50 CASE N DPRB PROD3 Rig up 4 1/2" handling tools, clear rig floor, crew change, & prepare to lay-down 4 1/2" liner & assembly. 7/7/2001 00:00 - 01:00 1.00 CASE N DPRB PROD3 Cont. servicing toP drive. 01:00 - 05:00 4.00 CASE N DPRB PROD3 Laydown 14 joints 4 1/2" solid liner, 75 jts solid liner, pack-off bushing, bent joint, and guide shoe. Guide shoe had minor scrapes on its nose. Joints #38 & 56 were slightly bent. Some stop collars came loose. 05:00 - 06:00 1.00 CASE N DPRB PROD3 Clear floor, pull wear ring, install test plug below BOP, fill stack and choke manifold. 06:00 - 12:00 6.00 CASE P PROD3 Test HCR, Hydril, choke manifold, TIW valve, Dart, Upper & Lower pipe rams, Blind rams, manual choke & kill valves to 250 psi Iow and 2500 psi high. BOP test witnessing waived by AOGCC John Spaulding. Remove test plug, rig-down test assy, install wear ring, blow down and line up choke manifold, clear rig floor. 12:00 - 17:30 5.50 CASE N DPRB PROD3 Made up guide shoe & bent jt(16' from center w/10" offset from axis) float sub, and MWD collar. TIH on 3 1/2" DP. 17:30 - 18:00 0.50 DRILL N DPRB PROD3 Checked toolface w/MWD. 135 deg left of high side. Made qtr turn, tool face was erratic from 180-270. Worked pipe w! tool face changing continuously. Lowered guide showe to window depth w/pumps on and toolface transmitting. Toolface now holding 40 deg left of high-side. Lowerd guideshoe/bent joint through window depth, weight indicator showed 10K loss. TIH 10725 indicating successful window exit. 18:00 - 19:00 1.00 DRILL N DPRB PROD3 Circulated bottoms up 2500 strokes working pipe. Mud in acceptable condition. 19:00 - 19:30 0.50 DRILL N DPRB PROD3 Pull up above window w/140k PUW with no weight change. Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1,7 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC--41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/7/2001 19:00 - 19:30 0.50 DRILL N DPRB PROD3 Pump up toolface w/234 gpm, 55 spin, 1650 psi SPP. 132 deg right of high side. Move guide shoe across window, lowered no weight loss, no window exit. 19:30 - 20:30 1.00 DRILL N DPRB PROD3 Qtr turn work pipe, lowered and did not exit window. Check toolface at 44 deg left. RIH past top of liner depth to 10450 and confirmed that the assembly again exited the window. 20:30 - 23:00 2.50 DRILL N DPRB PROD3 Pull up above window depth. Pre-job safety and planning meeting held then cut and slip drilling line 101'. 23:00-00:00 1.00 DRILL N DPRB PROD3 Mix 25 bbl dry job at l l .2 ppg. Start POOH w/ 31/2" DP to 9000'. 7/8/2001 '00:00 - 04:30 4.50 CASE N DPRB PROD3 TOOH w/3 1/2" DP. LD MWD collar & float sub. 04:30 - 05:30 1.00 CASE N DPRB PROD3 Change-out elevators & rig-up 4 1/2" handling tools 05:30 - 09:30 4.00 CASE N DPRB PROD3 RIH w/4 1/2" guide shoe, bent joint, pack-off bushing, 75 joints slotted liner, 14 joints solid liner. Set liner in elevators on rotary table. Tie-off handles. 09:30 - 15:30 6.00 CASE N DPRB PROD3 RU handling tools, tongs, elevators for 2 7/8" FOX. RIH w slick stinger on 112 its 2 7/8" FOX tubing & space-out. 15:30 - 16:30 1.00 CASE N DPRB PROD3 MU 4 1/2"x 7" Hook-wall Liner Hanger Assembly to FOX tubing & 4 1/2" liner w/runningtool. 16:30 - 18:30 2.00 CASE N DPRB PROD3 RIH w/liner assembly on 3 1/2" DP to window depth at 110091-10103'. 18:30 - 20:00 1.50 CASE N DPRB PROD3 Make 3 attempts at lowering guide shoe & bent joint through the casing window. Each time the string was rotated and torque was worked down the drillstring via pipe movement. Weight indicator was monitored for indications of window exit. Set down twice on the previous top of liner at 10420'. On the 3rd attempt the assembly went out the window and into open hole. 20:00 - 21:30 1.50 CASE P PROD3 PUW at 150K, SOW at 110K. Lowered liner assembly into open hole and set hook on lower edge of casing window w/20K slack-off weight. 21:30 - 23:00 1.50 CASE P PROD3 Pumping down drill string at 1 bpm to clear DP, inner string, and stinger. Good circulation & returns. Dropped ball & displaced to seat. Pressured up to 2500 psi to hydraulic release hanger &collet. Picked up off hanger and set back down. Pressured up to 3600 psi to blow out ball into catcher and open circulating port. PUW 140K. Top of liner-10085 ft. Btm of liner-13668 ft. 23:00 - 00:00 1.00 CASE P PROD3 Started pulling stinger out of bushing slowly. Continued slow pull until cross-overs cleared inner diameter of liner hanger. Continue pulling out of hole with 3 1/2" drillpipe. 7/9/2001 00:00 - 01:30 1.50 CASE P PROD3 POOH w/3 1/2" DP to 10070'. Monitor well f/10 mins. 01:30 - 04:00 2.50 CASE P PROD3 Pump 25 bbls 11.2# weighted slug "dry job". Blow down top drive & mud line. Continue POOH. 04:00 - 10:30 6.50 CASE P PROD3 LD liner running tool. RU handling tools and lay-down 112 jts 2 7/8" FOX tubing. RD handling tools. 10:30 - 11:00 0.50 CASE P PROD3 Lay-down Baker slick stinger assy. 11:00 - 14:30 3.50 TA N DPRB COMP PU Baker 7 inch RBP. RIH on 3 1/2" DP to 4268'. Down drag increasing & fluid level dropping. Hole being "surged" while TIH. Monitor well. Printed: 7/23/2001 11:49:12AM BP EXPLORATION Page 18 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 7/9/2001 14:30 - 17:30 3.00 TA N DPRB COMP Pump 25 bbl, 11.2 ppg, weighted slug. Blow down top drive & mud line. POOH w/7" RBP. Monitor. 17:30 - 21:30 4.00 TA N DPRB COMP MU 7" csg scraper, bit sub, & bit. & TIH. 21:30 - 23:30 2.00 TA N DPRB COMP Circulate wellbore & condition mud. Mud in 37vis & 9.1 ppg. Mud out 57 vis 9.4 out. Started centrifuge Conditioned to 9.1 ppg & 40 vis out. (Mud was loaded up w/CaCO3 after multiple "dry jobs" pumped prior to TOOH). 23:30 - 00:00 0.50 TA N DPRB COMP Start POOH w/scraper assy. 7/10/2001 00:00 - 04:30 4.50 DRILL N DPRB PROD1 POH with 7" casing scraper and 6" bit. 04:30- 05:00 0.50 DRILL N DPRB PROD1 Service rig. 05:00 - 09:00 4.00 TA N DPRB COMP Make up 7" Baker Retrievable Bribge Plug (RBP) on 3 1/'2" drill pipe and RIH to 9100'. RBP taking weight and forcing mud into the formation. 09:00 - 10:00 1.00 TA P COMP Drop 1 7/16" ball and pump down same. Pressure up to 2000 psi, pull 15K over pull and set RBP at 9060'. 10:00 - 10:30 0.50 T^ P COMP Test RBP to 2500 psi for 10 minutes and record on chart. 10:30 - 15:30 5.00 TA P COMP Drop 2" ball to open ports in circulating sub. Displace mud in hole with 8.5 ppg sea water. 15:30 - 17:30 2.00 TA P COMP Displace 8.5 ppg Sea WaterTo 9.1 ppg KCL Brine 17:30 - 00:00 6.50 TA P COMP POH Laying Down (294 Joints) 3 1/2" Drill Pipe - Lay Down Baker Model "J" Setting Assembly & Clear Rig Floor 7/11/2001 00:00 - 02:30 2.50 DRILL P PROD3 RIH With 3 1/2" Drill Pipe From Mast 02:30 - 07:00 4.50 DRILL P PROD3 POH Laying Down 3 1/2" Drill Pipe 07:00 - 07:30 0.50 DRILL P PROD3 Pull Wear Ring And Install Test Plug 07:30 - 09:30 2.00 TA P COMP Hold Pre Job Safety Meeting - Remove 3 1/2" X 6" Variable Rams From Top Pipe Ram Profile And Install 2 7/8" Rams - Test @ 2500 Psi. For 10 Minutes 09:30 - 10:30 1.00 TA P COMP Hold Pre Job Safety Meeting - Rig Up Tools To Run 2 7/8" Tubing 10:30 - 20:00 9.50 TA P COMP Pick Up Baker RPB Model "M" Retrieving Head With Cross Over With 279 Joints Of 2 7/8" EUE (6.4 lb.) L-80 Tubing And RIH 20:00 - 21:00 1.00 T^ P COMP Hold Pre Job Safety Meeting With Rig Crews. Pick Up FMC Tubing Hanger - Install TWC And Blanking Plugs - Make Up Hanger & Landing Joint - Top Drive And Traveling Blocks Weight At 70K - Completion String And Top Drive & Blocks Up Weight At 98K And Down Weight At 90K 21:00 - 23:00 2.00 TA P COMP Drain BOP Stack - Land 2 7/8" Tubing Completion String In Tubing Spool- Energize Lock Down Studs -Test Two Way Check Valve On Annulus Side @ 1000 Psi. For 10 Minutes - Test Two Way Check Valve From Tubing Side @ 1000 Psi. For 10 Minutes 23:00 - 23:30 0.50 TA P COMP Rig Down Test Equipment & Lay Down Test Joint - Rig Down Tubing Tongs And Equipment - Clear Rig Floor 23:30 - 00:00 0.50 TA P COMP Hold Pre Job Safety Meeting - Change Rams In Top Gate To 3 1/2"X 6" Varaibles - Remove Mouse Hole & Bell Nipple - Prepare To Nipple Down BOP Stack And Related Equipment - Clean Mud System 7/12/2001 00:00 - 03:30 3.50 TA P COMP Continue To Change Rams In Top Gate To 3 1/2"X 6" Variables & Nipple Down BOP And Related Equipment 03:30 - 06:00 2.50 TA P COMP Install FMC Tubing Head Adapter And Cameron 2 9/16" 5M Tree Test Tubing Head Adapter Void Area With FMC At 5000 Psi. (OK) - Install Pump In Flange On Wing Valve - Rig Up Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1'9 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of operations 7/12/2001 03:30 - 06:00 2.50 TA P COMP Circle Chart Recorder - Pressure Test Tree At 5000 Psi. With Rig Test Pump - Rig Up Manifold To Freeze Protect Annulus And Tubing. 06:00 - 09:00 3.00 TA P COMP Pull Two Way Check Valve - Rig Up HB&R & Pump 80 Barrels Diesel Down Annulus & U-Tube Into 2 7/8" Tubing 09:00 - 10:30 1.50 TA P COMP Rig Down HB&R - Remove Second Tubing Head Valve - Install Blind Flange On Manumatic Wing Valve - Install Back Pressure Valve 10:30 - 12:00 1.50 DRILL P COMP Clear Rig Floor Of Cross Overs And Misc. Tools - Nabors Alaska Drilling Rig 22E Released From MPC-41 @ 1200 Hours On 7/12/2001 Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page I of 1 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: COMPLETION Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 4ES Rig Number: Date FrOm- To Hours ActivityCode NPT phase Description of Operations I 7/15/2001 06:00 - 09:00 3.00 MOB P PRE MOVE FROM E-13A TO MPC-41. 09:00 - 10:00 1.00 RIGU P PRE RAISE & SCOPE DERRICK. 10:00 - 12:30 2.50 RIGU P PRE SET AND BERM TIGER TANK. RIG UP AND TEST HARDLINES AND HCR TO TREE. LOAD PITS W/9.1 BRINE. ~ 12:30 - 13:00 0.50 RIGU P PRE PRESSURE TEST ALL LINES TO TREE & TANK. 13:00 - 14:00 1.00 KILL P DECOMP PRE-COMPLETION MEETING. PULL BP¥. 14:00 - 16:00 2.00 KILL P DECOMP CIRCULATE DIESEL FROM WELL. MONITOR RETURNS. 9.1#. 16:00 - 17:00 1.00 PULL P DECOMP ND TREE. 17:00 - 19:30 2.50 PULL .P DECOMP NU BOPE. 19:30 - 20:30 1.00 PULL P DECOMP TEST BOPE STACK 250~3500 PER BP/AOGCC REQUIREMENTS. RIGHT TO WITNESS WAIVED BY AOGCC...C. SHEVE 20:30 - 21:30 1.00 PULL P DECOMP PU LUB. PULL TWC. LD LUB. 21:30 - 22:30 1.00 PULL P DECOMP MU LJ. BOLDS. PU HANGER & TBG. PU WT 36K#. BO & LD HANGER. 22:30 - 23:00 0.50 PULL P DECOMP RUN 10 JTS TBG IN HOLE. SET DOWN 10K ON RBP. LATCH UP. 23:00 - 00:00 1.00 PULL P DECOMP CIRCULATE HOLE VOL WITH 9.1# BRINE. 711612001 00:00 - 00:30 0.50 REST P DECOMP MONITOR WELL. VERY SLIGHT FLOW FROM ANNULUS. TBG DEAD. 00:30 - 01:30 1.00 REST P DECOMP START POOH WI5 STDS. STOP FLOW CHECK WELL. STILL SLIGHT FLOW FROM WELL. RIH WI5 STDS. PREP TO WT UP. 01:30 - 04:00 2.50 REST P DECOMP WT UP FROM 9.1# TO 9.3#. MONITOR WELL. WELL DEAD. 04:00 - 09:00 5.00 REST P DECOMP START POOH WITH 2 7/8" TBG AND RBP. 09:00 - 11:30 2.50 P COMP OOH W/RBP. CLEAR FLOOR. RU TO RUN ESP. ATTACH CABLE & SECURE TO ESP. 11:30 - 15:30 4.00 RUNCOI~F' COMP 2-7/8" TIH W/ESP TO 6100-FT. INSTALL LASALLE CLAMPS EVERY COLLAR. 15:30 - 18:30 3.00 RUNCOItP COMP CHANGE OUT REEL & SPLICE CABLE. 18:30 - 21:00 2.50 RUNCOItF' COMP CONTINUE TIH WELL, 231 JTS TIH. MU GLM W/DUMMY. INSTALL LASALLE CLAMPS EVERY OTHER COLLAR. 21:00 - 21:30 0.50 RUNCOItF' COMP MU CAMCO GLM W/DPSOV INSTALLED. MU HANGER & LJ. INSTALL PENETRATOR. 21:30 - 23:00 1.50 RUNCOItF) COMP SPLICE EFT CONNECTOR. TEST GOOD. 23:00-23:30 0.50 RUNCOr~P COMP POW=48K. SOW= 29K. LAND HANGER, RILDS, INSTALL & TEST TWC. 23:30 - 00:00 0.50 RUNCOI~F' COMP ND BOPE STACK. 7/17/2001 00:00 - 01:00 1.00 BOPSUR P COMP REMOVE BOPE. 01:00 - 02:00 1.00 WHSUR P COMP INSTALL X-MASS TREE. TEST HANGER SEALs AND TREE TO 5,000 PSI. GOOD. 02:00 - 03:00 1.00 WHSUR P COMP RU LUBRICATOR. PULL TWC. SET BPV. FINAL ESP CHECK. GOOD. SECURE WELL. RELEASE RIG. Printed: 7/23/2001 11:08:46 AM I MILNE POINT, ALASKA WELL TELEX TO: Bixby/Smith Date: 17/18/01 FROM: Dale DeYonge Operational Cost: Well Name: I MPC-41 I HB&R $1040.00 Main Category: [DRLG J Diesel $ 945.00 Sub Category: I Freeze protect I Operation Date: 17117101 J Total $1945.00 Objective: To freeze protect Well after DRLG completion Operation: HB&R pumped 15 BBLS diesel down the tubing at 1 bpm and 65 bbls of dead crude down the IA at 1.35 bpm. Conclusion: Well bore is freeze protected Initial WHP: 100 IA: 500 OA: Final WHP: IA: OA: Diesel Used 115 bbls J Methanol Used [0 Diesel = $ 945.00 DRLG / Freeze Protect / Diesel 337243 - 9335-070-765 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPC-41 Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 11,749.70' MD 11,846.51' MD 12,087.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFiNiTiVE Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 Job No. AKZZ11092, Surveyed: 13 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301400 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149° 31' 28.2842" W) DRILL. lNG SER:VIC. ES A Halliburton Company Survey Ref: svy9919 Sperry-Sun Drilling Services Survey Report for MPC-41 Your Ref'. AP1-$00292301400 Job No. AKZZ11092, Surveyed: 13 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) , (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11749.70 90.310 163.190 4371.98 4417.15 9441.91 S 2577.30 E 6019554.93 N 560816.61 E 11846.51 83.350 163.630 4377.33 4422.50 9534.49 S 2604.89 E 6019462.57 N 560844.91 E 11939.05 84.950 166.250 4386.76 4431.93 9623.37 S 2628.80 E 6019373.87 N 560869.52 E 12005.50 89.260 169.990 4390.12 4435.29 9688.29 S 2642.45 E 6019309.06 N 560883.68 E 12087.00 89.260 169.990 4:~91.17 4436.34 9768.54 S 2656.62 E 6019228.92 N 560898.48 E 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 26.307° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calbulated along an Azimuth of 164.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12087.00ft., The Bottom Hole Displacement is 10123.34ft., in the Direction of 164.786° (True). Dogleg Rate (°/100ft) 7.204 3.305 8.582 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 9787.34 Tie On Point 9883.92 Window Point 9975.96 10042.19 10123.34 Projected To TD Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (it) (ft) 11749.70 4417.15 9441.91 S 2577.30 E 11846.51 4422.50 9534.49 S 2604.89 E 12087.00 4436.34 9768.54 S 2656.62 E Comment Tie On Point Window Point Projected To TD 14 August, 2001 - 13:01 Page 2 of 3 DrillQuest Z00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 Your Ref: AP1-$00292301400 Job No. AKZZ11092, Surveyed: 13 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Survey tool program for MPC-41 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 12087.00 4436.34 Survey Tool Description AK-6 BP_IFR-AK (MPC-41 PB1) 14 August, 2001 - 13:01 Page 3 of 3 DrillQuest 2.00.08.005 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-41 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 11,749.7O' MD 11,846.51' MD 12,087.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 20 2001 Ala~,a Oil & Gas Cons. Commissior~ Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 MWD Job No. AKMM10166, Surveyed: 13 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301400 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149°31'28.2842"W) DRILLING SERVICES Survey Ref: svy9924 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 MWD Your Ref: API-500292301400 Job No. AKMM10166, Surveyed: 13 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11749.70 90.310 163.750 4371.99 4417.16 9428.59 S 2619.97 E 6019568.59 N 560859.17 E 11846.51 83.350 164.220 4377.34 4422.51 9521.44 S 2646.62 E 6019475.95 N 560886.55 E 11939.05 84.950 168.190 4386.78 4431.95 9610.82 S 2668.56 E 6019386.74 N 560909.19 E 12005.50 89.260 170.680 4390.13 4435.30 9676.04 S 2680.73 E 6019321.61 N 560921.86 E 12087.00 89.260 170.680 4391.19 4436.36 9756.46 S 2693.92 E 6019241.30 N 560935.69 E 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 26.307° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from Well and calculated along an Azimuth of 164.760° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 12087.00ft., The Bottom Hole Displacement is 10121.55ft., in the Direction of 164.564° (True). Dogleg Rate (°/100ft) 7.206 4.604 7.488 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 9785.71 Tie On Point 9882.30 Window Point 9974.31 10040.43 10121.49 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11749.70 4417.16 9428.59 S 2619.97 E 11846.51 4422.51 9521.44 S 2646.62 E 12087.00 4436.36 9756.46 S 2693.92 E Comment Tie On Point Window Point Projected Survey 14 August, 2001 - 13:00 Page 2 of 3 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 MWD Your Ref: API-500292301400 Job No. AKMM10166, Surveyed: 13 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Survey tool program for MPC-41 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12087.00 4436.36 Survey Tool Description MWD Magnetic (MPC-41 PB1 MWD) 14 August, 2001 - 13:00 Page 3 of 3 DrillQuest Z00.08.005 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPC-41 PB2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,550.00' MD 8,646.88' MD 12,205.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 PB2 Job No. AKZZ11092, Surveyed: 13 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301471 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149° 31' 28.2842" W) DRILLING SERVICES Survey Ref: svy9918 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 PB2 Your Ref: API-500292301471 Job No. AKZZ11092, Surveyed: 13 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8550.00 74.380 159.260 3764.39 3809.56 8646.88 70.290 159.500 3793.78 3838.95 8740.97 73.470 161.490 3823.05 3868.22 8835.19 76.140 163.010 3847.74 3892.91 8929.15 76.320 162.600 3870.10 3915.27 9023.21 76.320 162.370 3892.35 3937.52 9116.74 76.270 161.730 3914.51 3959.68 9211.54 74.860 163.320 3938,14 3983.31 9305.11 74.410 163.200 3962.94 4008.11 9398,92 74.020 163.410 3988.45 4033.62 9493.38 73.460 163.000 4014.90 4060.07 9587.06 73.770 163.590 4041.33 4086.50 9678.51 73.970 163.690 4066.74 4111.91 9772.69 73.600 162.890 4093.04 4138.21 9867.74 75.310 163.970 4118.51 4163.68 9962.08 75.560 163.430 4142.23 4187.40 10056.52 75.170 164.190 4166.09 4211.26 10150.70 74.740 163.130 4190.54 4235.71 10244.18 74.300 162.810 4215.49 4260.66 10337.75 76.590 163.930 4239.01 4284.18 10431.94 76.090 163.070 4261.25 4306.42 10524.14 77.900 164.310 4282.00 4327.17 10618.91 81.040 164.980 4299.32 4344.49 10712.53 81.160 163.920 4313.80 4358.97 10806.69 83.330 164.330 4326.50 4371.67 10900.55 85.130 164.650 4335.94 4381.11 10994.67 86.490 164.720 4342.82 4387.99 11087.82 86.920 164.430 4348.17 4393.34 11162.50 87.480 165.400 4351.82 4396.99 11285.86 87.110 165.670 4357.64 4402.81 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6446.42 S 1689.70 E 6022543.39 N 559905.60 E 6532.80 S 1722.20 E 6022457.27 N 559938.78 E 6617.08 S 1752.04 E 6022373.22 N 559969.28 E 6703.67 S 1779.75 E 6022286.85 N 559997.67 E 6790.85 S 1806.73 E 6022199.88 N 560025.32 E 6878.00 S 1834.24 E 6022112.95 N 560053.51 E 6964.44 S 1862.24 E 6022026.73 N 560082.19 E 7052.01 S 1889.81 E 6021939.38 N 560110.44 E 7138.41 S 1915.80 E 6021853.18 N 560137.11 E 7224.88 S 1941.73 E 6021766.92 N 560163.72 E 7311.69 S 1967.93 E 6021680.32 N 560190.60 E 7397.77 S 1993.77 E 6021594.44 N 560217.10 E 7482.06 S 2018.51E 6021510.34 N 560242.51E 7568.68 S 2044.51 E 6021423.94 N 560269.18 E 7656.45 S 2070.62 E 6021336.38 N 560295.98 E 7744.08 S 2096.25 E 6021248.94 N 560322.29 E 7831.83 S 2121.73 E 6021161.39 N 560348.46 E 7919.11 S 2147.32 E 6021074.32 N 560374.72E 8005.25 S 2173.70 E 6020988.39 N 560401.78 E 8092.02 S 2199.61 E 6020901.82 N 560428.37 E 8179.78 S 2225.61 E 6020814.27 N 560455.05 E 8265.99 S 2250.83 E 6020728.26 N 560480.95 E 8355.83 S 2275.50 E 6020638.61 N 560506.32 E 8444.94 S 2300.29 E 6020549.71 N 560531.81 E 8534.67 S 2325.81 E 6020460.17 N 560558.03 E 8624.65 S 2350.78 E 6020370.39 N 560583.70 E 8715.18 S 2375.57 E 6020280.05 N 560609.20 E 8804.83 S 2400.31 E 6020190.60 N 560634.64 E 8876.85 S 2419.72E 6020118.74 N 560654.61E 8996.17 S 2450.50 E 6019999.67 N 560686.32 E Dogleg Rate (°/100ft) 4.228 3.932 3.233 0.465 0.238 0.667 2.202 0.497 0.468 0.725 0.689 0.243 0.905 2.106 0.614 0.881 1.179 0.575 2.7O8 1.034 2.360 3.385 1.126 2.345 1.948 1.447 0.557 1.498 0.371 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 6663.74 Tie On Point 6755.64 Window Point 6844.81 6935.65 7026.86 7118.19 7208.96 7300.70 7390.90 7481.14 7571.80 7661.65 7749.48 7839.89 7931.44 8022.73 8114.10 8205.04 8295.O9 8385.62 8477.13 8566.95 8660.11 8752.60 8845.89 8939.27 9033.13 9126.13 9200.72 9323.93 14 August, 2001 - 13:01 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB2 Your Ref: API-500292301471 Job No. AKZZ11092, Surveyed: 13 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11381.83 85.510 164.140 4363.82 4408.99 9088.63 S 2475.44 E 6019907.40 N 560711.98 E 11475.06 89.450 164.570 4367.92 4413.09 9178.30 S 2500.55 E 6019817.93 N 560737.80 E 11564.71 90.120 164.790 4368.25 4413.42 9264.76 S 2524.24 E 6019731.66 N 560762.16 E 11659.17 87.480 162.640 4370.23 4415.40 9355.40 S 2550.71 E 6019641.23 N 560789.34 E 11749.70 90.310 163.190 4371.98 4417.15 9441.91 S 2577.30 E 6019554.93 N 560816.61 E 11845.52 90.980 160.400 4370.90 4416.07 9532.92 S 2607.23 E 6019464.16 N 560847.25 E 11935.26 96.170 164.660 4365.30 4410.47 9618.30 S 2634.11 E 6019378.99 N 560874.80 E 12032.47 96.540 164.090 4354.54 4399.71 9711.34 S 2660.14 E 6019286.15 N 560901.55 E 12118.23 88.090 162.140 4351.08 4396.25 9793.26 S 2685.00 E 6019204.44 N 560927.06 E 12205.00 88.090 162.140 4353.97 4399.14 9875.80 S 2711.60 E 6019122.10 N 560954.30 E 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 26.308° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 164,647° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12205.00ft., The Bottom Hole Displacement is 10241.30ft., in the Direction of 164.647° (True). Dogleg Rate (°/100ft) 2.304 4.251 0.787 3.604 3.184 2.994 7.475 0.696 10.111 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 9419.69 9512.81 9602.46 9696.87 9787.33 9883.02 9972.47 10069.08 10154.66 10241.30 Projected To TD 14 August, 2001 - 13:01 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling ServiCes Survey Report for MPC-41 PB2 Your Ref: API-500292301471 Job No. AKZZ11092, Surveyed: 13 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8550.00 3809.56 6446.42 S 1689.70 E 8646.88 3838.95 6532.80 S 1722.20 E 12205.00 4399.14 9875.80 S 2711.60 E Comment Tie On Point Window Point Projected To TD Survey tool program for MPC-41 PB2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12205.00 4399.14 Survey Tool Description AK-6 BP_IFR-AK (MPC-41 PB1) 14 August, 2001 - 13:01 Page 4 of 4 DrillQuest Z00.08.005 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-41 PB2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,550.00' MD 8,646.88' MD 12,205.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU6 20 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 PB2 MWD Job No. AKMM10166, Surveyed: 13 June, 2001 SURVEY REPORT 14 August, 2001 Your Reft API-500292301471 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, 149° 31' 28.2842" W) Kelly Bushing: 45.17ft above Mean Sea Level DRILLING SERVIC'ES Survey Ref: s vy9923 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 PB2 MWD Your Ref: API-500292301471 Job No. AKMM10166, Surveyed: 13 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8550.00 74.380 159.260 3764.40 3809.57 8646.88 70.290 159.450 3793.79 3838.96 8740.97 73.470 161.290 3823.05 3868.22 8835.19 76.140 162.660 3847.75 3892.92 8929.15 76.320 162.970 3870.11 3915.28 9023.21 76.320 162.850 3892.36 3937.53 9116.74 76.270 161.500 3914.52 3959.69 9211.54 74.860 162.590 3938.15 3983.32 9305.11 74.410 162.790 3962.94 4008.11 9398.92 74.020 164.380 3988.46 4033.63 9493.38 73.460 162.970 4014.91 4060.08 9587.06 73.770 163.630 4041.34 4086.51 9678.51 73.970 164.070 4066.75 4111.92 9772.69 73.600 162.420 4093.05 4138.22 9867.74 75.310 163.710 4118.52 4163.69 9962.08 75.560 164.140 4142.25 4187.42 10056.52 75.170 164.810 4166.11 4211.28 10150.70 74.740 164.190 4190.55 4235.72 10244.18 74.300 163.150 4215.50 4260.67 10337.75 76.590 164.630 4239.02 4284.19 10431.94 76.090 163.220 4261.26 4306.43 10524.14 77.900 164.800 4282.01 4327.18 10618.91 81.040 165.040 4299.33 4344.50 10712.53 81.160 164.540 4313.81 4358.98 10806.69 83.330 164.760 4326.52 4371.69 10900.55 85.130 164.520 4335.95 4381.12 10994.67 86.490 165.590 4342.83 4388.00 11087.82 86.920 164,600 4348.19 4393.36 11162.50 87.480 163.640 4351.83 4397.00 11285.86 87.110 165.670 4357.66 4402.83 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (fi) (fi) (ft) 6430.34 S 1742.19 E 6022559.87 N - 559957.97 E 6516.71 S 1774.73 E 6022473.77 N 559991.18 E 6600,92 S 1804.76 E 6022389.79 N 560021.86 E 6687.38 S 1832.88 E 6022303.55 N 560050.67 E 6774.56 S 1859.85 E 6022216.58 N 560078.31 E 6861.92 S 1886.70 E 6022129.44 N 560105.85 E 6948.42 S 1914.52 E 6022043,16 N 560134.34 E 7035.75S 1942.82 E 6021956.05 N 560163.33 E 7121.89 S 1969,67 E 6021870.12 N 560190.84 E 7208.48 S 1995.18 E 6021783.74 N 560217.03 E 7295.50 S 2020.66 E 6021696.91N 560243.20 E 7381.59 S 2046.49 E 6021611.04 N 560269.70E 7465.97 S 2070.93 E 6021526.85 N 560294.79 E 7552.56 S 2096.99 E 6021440.46 N 560321.54 E 7640.16 S 2123.66 E 6021353.07 N 560348.89 E 7727.90 S 2148.94 E 6021265.54 N 560374.86 E 7815.94 S 2173.40 E 6021177.69 N 560400.00 E 7903.58 S 2197.71E 6021090.24 N 560424.99 E 7990.04 S 2223.04E 6021003.99 N 560451.00 E 8077.04 S 2248.16 E 6020917.18 N 560476.80 E 8164.98 S 2273.50 E 6020829.44N 560502.83 E 8251.34 S 2298,24 E 6020743.28 N 560528.24 E 8341.29 S 2322,48 E 6020653.52 N 560553.18 E 8430.55 S 2346,74E 6020564.46 N 560578.15 E 8520.51 S 2371.44E 6020474.69 N 560603.54 E 8610.56 S 2396.17 E 6020384.84N 560628.98 E 8701.25 S 2420.38 E 6020294.34N 560653.90 E 8791.11 S 2444.30 E 6020204.67 N 560678.52 E 8862.85 S 2464.71 E 6020133.09 N 560699.49 E 8981.68 S 2497.32 E 6020014.52 N 560733.03 E Dogleg Rate (°/100ft) 4.226 3.857 3.162 0.373 0.124 1.403 1.858 0.523 1.683 1.551 0.753 0.511 1.728 2.224 0.515 0.801 0.783 1.171 2.887 1.548 2.577 3.323 0.543 2.316 1.935 1.837 1.157 1.487 1.671 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 6662.16 Tie On Point 6754.05 Window Point 6843.19 6934.00 7025.21 7116.55 7207.32 7299.02 7389.19 7479.44 7570.10 7659.95 7747.79 7838.18 7929.71 8021.01 8112.38 8203.33 8293.41 8383.95 8475.47 8565.29 8658.45 8750.94 8844.23 8937.61 9031.48 9124.47 9199.06 9322.27 14 August, 2001 - 13:00 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB2 MWD Your Ref: API-500292301471 Job No. AKMM10166, Surveyed: 13 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global COordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11381.83 85.510 164.560 4363.83 4409.00 9074.23 S 2521.92 E 6019922.16 N 560758.35 E 11475.06 89.450 165.420 4367.93 4413.10 9164.17 S 2546.03 E 6019832.41 N 560783.17 E 11564.71 90,120 165.300 4368.27 4413.44 9250.91 S 2568.69 E 6019745.85 N 560806.50 E 11659.17 87.480 163.260 4370.25 4415.42 9341.81 S 2594.27 E 6019655.16 N 560832.80 E 11749.70 90.310 163.750 4371.99 4417.16 9428.59 S 2619.97 E 6019568.59 N 560859,17 E 11845.52 90.980 159.980 4370.91 4416.08 9519.62 S 2649.79 E 6019477.79 N 560889.70 E 11935.26 96.170 164.940 4365.32 4410.49 9604.96 S 2676.77 E 6019392.66 N 560917.35 E 12032.47 96.540 164.100 4354.56 4399.73 9698.07 S 2702.56 E 6019299.75 N 560943.86 E 12118.23 88.090 162.670 4351.09 4396.26 9780.11 S 2727.04 E 6019217.91 N 560968.99 E 12205.00 88.090 162.670 4353.99 4399.16 9862.89 S 2752.87 E 6019135.33 N 560995.47 E 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 26.307° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 164.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12205.00ft., The Bottom Hole Displacement is 10239.87ft., in the Direction of 164.405° (True). Dogleg Rate (°/100ft) 2.028 4.325 0.759 3.532 3.173 3.996 7.991 0.939 9.993 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 9418.04 9511.16 9600.80 9695.22 9785.71 9881.38 9970.81 1 OO67.42 10153.01 10239.67 Projected Survey 14 August, 2001 - 13:00 Page 3 of 4 DrillQuest 2. 00.08. 005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB2 MWD Your Ref: API-500292301471 Job No. AKMM10166, Surveyed: 13 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8550.00 3809.57 6430.34 S 1742.19 E 8646.88 3838.96 6516.71 S 1774.73 E 12205.00 4399.16 9862.89 S 2752.87 E Comment Tie On Point Window Point Projected Survey Survey tool program for MPC-41 PB2 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12205.00 4399.16 Survey Tool Description MWD Magnetic (MPC-41 PB1 MWD) 14 August, 2001 - 13:00 Page 4 of 4 DrillQuest 2.00.08.005 14 -Au g-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPC - 41 PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 8,766.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU6 20 Na~t~ Oil & Gas Goos. Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-4~ MPC-4 ~ PB I Job No. AKT. Zlf092, Surveyed: 2 June, 200f DEFINITIVE SURVEY REPORT 13 August, 2001 Your Ref: API-500292301470 Surface Coordinates: 6028976.39 N, 558~65.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149°31'28.2842"H0 DRILLING SERVICES Survey Ref: svy9917 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 PBI Your Ref: AP!.50029230~470 Job No. AKZZl1092, Surveyed: 2 June, 2001 Milne Point Unit Measured Depth (ft) 0.00 0.000 0.000 228.47 1.090 207.520 316.10 2.980 231.810 407.26 4.690 236.380 494.49 6.440 235.020 584.88 7.970 235.340 675.82 8,910 234.810 762.40 9.350 223.430 859.58 10.770 214.490 953.27 12,150 209,670 Sub-Sea Depth (ft) -45.17 183.29 270.86 361.81 448.63 538.30 628.25 713.74 809.43 901.26 Vertical Depth (ft) 0.00 228.46 316.03 406.98 493.80 583.47 673.42 758.91 854.60 946.43 1043.56 14.110 207.330 989.18 1034.35 1139.79 17.270 198.680 1081.83 1127.00 1233.31 20.680 189.870 1170.27 1215.44 1327.65 23.090 185.650 1257.81 1302.98 1420.31 25.720 179.210 1342.20 1387.37 1513.71 27.450 176.450 1425.72 1470.89 1603,32 28.840 175.420 1504,74 1549.91 1700.76 29.000 174.920 1590.03 1635.20 1794.29 30.400 175,350 1671,27 1716.44 1889.89 33,370 171.550 1752,44 1797.61 1982.69 36.730 171.290 1828.40 1873.57 2076.64 40.380 171.790 1901.86 1947.03 2170.31 45.090 170.330 1970.64 2015.81 2263.84 50.680 169.650 2033.34 2078.51 2357.00 55.450 166.800 2089.31 2134.48 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 6028976.39 N 558165.53 E 1.93 S 1.00 W 6028974.45 N 558164.54 E 4.07 S 3,18 W 6028972.29 N 558162.38 E 7.60 S 8.15 W 6028968.72 N 558157.44 E 12.38 S 15.12 W 6028963.89 N 558150.50 E 18.85 S 24.43 W 6028957.35 N 558141.25 E 26.50 S 35.37 W 6028949.62 N 558130.36 E 35.47 S 45.69 W 6028940.56 N 558120.12 E 48.69 S 56.26 W 6028927.26 N 558109.65 E 64.47 S 66.10 W 6028911.40 N 558099.94 E 82.51 S 75.86 W 6028893.29 N 558090.32 E 106.47 S 85.82 W 6028869.25 N 558080.55 E 135,90 S 93.10 W 6028839.76 N 558073.50 E 170.73 S 97.78 W 6028804.90 N 558069.09 E 208.93 S 99.29 W 6028766.69 N 558067.88 E 250.68 S 97.68W 6028724.95 N 558069.82 E 292.84 S 94.67W 6028682.81N 558073.15 E 339.80 S 90.70W 6028635.89 N 558077.49 E 385.97 S 86.78W 6028589.75 N 558081.77 E 436.10 S 80.95W 6028539.67 N 558087.99 E 488.79 S 73.00 W 6028487.04 N 558096.36 E 546.70 S 64.39 W 6028429.20 N 558105.41 E 609.47 S 54.48 W 6028366.52 N 558115.82 E 677.76 S 42.41 W 6028298.32 N 558128.42 E 750.61 S 27.16 W 6028225.59 N 558144.24 E Dogleg Rate (°/lO0~t) 0.477 2.324 1.904 2.012 1.693 1.037 2.143 2.168 t .792 2.249 4.077 4.753 3.049 4.034 2.275 1.643 0.298 1.514 3.748 3.624 3.899 5.138 6,001 5.673 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 0.00 1.60 3.10 5.20 7.97 11.77 16.27 22.21 32.19 44.83 59.67 80.16 106.65 139.02 175.48 216.19 257.66 304.01 349.59 399.49 452.41 510.55 573.71 642.78 717.07 AK-6 BP_IFR-AK 13 August, 2001.23:49 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 Your Ref: APl.500292301470 Job No. AKZZlI092, Surveyed: 2 June, 2001 Milne Point Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2452.53 60.740 168,280 2139.78 2184.95 2546.19 64.390 167.800 2182.93 2228.10 2639.79 68,050 166,260 2220.67 2265.84 2733.20 72.700 165.920 2252.03 2297.20 2827.28 72.300 166.630 2280,32 2325.49 2921.11 72.690 165.670 2308.55 2353.72 3013.51 73.200 165.230 2335.65 2380.82 3108.12 73.150 164.530 2363.03 2408.20 3202.94 73.200 164.420 2390.48 2435.65 3295.56 73.210 164.050 2417.24 2462.41 3389.32 75.200 161.680 2442.76 2487.93 3483.80 75.370 161.150 2466.76 2511.93 3578.52 75.750 161.300 2490.38 2535.55 3672.80 75.570 160.920 2513.73 2558.90 3766.94 75.510 160.630 2537.24 2582.41 3860.71 75,510 160.130 2560.70 2605.87 3955.05 74.670 161.570 2584.98 2630.15 4048.81 75.110 160.980 2609.42 2654.59 4142.46 75.450 160.770 2633.21 2678.38 4237.62 75.180 162.920 2657,34 2702,51 4328.18 74.750 163.210 2680.83 2726.00 4422.78 75.190 162.940 2705.36 2750.53 4517.50 75,810 162.850 2729.08 2774.25 4611.60 76.450 161.990 2751.64 2796.81 4704.14 75.950 161.210 2773.71 2818.88 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 829.77 S 9.70 W 6028146.56 N 558162.32 E 911.08 S 7.53 E 6028065.40 N 558180.18 E 994.53 S 26.76 E 6027982.10 N 558200.07 E 1079.91 S 47.91 E 6027896.89 N 558221.89 E 1167.07 S 69.20 E 6027809.90 N 558243.86 E 1253.95 S 90.62 E 6027723.19 N 558265.96 E 1339.45 S 112.81 E 6027637.86 N 558288.82 E 1426.88 S 136.43 E 6027550.62 N 558313.12 E 1514.33 S 160.73 E 6027463.37 N 558338.10 E 1599.66 S 184.82 E 6027378.22 N 558362.86 E 1685.86 S 211.40 E 6027292.23 N 558390.11 E 1772.48 S 240.53 E 6027205.85 N 558419.92 E 1859.33 S 270.05 E 6027119.23 N 558450.12 E 1945.75 S 299.62 E 6027033.04 N 558480.36 E 2031.82 S 329.64 E 6026947.21 N 558511.05 E 2117.34 S 360.12 E 6026861.93 N 558542.21 E 2203.45 S 390.03 E 6026776.06 N 558572.78 E 2289.18 S 419.09 E 6026690.56 N 558602.51 E 2374.76 S 448.77 E 6026605.22 N 558632.86 E 2462.22 S 477.45 E 6026517.98 N 558662.22 E 2545.89 S 502.92 E 6026434.52 N 558688.35 E 2633.29 S 529.52 E 6026347.32 N 558715.63 E 2720.94 $ 556.49 E 6026259.89 N 558743.29 E 2808.03 S 584.09 E 6026173.02 N 558771.56 E 2893.30 S 612.45E 6026087.97 N 558800.59 E Dogleg Rate (°/100ft) 5.691 3.924 4.190 4.990 0.836 1.061 0.715 0.710 0.123 0.383 3.228 0.572 0.429 0.435 0.305 0.516 1.723 0.768 0.423 2.204 0.567 0.541 0.661 1.118 0.981 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 798.04 881.02 966.59 1054.52 1144.22 1233.67 1322.00 1412.56 1503.32 1591.99 1682.15 1773.37 1864.93 1956.08 2047.02 2137.54 2228.49 2318.84 2409.21 2501.13 2588.56 2679.88 2771.53 2862.81 2952.54 13 August, 2001.23:49 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB'I Your Reft API,50029230f470 Job No, AKZZ'I f092, Surveyed: 2 June, 200f Milne Point Unit Measured Depth fit) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 4798.81 76.030 161.090 2796.63 2841.80 4892.95 73.850 162.730 2821.09 2866.26 4987.29 73.980 162.490 2847.23 2892.40 5081.15 74.480 161.070 2872.74 2917.91 5174.78 74.810 161.050 2897.53 2942.70 5265.45 72.830 163.990 2922.80 2967.97 5362.73 73.070 164.080 2951.33 2996.50 5456.52 73.000 163.840 2978.69 3023.86 5550.91 73.700 163.780 3005.74 3050.91 5643.68 74.230 163.290 3031.36 3076.53 5737.68 74,480 162,400 3056.71 3101.88 5831,62 74,620 162,190 3081.74 3126.91 5926.64 75,310 162.530 3106,39 3151.56 6000,87 74,480 161.980 3125,73 3170.90 6113.82 73,840 159,610 3156.56 3201.73 6208,31 74,1 O0 161,700 3182.66 3227.83 6302.36 73,910 164.130 3208.58 3253.75 6395,86 74,290 164,090 3234.19 3279.36 6490.02 74.870 164.200 3259,23 3304.40 6583.22 75,040 165.050 3283,42 3328,59 6676.95 75.440 165.510 3307.30 3352.47 6769.05 75.890 165.180 3330.11 3375.28 6863.20 75.690 166.180 3353.22 3398.39 6957.29 74.850 166.390 3377.14 3422.31 7051.20 75.190 166.410 3401.42 3446.59 Local Coordinates Global Coordinates Northings Eastings Northings Eastings fit) fit) fit) (ft) 2980.23 S 642.13 E 6026001.28 N 558830.95 E 3066.63 S 670.36 E 6025915.10 N 558859.86 E 3153.13 S 697.45 E 6025828.81 N 558887.62 E 3238.93 S 725.69 E 6025743.24 N 558916.54 E 3324.33 S 755.00 E 6025658.07 N 558946.51 E 3407.37 S 781.1 6 E 6025575.24 N 558973.32 E 3496.78 S 806.74 E 6025486.02 N 558999.60 E 3583.00 S 831.53 E 6025400.00 N 559025.06 E 3669.85 S 856.74 E 6025313.36 N 559050.95 E 3755.35 $ 882.02 E 6025228.05 N 559076.89 E 3841.84 S 908.71 E 6025141.78 N 559104.27 E 3928.10 S 936.25 E 6025055.74 N 559132.48 E 4015.55 S 964.06 E 6024968.51 N 559160.97 E 4083.80 S 985.90 E 6024900.42 N 559183.34 E 4186.41 S 1021.64 E 6024798.10 N 559219.88 E 4272.09 S 1051.72 E 6024712.66 N 559250.63 E 4358.50 S 1078.28 E 6024626.45 N 559277.87 E 4444.99 S 1102.90 E 6024540.16 N 559303.16 E 4532.31 S 1127.70 E 6024453.04 N 559328.64 E 4619.09 S 1151.56 E 6024366.45 N 559353.19 E 4706.75 S 1174.59 E 6024278.97 N 559376.90 E 4793.08 S 1197.17 E 6024192.82 N 559400.15 E 4881.51 S 1219.74 E 6024104.57 N 559423.42 E 4969.92 $ 1241.32 E 6024016.34 N 559445.68 E 5058.09 S 1262.65 E 6023928.33 N 559467.70 E Dogleg Rate (°/100ft) 0.149 2.862 0.281 1.550 0.353 3.803 0.262 0.256 0.744 0.764 0.950 0.262 0.804 1.327 2.097 2.144 2.492 0.408 0.626 0.899 0.638 0.599 1.05t 0.918 0.363 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3044.21 3135.00 3225.58 3315.78 3405.88 3492.88 3585.88 3675.58 3766.00 3855.14 3945.60 4036.06 4127.75 4199.34 4307.74 4398.31 4488.67 4578.58 4669.35 4759.35 4849.99 4939.21 5030.47 5121.43 5212.12 13 August, 2001 - 23:49 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB`/ Your Reft API-50029230'1470 Job No. AKZZ`/`/092, Surveyed: 2 June, 200'/ Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~t) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~t) (~t) (~t) 7144.35 74.940 165.880 3425.42 3470.59 5145.47 S 1284.20 E 6023841.12 N 559489.94 E 7239.01 74.360 165.410 3450.48 3495.65 5233.91 S 1306.83 E 6023752.87 N 559513.26 E 7332.76 73.520 165.510 3476.42 3521.59 5321.11 S 1329.45 E 6023665.84 N 559536.56 E 7426.38 77,400 164.940 3499.92 3545.09 5408.72 S 1352.56 E 6023578.42 N 559560.35 E 7520.70 76.640 164.660 3521.10 3566.27 5497.41 S 1376.66 E 6023489.91 N 559585.14 E 7614.81 76.630 164.830 3542.86 3588.03 5585.75 S 1400.75 E 6023401.77 N 559609.93 E 7708.38 76.830 162.750 3564.34 3609.51 5673.19 S 1426.17 E 6023314.53 N 559636.03 E 7803.17 77,260 162.800 3585.59 3630.76 5761.43 S 1453.52 E 6023226.51 N 559664.08 E 7896.20 77.520 162.370 3605.90 3651.07 5848.05 S 1480.70 E 6023140.10 N 559691.92 E 7990.07 77.650 162.830 3626.08 3671.25 5935.53 S 1508.11 E 6023052.84 N 559720.02 E 8082.65 77.910 161.680 3645.67 3690.84 6021.71 S 1535.69 E 6022966.88 N 559748.27 E 8176.88 77.080 161.270 3666.08 3711.25 6108.93 S 1564.91 E 6022879.88 N 559778.18 E 8272.13 75.950 160.510 3688.29 3733.46 6196.45 S 1595.24 E 6022792.61 N 559809.19 E 8365.52 73,310 159.150 3713.04 3758.21 6280.97 S 1626.28 E 6022708.33 N 559840.89 E 8459.44 73,840 158.830 3739.60 3784.77 6365.07 S 1658.58 E 6022624.49 N 559873.84 E 8545.00 74,350 159.270 3763.04 3808.21 6441.91 S 1688.00 E 6022547.88 N 559903.86 E 8550.00 74.380 159.260 3764.39 3809.56 6446.42 S 1689.70 E 6022543.39 N 559905.60 E 8553.78 74.400 159.280 3765.41 3810.58 6449.82 S 1690.99 E 6022539.99 N 559906.92 E 8645.33 75,950 159.580 3788.83 3834.00 6532.68 S 1722.08 E 6022457.38 N 559938.66 E 8766.00 75.950 159.580 3818.13 3863.30 6642.38 S 1762.93 E 6022348.00 N 559980.36 E 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 Easfings are relative to Well. Magnetic Declination at Surface is 26.308° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 164.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8766.00ft., The Bottom Hole Displacement is 6872.35ft., in the Direction of 165.136° (True). Dogleg Rate (°/100ft) 0,612 0.778 0.902 4.186 0.856 0.176 2.174 0.457 0.531 0.498 1.246 0.978 1.418 3.156 0.652 0.775 0.630 0.735 1.722 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 5302.09 5393.36 5483.45 5574.05 5665.96 5757.52 5848.57 5940.89 6031.61 6123.22 6213.62 6305.46 6397.87 6487.58 6577.21 6659.08 6663.88 6667.50 6755.62 6872.20 Projected to TD 13 August, 2001 - 23:49 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-4f PB1 Your Reft APi.50029230f470 Job No. AKZZlI092, Surveyed: 2 June, 200~ Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Depth fit) 8766.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3863.30 6642.38 $ 1762.93 E Comment Projected to TD Survey tool program for MPC-4f PBf From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8766.00 3863.30 Survey Tool Description AK-6 BP IFR-AK 13 August, 2001 - 23:49 Page 6 of 6 DrillQuest 2.00.08.005 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-41 PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 8,766.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU6 20 200! ~aska Oil & Gas Cons. Commi~n Anchore~e Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 PB 1 MWD Job No. AKMM10166, Surveyed: 2 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301470 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149°31'28.2842"W) DRILL. lNG SERVICES Survey Ref: svy9922 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 MWD Your Ref: API-500292301470 Job No. AKMM10166, Surveyed: 2 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. 0.00 0.000 0.000 228.47 1.090 207.490 316.10 2.980 231.970 407.26 4.690 236.620 494.49 6.440 235.470 584.88 7.970 235.580 675.82 8.910 235.080 762.40 9.350 223.870 859.58 10.770 215.060 953.27 12.150 209.620 Sub-Sea Depth (ft) -45.17 183.29 270.86 361.81 448.63 538.30 628.25 713.74 809.43 901.26 Vertical Depth (ft) 0.00 228.46 316.03 406.98 493.80 583.47 673,42 758.91 854.60 946.43 1043.56 14.110 207.290 989.18 1034.35 1139.79 17.270 198.610 1081.83 1127.00 1233.31 20.680 189.670 1170.27 1215.44 1327.65 23.090 185.310 1257.81 1302.98 1420.31 25.720 178.610 1342.20 1387.37 1513.71 27.450 175.860 1425.73 1470.90 1603.32 28.840 174.830 1504.74 1549.91 1700.76 29.000 174.370 1590.03 1635.20 1794.29 30.400 175.030 1671.27 1716.44 1889.89 33.370 171.200 1752.44 1797.61 1982.69 36.730 170.900 1828.40 1873.57 2076.64 40.380 171.390 1901.86 1947.03 2170.31 45.090 169.940 1970.64 2015.81 2263.84 50.680 169.240 2033.34 2078.51 2357.00 55.450 166.340 2089.31 2134.48 2452.53 60.740 167.930 2139.79 2184.96 2546.19 64.390 167.490 2182.93 2228.10 2639.79 68.050 166.080 2220.67 2265.84 2733.20 72.700 165.750 2252.04 2297.21 2827.28 72.300 166.410 2280.33 2325.50 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 6028976.39 N 558165.53 E 1.93 S 1.00W 6028974.45 N 558164.54 E 4.07 S 3.18W 6028972.29 N 558162.38 E 7.58 S 8.16W 6028968.75N 558157.43 E 12.32 S 15.17W 6028963.96 N 558150.46 E 18.73 $ 24.52W 6028957.47 N 558141.16 E 26.33 S 35.49W 6028949.79 N 558130.25 E 35.24 S 45.86W 6028940.80 N 558119.94 E 48.36 S 56.55W 6028927.59 N 558109.36 E 64.10 S 66.45W 6028911.77 N 558099.58 E 82.14 S 76.20W 6028893.65 N 558089.98 E 106.11 S 86.14W 6028869.61 N 558080.22 E 135.56 S 93.35W 6028840.10 N 558073.25 E 170.41S 97.86W 6028805.22 N 558069.01E 208.62 S 99.05W 6028767.00 N 558068.11 E 250.35 S 97.00W 6028725.29 N 558070.49 E 292.48 S 93.57W 6028683.19 N 558074.25 E 339.39 S 89.13W 6028636.31N 558079.06 E 385.53 S 84.86W 6028590.21 N 558083.69 E 435.63 S 78.74W 6028540.16 N 558090.20 E 488.27 S 70.44W 6028487.59 N 558098.91 E 546.11 S 61.44W 6028429.81 N 558108.37 E 608.81 S 51.10W 6028367.20 N 558119.20 E 677.02 S 38.55W 6028299.09 N 558132.28 E 749.75 S 22.75W 6028226.48 N 558148.65 E 828.79 S 4.73W 6028147.59 N 558167.28 E 910.00 S 12.97 E 6028066.52 N 558185.62 E 993.36 S 32,56 E 6027983.31N 558205,86 E 1078.67 S 53.97 E 6027898.17 N 558227.93 E 1165.76 $ 75,55 E 6027811.25 N 558250.20 E Dogleg Rate (°/100ft) 0.477 2.326 1.905 2.010 1.693 1.037 2.113 2.151 1.869 2.248 4.082 4.782 3.080 4.117 2.273 1.643 0.281 1.537 3.758 3.625 3.899 5.137 6.002 5.692 5.715 3.919 4.146 4.989 0.793 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 0.00 1.60 3.09 5.17 7.9O 11.63 16.07 21.94 31.80 44.38 59.22 79.74 106.26 138.70 175.24 216.05 257.60 304.03 349.67 399.61 452.58 510.76 573.97 643.08 717.41 798.40 881.40 966.99 1054.93 1144.63 MWD Magnetic 14 August, 2001 - 9:04 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 MWD Your Ref: API-500292301470 Job No. AKMM10166, Surveyed: 2 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 2921.11 72.690 165.480 2308.55 2353.72 3013.51 73.200 165.470 2335.65 2380.82 3108.12 73,150 164.730 2363.03 2408.20 3202.94 73.200 164.480 2390.48 2435.65 3295.56 73.210 164.570 2417,24 2462.41 3389.32 75.200 161.900 2442.77 2487.94 3483.80 75.370 161.210 2466.77 2511.94 3578.52 75,750 161.250 2490.39 2535,56 3672.80 75.570 160.570 2513.74 2558.91 3766.94 75.510 160.550 2537,24 2582,41 3860.71 75.510 159.950 2560.71 2605.88 3955.05 74.670 161.050 2584.98 2630.15 4048.81 75.110 159.900 2609.42 2654.59 4142.46 75.450 159.720 2633.22 2678.39 4237.62 75.180 161.860 2657.34 2702.51 4328.18 74.750 162.260 2680.84 2726.01 4422.78 75.190 162.100 2705.37 2750.54 4517.50 75.810 161.990 2729.08 2774.25 4611.60 76.450 161.180 2751.64 2796.81 4704.14 75.950 160.800 2773.72 2818,89 4798.81 76.030 160.660 2796.64 2841.81 4892.95 73.850 162.180 2821.10 2866.27 4987.29 73.980 161.960 2847.23 2892,40 5081.15 74.480 160.570 2872.74 2917.91 5174.78 74.810 160.650 2897.54 2942.71 5265.45 72.830 163,660 2922.81 2967.98 5362.73 73.070 163.760 2951.33 2996.50 5456.52 73.000 163.510 2978.70 3023.87 5550.91 73.700 163.500 3005.74 3050,91 5643.68 74,230 162.850 3031.37 3076.54 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1252.57 S 97.29 E 6027724.62 N 558272.61E 1338.08 S 119.44 E 6027639.28 N 558295.43 E 1425.60 S 142.73 E 6027551.95 N 558319.40 E 1513.10 S 166.82 E 6027464.64 N 558344.18 E 1598.56 S 190.48 E 6027379.37 N 558368.51E 1684.92 S 216.51E 6027293.21N 558395.21E 1771.61 S 245.42 E 6027206.75 N 558424.80 E 1858.46 S 274.94 E 6027120.14 N 558455.00 E 1944.78 S 304.81 E 6027034.06 N 558485.54 E 2030.74 S 335.15 E 6026948.33 N 558516.55 E 2116.19 S 365.83 E 6026863.13 N 558547.90 E 2202.12 S 396.26 E 6026777.44 N 558579.00 E 2287.43 S 426.51 E 6026692.37 N 558609.92 E 2372.44 S 457.77 E 6026607.60 N 558641.85 E 2459.36 S 488.06 E 6026520.92 N 558672.81 E 2542.57 S 515.00 E 6026437.93 N 558700.40 E 2629.55 S 542.96 E 6026351.17 N 558729.04 E 2716.78 S 571.23 E 6026264.16 N 558757.99 E 2803.46 S 600.09 E 6026177.71N 558787.53 E 2888.43 S 629.36 E 6026092.98 N 558817.47 E 2975.13 S 659.68 E 6026006.51 N 558848.46 E 3061.29 S 688,64 E 6025920.58 N 558878.10 E 3147.54 S 716.55 E 6025834.55 N 558906.68 E 3233.07 S 745.56 E 6025749.25 N 558936.36 E 3318.24 S 775.54 E 6025664.32 N 558967.00 E 3401.11 S 802.23 E 6025581.66 N 558994.34 E 3490.38 S 828.32 E 6025492.59 N 559021.12 E 3576.46 S 853.59 E 6025406.72 N 559047.07 E 3663.17 S 879.27 E 6025320.21N 559073.42 E 3748.51 S 905.08 E 6025235.07 N 559099.90 E Dogleg Rate (°/100ft) 1.033 0.552 0.751 0.258 0.094 3.466 0.729 0.403 0.724 0.067 0.620 1.436 1.274 0.408 2.194 0.638 0.493 0.664 1.077 0.672 0.167 2.792 0.263 1.521 0.362 3.864 0.266 0.266 0.742 0.883 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 1234.09 1322.42 1412.98 1503.74 1592.41 1682.58 1773.82 1865.37 1956.51 2047.42 2137.93 2228.84 2319.10 2409.34 2501.16 2588.53 2679.80 2771.40 2862.61 2952.29 3043.91 3134.66 3225.20 3315.36 3405.41 3492.38 3585.37 3675.06 3765.47 3854,60 14 August, 2001 - 9:04 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 MWD Your Ref: API-500292301470 Job No. AKMM10166, Surveyed: 2 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5737.68 74.480 162.480 3056.72 3101.89 5831.62 74.620 162.130 3081.74 3126.91 5926.64 75.310 162.040 3106.39 3151.56 6000.87 74.480 161.21 0 3125.73 3170.90 6113.82 73.840 159.060 3156.57 3201.74 6208.31 74.100 161.180 3182.66 3227.83 6302.36 73.910 163.490 3208.58 3253.75 6395.86 74.290 164.110 3234.20 3279.37 6490.02 74.870 164.300 3259.23 3304.40 6583.22 75.040 165.330 3283.43 3328.60 6676.95 75.440 166.310 3307.31 3352.48 6769.05 75.890 165.330 3330.11 3375.28 6863,20 75.690 166.340 3353.22 3398,39 6957.29 74.850 166.160 3377.15 3422.32 7051.20 75.190 164.790 3401.42 3446.59 7144.35 74.940 164.050 3425.43 3470.60 7239.01 74.360 163.950 3450.49 3495.66 7332.76 73.520 164.790 3476.42 3521.59 7426.38 77.400 164.400 3499.92 3545.09 7520.70 76.640 163.450 3521.11 3566.28 7614.81 76.630 164.630 3542.86 3588.03 7708.38 76.830 161.440 3564.34 3609.51 7803.17 77.260 161.210 3585.60 3630.77 7896.20 77.520 161.040 3605.91 3651.08 7990.07 77.650 160.290 3626.09 3671.26 8082.65 77.910 160.170 3645.68 3690.85 8176.88 77.080 160.240 3666.09 3711.26 8272.13 75.950 160.530 3688.30 3733.47 8365.52 73.310 158.730 3713.05 3758.22 8459.44 73.840 158.590 3739.61 3784.78 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3834.92 S 932.05 E 6025148.88 N 559127.55 E 3921.18 S 959.57 E 6025062.84 N 559155.74 E 4008.49 S 987.80 E 6024975.75 N 559184.65 E 4076.50 S 1010.39 E 6024907.91 N 559207.77 E 4178.69 S 1047.30 E 6024806.02 N 559245.49 E 4264.09 S 1078.18 E 6024720.86 N 559277.03 E 4350.23 S 1105.62 E 6024634.94 N 559305.14 E 4436.58 S 1130.70 E 6024548.79 N 559330.90 E 4523.92 S 1155.41 E 6024461.64 N 559356.29 E 4610.79 S 1178.99 E 6024374.97 N 559380.55 E 4698.66 S 1201.19 E 6024287.27 N 559403.43 E 4785.17 S 1223.05 E 6024200.93 N 559425.97 E 4873.67 S 1245.38 E 6024112.62 N 559449.00 E 4962.05 S 1267,01 E 6024024.40 N 559471.32 E 5049.87 S 1289,76 E 6023936.76 N 559494.75 E 5136.57 S 1313.94 E 6023850.26 N 559519.60 E 5224.31 S 1339.10 E 6023762.71 N 559545.45 E 5311.07 S 1363,37 E 6023676.15 N 559570.40 E 5398.42 S 1387,44 E 6023588.99 N 559595.16 E 5486.73S 1412,89 E 6023500.88 N 559621.29 E 5574.76 S 1438.06 E 6023413.05 N 559647.16 E 5661.86 S 1464.64 E 6023326.16 N 559674.41E 5749.37 S 1494.21 E 6023238.88 N 559704.67 E 5835.28 S 1523.58 E 6023153.21N 559734.71E 5921.78 S 1553.94 E 6023066.95 N 559765.74 E 6006.93 S 1584.54 E 6022982.04 N 559797.01 E 6093.49 S 1615.70 E 6022895.73 N 559828.84 E 6180.73 S 1646.79 E 6022808.73 N 559860.62 E 6265.15 S 1678.12 E 6022724.56 N 559892.61E 6349.06 S 1710.91 E 6022640.91 N 559926.05 E Dogleg Rate (°/100ft) 0.463 0.389 0.732 1.554 1.917 2.174 2.370 0.756 0.646 1.083 1.097 1.141 1.061 0.912 1.455 0.813 0.621 1.243 4.164 1.270 1.220 3.325 0.512 0.332 0.792 0.308 0.884 1.223 3.383 0.582 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3945.05 4O35.52 4127.18 4198.74 4307.04 4397.55 4487.87 4577.78 4668.55 4758.55 4849.17 4938.39 5029.64 5120.61 5211.31 5301.31 5392.59 5482.68 5573.28 5665.18 5756.73 5847.75 5939.96 6030.56 6122.00 6212.20 6303.91 6396.26 6485.94 6575.51 14 August, 2001 - 9:04 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 MWD Your Ref: API-500292301470 Job No. AKMM10166, Surveyed: 2 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8545.00 74.350 159.270 3763.05 3808.22 6425.84 S 1740.49 E 6022564.36 N 559956.23 E 8550.00 74.380 159.260 3764.40 3809.57 6430.34 S 1742.19 E 6022559.87 N 559957.97 E 8553.78 74.400 159.350 3765.42 3810.59 6433.75 S 1743.48 E 6022556.48 N 559959.28 E 8645.33 75.950 159.580 3788.84 3834.01 6516.62 S 1774.52 E 6022473.85 N 559990.97 E 8766.00 75.950 159.580 3818.14 3863.31 6626.33 S 1815.36 E 6022364.47 N 560032.67 E 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 26.240° (06-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 164.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8766.00ft., The Bottom Hole Displacement is 6870.50ft., in the Direction of 164.679° (True). Dogleg Rate (°/lOOft) 0.969 0.630 2.353 1.710 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 6657.37 6662.16 6665.79 6753.91 6870.49 Projected To TD Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8766.00 3863.31 6626.33 S 1815.36 E Comment Projected To TD 14 August, 2001 - 9:04 Page 5 of 6 DrillQuest 2.00.08.005 r Sperry-Sun Drilling Services Survey Report for MPC-41 PB1 MWD Your Ref: AP1-500292301470 Job No. AKMM10166, Surveyed: 2 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Survey tool program for MPC-41 PB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 8766.00 3863.31 Survey Tool Description MWD Magnetic 14 August, 2001 - 9:04 Page 6 of 6 DriliQuest 2.00.08.005 K~ STATE OF ALASKA ~' ALAS ..,IL AND GAS CONSERVATION COM ....,SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Plugging [] Time Extension [] Perforate [] Pull Tubing [] Vadance [] Other [] Re-Enter Suspended Well [] Stimulate Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 694' NSL, 2298' WEL, SEC. 10, T13N, R10E, UM At top of productive interval 2874' SNL, 89' EWL, SEC. 23, T13N, R10E, UM (AS Planned) At effective depth 1101' SNL, 1045' EWL, SEC. 26, T13N, R10E, UM At total depth 1101' SNL, 1045' EWL, SEC. 26, T13N, R10E, UM (AS Planned) 12. Present well condition summary ~:3~ ~"~'~/ Total depth: measured ~eet ("AS"--Plugs (measured) true verticali measured true vertical Effective depth: 4396 feet .1-1.090' feet Junk (measured) 4396 feet Length Size 110' 13-3/8" 11197' 7" Cemented 260 sx Arctic Set (Approx.) 1456 sx Arctic Set III, 792 sx Class 'G' Casing Structural Conductor Surface Intermediate Production Liner 6. Datum Elevation (DF or KB) Planned KBE = 29.75' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-41 9. Permit Number 201-078 10. APl Number 50- 02923014-00 11. Field and Pool Milne Point Unit / Schrader Bluff MD TVD 110' 110' 11197' 4235' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) RECEIVED JUN 1 :'Z001 Alaska 0ii & Gas Cons. Commission Anchorage 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation June 13, 2001 16. If proposal was verbally approved i/ Tom Maunder PJ'~' ~"(~~/2001 Name of approver Date Approved Contact Engineer Name/Number: Steve Shultz, 564-5491 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that the Signed Steve Shultz to the best of my knowledge Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required lO- Approved by order of the Commission ,RIGIN^L SIGNED BY Form 10-403 Rev. 06/15/88 % '7"ayi~~(J~i:l N A L Approval No. ,..~..~J-[ ~.~ Commissioner Date Submit Ih"'TiiPlr(~te ' Procedure for Abandoning the OB Lateral on MPC-41 ML C-41 ML was spudded on May 28,2001 with a 9 7/8" bit and the surface hole was drilled to 11.210' with a sail angle of 75 ° and a final build angel of 89° into the OB sand. A string of 7", 26 4/casing was run and cemented into place at 11,197' MD (4,397' TVD). The OB was drilled out and an FIT was performed to 11.0 ppg MWE with a 9.0 ppg mud in the hole. The OB was sand was drilled to a depth of 12,200' MD when we drilled out of the top of the OB sand into the shale above. An open hole sidetrack was performed at 11,741' MD in an attempt to regain the lost section. The sidetrack was drilled to a depth of 12,090' MD when the resistivity indicated that we had hit the oil water contact. The decision was then made to abandon the OB lateral and continue on with the previously permitted lateral in the OA sands. Several options were discussed as potential abandonment procedures. The main risk associated with normal abandonment options is the possibility of fracing past the shale between the OA and OB when squeezing cement under the retainer by bulheading into the OB sand and subsequently watering out the OA lateral. Therefore we are opting to set two bridge plugs (one 50' above the 7" shoe and one 677' above the shoe) in order to comply with AOGCC requirements to avoid a squeeze cementing operation. The following is the abandonment procedure to meet this objective (this plan was discussed via a telephone conversation with Tom Maunder on 6/13/01 @ ~ 11:00 am and was verbally approved): o . . . o POOH with the drilling BHA to just below the 7" shoe and circulate, rotate and condition mud to clean up the 7" casing, POOH with the drilling BHA. Rotate at least 60 RPM's and circulate at max rate within ECD tolerances so as to ensure a clean hole prior to running the BP. MU 7", 264/permanent bridge plug and RIH on drill pipe, set at +11,147', POOH 9~~: MU second 7", 26g bridge plug and RIH ~d set at !10,520' MD (so as to ensure the top of the whipstock is set at 10,505' MD - 4' below the top of the OA s~d (10,501' MD), POOH MU whipstock assembly and RIH ~d set on BP ~ 10,520' MD, orient as per the original well plan dated 5/22/01. Shemoff whipstock ~d mill window in 7" casing across the OA s~d as per the drilling program for C-41 ML, dated 5/22/01. TREE: F~MC Horizontal 3-1/8" 5M PROPOSED COMPLETION 'WELLHEAD:FMCHorizontalll",5Mtbg. head (71P c-41 & c-41 L1 {" KB. ELEV=45.00 11" x 3-1/2", EUE (btm) Cellar Box ELEV = 15.00' FMC tbg. hanger, 'H' BPV profile i , 110' ~ 3 3/8-0- 92 lb/fi, H-40 ~ · · Welded 2 7/8", 9.3 Ib/ft, L-80, EUE-M Coupling OD: 4.5" Drift/ID' 2.867"/2.992" 7",26#, L-80, Hyd ril521 Casing Drift: 6.151" Casing ID: 6.276" I I 6-1/8" CA Lateral TD 10,§05' - 14,800' I ~ ~ 6-1/8" OB Lateral TD 11,200' - 12,210' I I I I TOP °f Wind°w in 7" casing @ 10,505' I Well Inclination @ Window = 75Degrees ~:;F~ ~,~.~:) 7" Casing Shoe @ 11,197' Well Inclination @ Shoe -- 90 Degrees Reference Directional Plan WP3 DATE REV. BY COMMENTS Milne Point Unit WELL: C-41 ML 6/~ 3/01 SMS APl NO: Plugback of the OB due to watered out sands -" BP Exploration (Alaska) ,, BP ExpLoRATION Daily Operations Report Page I of 2 ~ BP ~PLORATION Rig: NABORS 22E 22E ........... ~ 20 Well: !~'C-41 Event: ORIG DRILUNG Date: 6/14T2001 F~ekJ: MILNE POINT Wd Type: DEVELOPMENT , Current Well Status De~U~ ~0,~23.0(ft) Cas~'~ '7.00b(-~) cests~ USD FUg~ ~0~ 5rzsr~oo~ Est_ TVD: 4,327.0 (ft) Casing (MD): 11,196.72 pt) AFE No: 33T233 RJg Release: Progress: (It) Next Casing Size: 4.500 ('m) AFE ~ 4,144,000 Spud Date: 5/28F2001 Aah Dep~ 14,800.0 (~t) Next Casing (MD): 14,800.0 (tt) Daay Mud: 2,392 Bev Ret:. ROTARY KELLY BUS~N Ho~e Size: Next Casing (TVD):4,356.0 pt) Cum. ~ 2O6.748 DOUOFSrrargec 18.0(V17.05/42.50 Un= (MD): Oa~ We~ 133,833 KB Bev:. 53.7O pt) Ge~ogisC Dave Boyer Liner Top (MD): Cum. Wea: 2,332,945 Enginea:. Steve Campbell Tot_ Pemonnel: 38 IC~rrmt Staus: ~aH W~h Wmdow ~ ~ And ~ AssemUy 24hr Sanmay:. RIH Set EZSV @ 1~,147' & ~0,523' - PO, Z4hr Forecast: RIH Wdh Whipstodc And ~ W'mdow- POH - Test BOP Comntents: NO ACCIDENTS, INCIDENTS, OR SPILLS. $200.000 Over On Costs Est_, 1.25 Days Ahead Of Plan . .Weath~. Temp. 3~ D~ - Wind Out O~ NW At 8 ~- C~, Faa= 24 De~ ..... HSE & Well Control Da~'~ r:~st D,V'WC: ' ~'~ ......... ~ F= Da>: 0 ................. Last Csg Test Press.: 3,5OO (psi) Last Envir. incident: 5r2w20m Last BOP Press. Test: 6/9/2001 Last Atmndonme~ Dnll: 5/19/2001 Last Trip Ddll (D1): 6/14/2001 Next BOP Press. Test: 6/16/'2001 Last Accum. Ddll (D4): 5/28F2001 Last Safety Meeting. 6/14/2001 Last Diverl~r Dril (133): 5/28/2001 Last Spill Ddll: 6/13/2001 Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) 'Slow Pmnp Rates (Kill) RT TVD: 4,,100.0 (~) Slmke Rate Pn~sstre0 Stroke Rate Pressure0 Stroke Rate Pressure0 FIT EMW: 10.97 (ppg) MAASSP: 2,507 (psi) Test F'mssae: 45O (psi) mckT~: 11.00 (ppg) mck. Vel~ne.: 1,000.0,{ha) .......vl~. ,,,,,,.,"~-"';'="'"1 P"ra-'''~'~''" :,,,~,=,= .. '. ' ..". ............... ROP r)a~: .............................. Rat~dng Waght: Oai~ i~t H~s! (hr) ' Pump Sram - Dn~ing and Faser 'ROP Cmn.: Pick Up WL: Daily Slking Hfs:0.00 (hr) Pump Type Eft. Slmkes Liner Size! Circ. Rate WOB (min): Slack Off WL: Cum. Bit Hfs: 0 0 0 0 WOB (rna~): Circ. Rate Riser:. RPM at Surface: Circ. Rate Hole: Ann. Vel. Riser:. (It/min) RPM at 13(Xl=~: Circ. Off Boltom: Ann. Vd. DC: (lt/min) Torq. on Boltcmt: Circ. On Bottom: Ann. Vel. DP: (It/min) Tmq~ off Bottom: Jar I-ks since Inspect:. 21 (hr) ................... ........................ ............ ',i',', ,' ........... L,,', ' Type: ' BARADRIL..N'' ' PV: ............... 11 (CP) Solids'. 4.60 (%) Daily Cuttings: (bbl) YP: 19 (Ib/100Ez) MBT: 2.20 (ppb) Ctun. Cutlings: (hbl) Density:. 9.~0 (ppg) ~0secgels: 9 (,b~00~ R,Jd~: 5.6 (cc,'30m~,) Cake: 1 (/32') F.u.r,~... v*~,~;,.'.. 43 (s/.qt) 10 min gels: 11 {Ib/lO01tz) pH: 8.5 ', ', .................. Fm~/-~o .... ./S' ~"ra~ .... ~' ' ~ ~ o~,a~ hh:mm (hr) 00:00-05:00 5.00 PROD1 DRILL PKRRP C RIHW'dhEZSVB~dgePlugon31/2'DriIIPipe(SLM)To11,14T 05:00-05:30' 0.50 PROD1 DRILL PKRST C Break Circulalion Wash And Clean EZSV Bddge Plug Setling A~ea - iApply 35 T~ To~ ~-~An ~ 5 Tums To The ~ Right- Rek~se Torque From Stdng -Pick Up And Ved[y That EZSV From F_.ZSV W'dh 45K ~ 195K - Pick Siting Up To 11,137' - Apply, 30 Tums To The Right And Release Torque - Sit Down And Tag EZSV W~h 30K- Pick Up Sldng And Test EZSV To 3,500 Psi. For 10 Minutes - Bleed Off Press~e 05:3O-O6:OO 0.5O PROD~ DRILL CIR C Palp Dry Job'-'Bk)w Down Top Drive And ~ Systan 05:00-12:00 6.00 PROD~ DRILL PTOH C POH W'dh Bddge Plug Running Tool (Si.~) , , , , , , , , , , ~ ..... , , ,,, , , ........ , ......... , , ..... , ...................... ,,, Printed: 611512001 5:58:15 AM BP EXPLORATION , ,, Daily Operations ,Report ., Page 2 of 2 Well: MPC-41 Event: ORIG DRILLING Date: 6/14/2001 Fm~d: MILI~ POINT Well Type: DEVELOPMENT O~rations Su..nary , csta~ 19.00-20:00 1.00 PROD1 DRILL PKRST C Bn~ak Circulalion Wash And Clean EZSV I~dge Plug Selling Area - Apply ~ T~ To ~ Right - Aptly An ~ 5 Turns To The Is Set ~ 10,523' To 25K,abov~ Normal ~ Drag- Shem'Oil From EZSV With 45K ~ 195K - Pick S~ing Up To 10,513' - Apply 30 T~'ns To The Right And Release T~ -Sit Doum A~ Tag EZSV W'dh 30K- Pic~ Up Sling And Test EZSV To 3,500 Psi. For 10 20:00-20:30 0.50 PROD1 DRILL CIR C Pmnp D~ Job - Blow Down Top Drive And Circulating System Install Safety Wire On Vano Top D~e 20:30-00:00 3.50 PROD1 DRILL PTOH C POH W'dh Halix,'l=n B~lge Plug Rtmning Tool , , I,, , ,, , ,, ..... , ..... , .... 06:00 Update: ' RIH W'~h Window IVlaster Whipstock And Milling Assembly ................... ;emarks .......... Up And Make Up Window Mastm' Whipstock And Milling Assembly - Pick Up I Drill Collar & S~Pace Test MWD Tool - C_,onlJr,~ To Pick Up 4 3/4" Drill Collar~ & 3 1/2" HWDP- RIH Wilh 3 1/2" Drill Pipe From Mast ............................. ...... . . . .... Uateda~s/ConsUmpti°n ................... . ,-- , ......... , , a~a~ ,, ,~?,o~lw^m~.o~ ............ PerSOnnel 'c.~p~ny ........... ~:" HO,,~ " Company' ..r'r'k'. ''''O"'S.... ~ ........ E:~PX 2 NABORS 26 BAROID 2 DOYON ~ SPERRY SUN 5 BPX Cha,enge ~ 2 ................................ c,mu~ative'Pha.e B'reakdO-. ..... ......................... p~a,~,~ .......................... Change or~ ........ T~i .... -ro~iCost Phase --Prod' % Total 'NPT % Total WOW % Total Prod %'l'olal I~T % Total WOW % Total Hours USD PRE 41.00 100'.0% .... 41.00 SURF 270.00 89.4% 32.00 10.6% 302.00 PROD1 68.50 59.1% 10.00 8.6% 35.00 30.2~ 2.50 2.2% 116.00 TOTALS 37~.50'82.7% 42.00 ~.2./. O.O0 0.0% 35.00 7.~% zr,0' 0.~% 0.00 0.0"~ 4.~.00 ................. Window / C0i~ed Tubi,g Ori~,,,g .................. Windo~Top: (fi) ........... CT OD: ..............(in) CT ~y Ftg:' (f~) CT ~ fpsi) ...... ........ Mud Sys Ftg: (ft) CT IO: (in) CT Cum Ftg: (It) CT Length: ,, , , , , ........ , , , , ,, ,, , ,,,, , , ,, ,, ,, , .... , ........ , .... , ....... Pdnted: 6115/2001 5:58:15 AM A~~l~k OIL ~ CO~SERYATIO~ COMMISSIOS~ TONY KNOWLES, GOVERNOR 3,33 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Milne Point Unit MPC-41 BP Exploration (Alaska) Inc. Permit No: 201-78 Sur Loc: 694' NSL, 2298' WEL, SEC. 10, T13N, R10E, UM Btmhole Loc. 1101' SNL, 1045' EWL, SEC. 26, T13N, R10E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional Permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. - C o n So:7°unt' Jr' BY ORDER OF THE COMMISSION DATED this ,~ day of MaY 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK.~ ...IL AND GAS CONSERVATION COMI~....,SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [][] Re-EntryDdll [][] DeepenRedrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 29.75' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 694' NSL, 2298' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 2874' SNL, 89' EWL, SEC. 23, T13N, R10E, UM MPC-41 Number 2S100302630-277 At total depth 9. Approximate spud date 1101' SNL, 1045' EWL, SEC. 26, T13N, R10E, UM 05/18/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 1045' MDI No Close Approach 2560 14800' MD / 4415' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} o Kick Off Depth 200' MD Maximum Hole Angle 91 Maximum surface 1378 psig, At total depth (TVD) 4115' / 1851 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 92# H-40 Welded 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7" 26# L-80 BTC-M 11163' 30' 30' 11163' 4415' ~3~r2sxArcticSetlll, 2M~sxArcticset~ 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 3637' 11100' 4412' 14800' 4415' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural RECEIVED Conductor Surface Intermediate Production rv//],¥ 0 ~. 2 0 01 Liner A/aska Oil & Gas Cons. Commission Anchorage Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Shultz, 564-5491 Prepared By Name/Number: Sondra Stewrnan, 564-4750 21. I hereby certify that the fore~'0i.~{I is true,~lr~d COllect to the best of my knowledge / _./ Date ~//'~/ ~,/ Signed Steve Shultz ~...~ ~ i~~ Title Senior Drilling Engineer . '.: ;.;:" '::' ...'....'...'. .... '..':. '~::. ... ;~.... ". ':.. . .:: .'.:.".. ~`~X~!~:~:~m:m;issi~:~se~n~y~:`~;i~;~:~:~:~:;: ':. · ;.;:' ..:. :'....,:": :..."i" '":'"'".':.::'.,'.'i':~:i.~.L. ' · Permit Number I APl Number I A vi te. i Se~ 'cover letter .~_o/.- ~' 50-O~ ~-- --~.-,~O,/~'~ L~eqV~i~re¢/ for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud [] Yes [] No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required I~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Ct O '~ ~'~ -~-~,~--- t~I~L 5~NED BYD Taylor Seamoun! by order of~,'/~../~ ,,Approved By Commissioner the commission Date ,._..,/~, Form 10-401 Rev. 12-01-85 ORI®INAL_ Sut ,riplicate Schrader Bluff 2001 Program MPC-41 Well Plan IWell Name:(,I MPC-41 & MPC-41 L1 I Type of Well (producer or injector): I Producer (Multilateral) I Surface Location: 694' NSL, 2298' WEL, Sec. 10, T13N, R10E X = 558,165.39 Y = 6,028,976.39 MPC-41 OB Target Start: 2874' SNL, 89' EWL, Se~. 23, T13N, R10E X = 560,637.59 Y = 6,020147.26 Z = 4371' TVDss MPC-41 OB Target End: 1102' SNL, 1045' EWL, Sec. 26, T13N, R10E X = 561,627.2 Y = 6,016,648.78 Z = 4369' TVDss MPC-41 L10A Target 2351' SNL, 47' WEL, Sec. 22, T13N, R10E Start: X = 560,496.25' Y = 6,020,668.78 Z = 4294' TVDss MPC-41 L10A Target 1107' SNL, 1038' EWL, Sec. 26, 'T13N, R10E End: X = 561,620.2 Y = 6,016,643.05 Z = 4310' TVDss AFE Number: I I I Rig= I Nabors 22E Estimated Start Date: ]May 18, 2001 I I Operating days to complete: 142.5 OAMD 10616'-)14800'[ ]OATVDrkb(TD)4356'11 OAMax. lnc. 93° KBE 29.75' OB MD 11200'-)14800' .OB TVDrkb (TD) 4415' I OB Max. Inc. 91° Well Design (conventional, slim hole, etc.): I Grassroots multi-lateral with extended horizontal I laterals. ESP completion. Objective: Drill 9-7/8" mainbore hole to +/- 11200' MD. Land mainbore hOle in OB reservoir. Run and cement 7" casing. Drillout shoe and drill horizontal lateral in OB. Run 4 Y2" slotted liner with hanger and liner top packer. Run retrievable whipstock at top of OA interval at +/- 10616' MD. Mill window in 7" casing. Drill horizontal lateral in OA. Run 4 Y2" slotted liner and hang off with a hookwall hanger system. Complete well with a 2 7/8" ESP completion. Version #1, 4/25/2001 1. Current Well Information Schrader Bluff 2001 Pro~lram MPC-41 Well Plan Well Name: APl Number: Well Type: Current Status: BHP: BHT: MPC-41 Development - Schrader Bluff Multilateral Producer New well, 20" conductor set 1963 psi Schader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4415' SS Estimated 2.1 Mechanical Condition MPC-41: Nabors 22E: Conductor: Cellar Box MSL = 15.00' KB = 29.75' 20", 92 Ib/ft, H-40 Welded set at 110' RKB 2.2 Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserves 2.1 MMbbl Production rate: 2043 b/d Production rate: 568 b/d 2.3 Materials Needed Production Casing: 1120O' I each I each 60 each I assembly 1 assembly 1 lot 7" 26# L-80 Hydril 521 Casing 7" Hydril 521 Float Shoe and Float Collar 7" 26# Hydril 521 Type TAM Cementer 7"x 9-5/8" Rigid SB Casing Centralizers FMC 11" 5m x 2 9/16" X-mas Tree Baker Level 3 Multilateral Equipment (Hookwall) 7" casing pups 5', 10', 20' with Hydril 521 2 x Production Liners: 7500' 200 off 4-5/8" x 5 3,~" x 8" 7,, x 4 1/2,, 4 1/2", 12.6#, L-80, IBT-Mod Slotted Liner Rigid Straight Blade Centralizers and stop rings Baker liner top hanger w/liner top packer and inner string Baker guide shoe, packoff bushing Schrader Bluff 2001 Program MPC-41 Well Plan 3. Drillin_q Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3,2. 3.1.1. The 9-7/8" surface hole will be drilled with a diverter on the well. The 6-1/8" horizontals will be drilled with the BOP installed. MPC-41 is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.65 lb/gal equivalent. The planned mud weight is 9.1 lb/gal which provides a 0.45 lb/gal overbalance (80 psi). Kick tolerance 3.2.1. The 7" casing will be set into the Schrader Bluff OB reservoir. The kick tolerance for the 6-1/8" horizontal open hole section is infinite assuming an influx at the 14800' in the Schrader OB formation. This is a worst case scenario based on a 8.65 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 lb/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.3. Lost Circulation 3.3.1. Lost circulation has not been encountered while drilling this interval on previous C-Pad wells. 3.3.2. Clean hole ECD in the 9-7/8" surface hole is estimated to be 10.1 lb/gal. Clean hole ECD in the 6- 1/8" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. 3.3.3. 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 3.4. Unexpected Hiqh Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no offtake or injection support. Reservoir pressure is expected to be 1963 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.5. Stuck Pipe 3.5.1. The C-41 directional plan has a 8488' interval of high angle (75°) in the surface hole with +3600 feet to drill for each lateral in the OA/OB reservoirs. All these hole intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud Schrader Bluff 2001 Pro~lram MPC-41 Well Plan properties as outlined in the Baroid mud program must be closely followed. 3.5.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5.3. There is a risk of differentially sticking the 4 Y2" slotted liners. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.65 lb/gal OA/OB sand reservoir pressure (86 psi differential pressure @ 4115' TVD). The liner should be kept moving as much as possible while running in the open hole. In order to combat this tendency, solid stand off centralizers will be run on the liner two per joint to ensure the casing from contacting the wellbore wall and allowing the casing to become differentially stuck. 3.6. Pad Data Sheet 3.6.1. Please Read the C-Pad Data Sheet thoroughly 3.7. Hydrates 3.7.1. Hydrates have not been encountered on previous C-Pad wells and are not expected. However hydrates have been encountered on H-Pad and mud returns should be monitored to determine if hydrates are encountered on this well. 3.7.2. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. 3.8. Breathing Schrader Bluff 2001 Pro~lram MPC-41 Well Plan 3.8.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3,9, Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3,10, Geosteerinc~ 3.10.1. Two rig site geologists are required onsite for accurate geosteering through the thin OA/OB sands 3.10.2. It is critical that we achieve a high percentage of 6-1/8" hole in reservoir zone drilling in the OA/OB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3.11. Hydrogen Sulfide 3.11.1. MPC Pad is not designated as an H2S Pad. Schrader Bluff 2001 Pro~lram MPC-41 Well Plan 4. Drilling Pro ram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-41. · Close Approach Wells: None · Close Approach Issues: We will be running IFR on the 9 7/8" hole section due to proximity of offset well to ensure directional control. The closest we will come to the edge of an elipse is 37 feet at 1293'. Well Name I Current Status Production Priority I Precautions N/A N/A N/A N/A 4.2. Well Control ., IExpected BHP 1851 psi, 4115' TVD (estimated) Max Exp Surface Pressure 1378 psi (0.115 psi/ft gas gradient) BOPE Rating 5000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2500/250 psi Rams and Valves 2000/250 psi Annular 4.3. Mud Proqram 9-7/8" Surface Hole Mud Properties: I Spud - LSND Freshwater Mud I Density (ppg) Funnel vis YP HTHP pH APl Filtrate LG Solids 8.6 - 9.2 50 - 150 25 -40 N/A 9.0 - 9.5 < 6 < 6.5 6-1/8" Production Hole Mud Properties: OB/OAI KCL - CaCO3 Baradril N Mud I Density (PPg) I Funnel vis I YP I "'"" I "" APl Filtrate I LG S°lids 9.1 40 - 55 22 - 27 < 10 8.0 - 8.5 4 - 6 < 12 ppb 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW (ppg) Base Permafrost 1856 1785 Top Ugnu 8415 3776 1698 8.66 Top Ugnu M 9665 4097 1844 8.65 NA 10019 4188 1885 8.65 NB 10138 4219 1898 8.65 NC 10220 4240 1908 8.65 NE 10323 4266 1919 8.65 NF 10485 4308 1938 8.65 Top OA 10607 4339 1952 8.66 Base OA 10745 4372 1967 8.65 Top OB 10970 4407 1983 8.65 Base OB NA 4431 1994 8.66 4.5. l,;asln_Cl/I UDIn_(:l I-'ro_(: ram Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. ~x-~.~( ~:~ t MD/TVDrkb MD/TVDrkb 30" 20" 92# H-40 W el~led ~\ 80' 30'/30' 110'/110' 9-7/8" 7" 26# L-80 I~"T-C-~ t/ 11163' 30' / 30' 11163' / 4415' 6-1/8" OB 4 Y2" 12.6# L-80 IBT-Mod 3637' 11100' / 4412' 14800' / 4415' 6-1/8" OA 4 ~" 12.6# L-80 IBT-Mod 4200' 10516'/4335' 14800'/4337' Schrader Bluff 2001 Program MPC-41 Well Plan 4.6. Cement Calculations Casin~ Size 1 7" 26 Ib/ft L-80 Hydril 521 I BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost This cement job will be pumped in 2 stages with a TAM Port Collar placed at 1000' MD The cement volumes will be confirmed by the acoustic caliper to be run whilst drilling the 9-7/8" hole section Need to ensure that the mud is conditioned to proper specs prior to pumping cement Total Cement Volume: Spacer 75 bbl of Viscosified Spacer (Mudpush XL Design) Weighted to 10.2 ppg Lead 966 sx 760 bbl 10.7 lb/gal Class G Arctic Set III Light Tail 1031 sx 211 bbl 15.8 lb/gal Class G Arctic Set I Temp BHST -80° F from SOR, BHCT 85° F estimated by Dowell 4.7. Survev and Lo_qqinq Proqram 9-7/8" Hole Section: Open Hole: Cased hole: MWD / GR/Res / PWD - (Res. over production interval only) NB. MWD inclination sensor to be placed directly above motor None 6-1/8" Hole Sections: Cased Hole: MWD / GR/Res / PWD / ABI / ABGR - (ABGR will be run if available) None 5. MPC-41 Operations Summary 5.1. Pre-Riq Operations 1. Install 20" conductor 5.2. Procedure 1. MIRU Nabors 22E, NU diverter on 20" conductor, PU 5" drill pipe 2. MU BHA with 9-7/8" milltooth bit, 6 3,4" Sperry MWD/LWD(GR-Res)/PWD/ABI/Caliper and 5" drill pipe 3. Drill 9-7/8" surface hole as per directional plan Tangent angle 75°. Surface hole landed on OB at 91 ° 4. POOH. Reamer trip with Hole opener to TD 5. Condition mud with lubes and spot casing running lube pill prior to 7" casing run. POOH 6. Run 7" casing (with RA tag @ 100' above Top OA Sand and TAM Port Collar @ 1000') to TD. Cement casing to surface Tam Port Collar will be run as a contingency in case cement does not return to surface on first stage 7. Install FMC 11" 5m horizontal wellhead 8. NU 13-5/8" 5m BOP. Test BOP to 2500/250 psi 9. Lay down 5" drill pipe, PU 3 Y2" drill pipe 10. MU BHA with 6-1/8" PDC bit, 4 3,4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe 11. RIH. Drill out float equipment 12. Displace hole to 9.1 lb/gal Bara Drill mud 13. Drill 20' of new hole and perform FIT to > 11.0 lb/gal 14. Drill 6-1/8" OB lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. TD criteria supplied by town 15. POOH. Reamer trip with Hole Opener to TD 16. Displace OB lateral with clean Bara Drill mud 17. 18. 19. 20. 21. 22. 2:3. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Schrader Bluff 2001 Pro~lram MPC-41 Well Plan Run 4 Y2" slotted liner with inner string to OB lateral TD and hang off 100' inside 7" casing Make up Baker Window Master milling assembly with retrievable whipstock and MWD Install whipstock in top of liner hanger. Verify whipstock orientation with MWD Shear off and mill window MU BHA with 6-1/8" PDC bit, 4 3/~,, MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe RIH. Displace hole to clean Bara Drill mud Drill OA horizontal lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. TD criteria supplied by town POOH. Reamer trip with Hole Opener TD. Displace OA lateral with clean Bara Drill mud MU whipstock retrieval tool and MWD. RIH. Orient and jet whipstock face Engage and pull whipstock free RIH with 4 Y~" slotted liner w/bent shoe joint, orient liner into window and run liner to point of hanging off with hookwall hanger Displace 7" casing to 9.1 lb/gal completion fluid (brine) POOH and L/D 3 Y~" drill pipe RIH with 2 7/8" tubing to top of Ist lateral and displace well to seawater Land 2 7/8" tubing, set TWC, ND BOPE and NU X-mas tree, pull TWC Pump enough volume of diesel to displace the annulus and tubing down to 2000' Set TWC and test. Remove TWC and install BPV. Secure well RDMO TREE: FMC 2-9/16" 5M WELLHEAD: FMC Gen 5A System .... 11", 5M csg.head w/ 7" mandrel hanger & packoff 7-1/16" x 11", 5M, tbg spool w/ 7" x 2-7/8" tubing hanger i 113' 120" 92 lb/fi, H-40 Welded I I POST-COMPLETION MP C-41 & C-41 L1 Odg KB elev ss (N22E) = 45.7' 2-7/8", 6.3 Ib/ft, L-80, EUE-M Coupling OD: 3.5" Drift/ID · 2.347"/2.441" Halliburton XN-Nipple (2.205" ID) Tapered Pump: Centdlift 27 stage GC2200 Centdlift 72 stage GC 3500 Centrilift 16 stage GCNPSH Tandem gas seperator Seal section, Model GST#DBIPLPFS 190 HP KMH 2415v/48a Motor .. ,, , I Standard 6 fin centralizer/Pump Mate 7,26#, L-80, Hydrii I ' · Casing Drift: 6.15.1" Casing ID: 6.276 . -~ M ul;:L~t~rGalBjai~tii~ mud below the ES P Baker Hughes Hookwall Hanger @ +/-10,150 ~ "~ .. ~--...~ Liner @ 14,800' MD I Windowin7"casing@10,163'o I ......................... IWell Inclination @ Window = 75 I ~ [~ ~ " ~.~ ~.~ 6-1/8" OA Lateral TD Baker Hughes Hanger @ 11 ~co' /~1 ~_... 4-1/2~5'3m~tedJJ= A . ' ' ' . ~ ~'m~ecLL,mer-a-l~anger -"~------~.._.~_ ~ ~."~ Q -'~, ~ 6-1/8". OB Lateral TD I 11200'-14800'1V~ I ,,,... 4-1/2 Slotted Liner & Hanger DATE REV. BY COMMENTS 4/24/01 Steve Shultz Level 3 Multi-Lateral, 2 718" ESP Completion Milne Point Unit WELL: C-41 ML APl NO: BP Exploration (Alaska) COMPANY DETAILS BP C~k:ul~fio~ Me~'~d: Minimum En~ Sy~,m: ISCWSA ~ ~: Troy Cyl~ ~ ~ s~ E~ * C~ W~mi~ Me~: Ru~ B~ A~OTAT[ONS No. T~ MD A~otation I 200.00 2~.00 SI~ Dir I.~°/1~': 200' MD, 2~'TVD 2 731.60 ?33.33 S~an Dir 2~/1~': 733.3Y MD, ?31.6'TVD 3 989.70 ~5.39 S~n ~r 3°/1~: ~5.39' MD, 989.7'TVD 4 1822.45 1909.46 End Dir: 19~.46' MD, 1822.45'WD 5 1950.00 2067.12 S~ Dir 6°/1~': 2067.12' MD, 1950TVD 6 2317.67 2729.30 End Dir: 2729.Y MD, 2317.6T TVD 7 4351.40 10654.89 St~ Dir 3~/100': 10654.89' MD, 4351.4~D 8 4415.75 11166.94 EndDir :III66.94'MD,~IS.?5'TVD 9 4423.44 12235.58 St~ ~r 3~/100': 12235.58' MD, ~23.~TVD l0 4423.33 12277.60 EndD~: 12277.6' MD, 4423.33'~D II 4406.68 13515.18 St~Dir3°/l~': 13515.18' MD, ~06.68TVD 12 44~.55 13555,05 EndDir: 13555.05'MD,~O6.55'~D 13 4415.50 14800.42 Total ~p~: 14800.42' MD,~I5.5'~D .1500-- REFER.ENCE INFORMATION Co-o~dim~ {N/E} Rekrm~: Well C~uc: Ptan MPC-41. Tru~ No~h V~ical (TVO) R~. 51: 36 I0q.~1~97 IO:.55 46_~O $eet~a~ (VS) R~fe~sce:. ~. (O.OON.O.Oa~) Me~l [X'l~h R~f~z~: 51:56 1005/1997 10'35 46-nO Cak'ulalion kk.0~od: M~mumCu~a~re SURVEY PROGRAM Depth Fm Del~h To .qm'wy/l~n 500.00 14800.42 ~ MPC-41~O4 VI FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1786.50 1865.37 Base Permafrost 2 3777.50 8418.36 Top Ugnu 3 4098.50 9669.32 Top Ugnu M 4 4189.50 10023.95 SchraderNA 5 4220,50 10144.76 SchraderNB 6 4241.50 10226,60 SchraderNC 7 4267,50 10327,92 SchraderNE 8 4309,50 10491.60 SchraderNF 9 4340.50 10612.41 TSBD-OA 10 4373,50 10749.90 TSBC(baseOA) II 4408.50 10986.88 TSBB-OB CASING DETAILS No. TVD MD Name I 4415.70 I ! 153.19 7" 2 4415.50 14800.41 4 1/2" Size 7.000 4.500 Plan: MPC-41 wp04 (Plan MPC-41/Plan MPC-41 ) Tool Created By: Ken Allan Date: 4t25/2001 CB-GYRO-SS Checked: Dale: MWD+IFR+MS .................... Reviewed: Dale: Wig_L DETAILS Plan MPC-4.1 1627.~6 120.21 602~976.00 TARGET DETAILS Nan~ TVD *N/~ +E/-W Na"ff, in8 F.~in8 Shape MPC-GTla 41S2_~0 -7'/$136 20~t24 6021242.04 5~fl24:13 Poim MPC43 T2a 4423__r~) -989437 ~0~.39 6019104.05 .%0948.16 POim MPC4:]T3a 440630 -111,10.12 3037.91 6017861.05 .~61290.18 Poinl MPC43 T4~ 4415~q} -12355.83 336.~.46 6016~8.06 561627.20 Point MI~'43T3 4407_t5 -11068.29 2~6~.04 601703135 _~1120.78 ~ MPC-G T4 4423.49 -1234526 3368.~4 60166~g.66 ~1630.60 Poinl MPC43 T2 442~~~.0 -89TLI5 205.1.66 6020016.03 560287.15 Point MPC43TI4167.17 -8226.42 1752.98 602076433 .~50982.6.1 Poim SECTION DETAILS Sec MD lnc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 46.50 0.00 0.00 46.50 0.00 0.00 0.00 0.00 0.00 2 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 3 733.33 8.00 230.00 731.60 -23.89 -28.48 1.50 230.00 15.57 4 995.39 12.00 210.00 989.70 -59.23 -56.09 2.00 308.88 42.41 5 1909.46 36.00 172.00 1822.45 -414.35 -66.41 3.00 308.21 382.33 6 2067.12 36.00 172.00 1950.00 -506.12 -53.51 0.00 0.00 474.26 7 2729.30 75.13 163.22 2317.67 -1026.24 70.96 6.00 -13.34 1008.81 8 9996.67 75.13 163.22 4182.50 -7751.36 2098.24 0.00 0.00 8030.32 MPC-GTIa 0- 1500- 3000- _~l? Dir 1.5°/100': 200' MD, 200'TVD 1000\ Base Permafrost ' ~ / EndDir :1909.46'MD. 1822.45'TVD ........ ~--~/TSran Dir 6'/100': 2067.12' MD, 1950'TVD End Dir: 2729.3' MD, 2317.67' TVD 2000 ~ . 3000 ' ' ~'~'~ ' '4000~~ ' 4500- ............................................. : All TVD deoths are 60oo- . : ...... ssTVD plus'46. ' for RKBE. -- . 9 10654.89 75.13 163.22 4351.40 -8360.47 2281.85 0.00 0.00 8666.27 10 11153.19 90.00 164.79 4415.70 -8834.14 2417.49 3.00 6.08 9158.93 II 11166.94 89.59 164.80 4415.75 -8847.40 2421.09 3.00 179.15 9172.69 12 12235.58 89.59 164.80 4423.44 -9878.61 2701.34 0.00 0.00 10241.29 13 12251.90 90.00 165.06 4423.50 -9894.37 2705.59 3.00 32.61 10257.61 MPC-GT2a 14 12277.60 90.77 165.07 4423.33 -9919.20 2712.21 3.00 0.37 10283.31 15 13515.18 90.77 165.07 4406.68 -!1114.87 3031.13 0.00 0.00 11520.76 16 13541.33 90.00 164.92 4406.50 -!1140.12 3037.91 3.00 -169.35 11546.91 MPC-G T3a 17 13555,05 89.59 164.92 4406.55 -! 1153.38 3041.48 3.00 179.90 11560.64 18 14800.42 89.59 164.92 4415.50 -12355.83 3365.46 0.00 0.00 12805.97 MPC-GT4a 5000 ~ i Top Ugnu .... · ~ . / Schrader NC o~ ~ - / Scluader NB / Schrader , : Schrader NA NE : 7000 ~ / Top Ugnu M \ \ \ / ,Schrader NF ........ : - - 8000 -'r----._..~. ;:\...\\~ 1-.1-TSBD-OA TSBB-OB · / -' "'ldO ' / : - St~'D[r~J"/T00'-:~I'0b"~4~9~: ~ST"~I'VD l l0~."0~\ ?" 12000 //'-~--13~----- 2~_ ;~g _ --]'4 ~/2" EndDir :!t166.94'MD, 4415.75'TVD II : II ! I s.~ oi~ 3o~100': 12235.58' MD, 4423.44~ I ~ /I : I ; End Dh': 12277.~' MD, 4423.33' TVD ; I J ! / Start'~ir3°/l°0'; 13515'18'MV'4406'68"rVD"I ~ ' / ' ' End Dir: 13555.05' MD, 4406.55' TVD : ...... ' ...... : ............ Total-Depth :-!4800.42' MD, 4415.5' TVD 0 1500 3000 4500 6000 7500 9000 i 0500 12000 13500 Vertical Section at 164.76° [1500fVin] -I0000 -1200O COMPANY DETAILS BP Ammo S~o Me.od: Tmv~ Start Dir 1.5°/100.: 200' MD, 200'TVD 2°/100': 733.33' MD, 731.6TVD P/100': 995.39' MD, 989.7"rVD End Dir: 1909.46' MD, 1822.45' TVD SUm Dir 6°/100': 2067.12' MD, 1950'TVD End Dir: 2729.3' MD, 2317.67' TVD 3OOO RE FERF~ZE INFORMATION Co..oedm~# ~1/~) Reference: Well Cmee: PI~ MPC-II. Venial ('l'~O) R~c~mee: :SI: ~ 1~1~1~7 1~5 ~ ~ ~ S~ - (0~0~1 3500 . 4000 ! End Dh': 1 i 166.94' MD, 4415.75' TVD · · i.--\.. Start Dh. 3°/100': 12235.58' MD, 4423.44'TVD i q~End Dir: 12277.6' MD, 4423.33' TVD i _. ~i~ TotaI Depth: 14800.42' MD, 4415.5' TVD SURVEY PROGRAM Del~hFm Del~hTo Sm'vey~aa FORMATION TOP DETAILS No. TVDPath MDPath Formation ! 1786.501865.37 Base Permafrost 2 3777.508418.36 TopUgnu 3 4098.509669.32 Top Ugnu M 4 4189.5010023.95SchraderNA 5 4220.5010144.76SchraderNB 6 4241.5010226.60SchraderNC 7 4267.5010327.92SchraderNE 8 4309.5010491.60Schrader NF 9 4340.5010612.41TSBD-OA 10 4373.5010749.90TSBC (base OA) i I 4408.5010986.88TSBB-OB CASINO DETAILS No. 'I'VD MD Name I ~4415.70 11153.19 7" 2 4415.50 14800.41 4 1/2" Tool CB-GYRO-SS Plan: MPC-41 wp04 (Plan MPC-41/Plan MPC-41) Crewed By: Ken Allen Dale: 4/25/200 Checked: Da~e: Reviewed: Date: Size 7.000 4.500 WELL DETAILS ~ +N/-S +E/.W l'~o~inS~ L~ti~uaeLo~/~uae Sk~ Ptan MPC-41 1627.~6 120216028976.00 5.~165.53 70'~9'23~'07N 149~31'28.284W N/A TARGET DETAILS Nam TVD +N/-S -+E/.W ~ ~ Shape MPC43TIa 4182~50 -7751J6 209~24 6021242.04 .~324.13 Poin~ MPC-OT2a 4423J0 -9894,17 270~J9 6019104.0~ 560948.16 Po~ MPC-GI'3a 4406.50 -11140.12 3037.91 6017861.05. 561290.18 P~nt MPC-G T4~ 4415J0 -12355.S3 336.¢.46 ~016~48.06 5~1627.20 Point MPC-GT!416'/.17 -8226.42 17.~2.~8 ~20764.33 $$999963 Po~ SECTION DETAILS Sec biD lnc Azi TVD +N/-S +E/-W DLeg TFace ¥$ec Target ! 46.50 0.00 0.00 46.50 0.00 0.00 0.00 0.00 0.00 2 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 3 733.33 8.00 230.00 731.60 -23.89 -28.48 !.50 230.00 15.57 4 995.39 12.00 210.00 989.70 -59.23 -56.09 2.00 308.88 42.41 5 1909.46 36.00 172.00 1822.45 -414.35 -66.41 3.00 308.21 382.33 6 2067.12 36.00 172.00 1950.00 -506.12 -53.51 0.00 0.00 474.26 7 2729.30 75.13 163.22 2317.67 -1026.24 70.96 6.00 -13.34 1008.81 8 9996.67 75.13 163.22 4182.50 -7751.36 2098.24 0.00 0,00 8030.32 MPC-GTIa 9 10654.8975.13 163.22 4351.40 -8360.47 2281.85 0.00 0.00 8666.27 l0 11153.1990.00 164.79 4415.70 -8834.14 2417.49 3.00 6.08 9158.93 II 11166.9489.59 164.80 4415.75 -8847.40 2421.09 3.00 179.15 9172.69 12 12235.5889.59 164.80 4423.44 -9878.61 2701.34 0.00 0.00 10241.29 13 12251.9090.00 165.06 4423.50 -9894.37 2705.59 3.00 32.61 10257.61biPC-GT2a 14 12277.6090.77 165.07 4423.33-9919.20 2712.21 3.00 0.37 10283.31 15 13515.1890.77 165.07 4406.68-11114.87 3031.13 0.00 0.00 11520.76 16 13541.3390.00 164.92 4406.50-i1140.12 3037.91 3.00 -169.3511546.91 biPC-G T3a 17 13555.0589.59 164.92 4406.55o11153.38 3041.48 3.00 179.90 11560.64 18 14800.4289.59 164.92 4415.50-12355.83 3365.46 0.00 0.0012805.97 MPC-GT4a ANNOTATIONS No. TYD ~ Annotation ! 200.00 200.00 Start Dir 1.5°/100*: 200' biD, 200TVD 2 731.60 733.33 StaflDir2°/100': 733.33'biD, 731.6Tv'D 3 989.70 995.39 Start Dir 3°/100.: 995.39' biD, 989.TTVD 4 1822.451909.46 End Dir: 1909.46' MD, 1822.45' TVD 5 1950.002067.12 Start Dir 6°/100': 2067.12' MD, 1950'TVD 6 2317.672729.30 End Dir: 2729.3' MD, 2317.67' TVD 7 4351.4010654.89Start Dir 3°/100': 10654.89' MD, 4351.4'TVD 8 4415.7511166.94EndDir: ilI66.94'MD, 4415.75'TVD 9 4423.4412235.58Start Dir 3°/100' :- 12235.58' MD, 4423.44~rVD 10 4423.3312277.60EndDir: 12277.6' MD, 4423.33'TVD 11 4406.6813515.18StnrtDir3°/100': 13515.18' MD, 4406.68~rVD 12 4406.5513555.05EndDir: 13555.05'MD, 4406.55'TVD 13 4415.5014800.42Total Depth: 14800.42' MD, 4415.5' TVD All TVD depths are ssTVD plus 46.5' for RKBE. 2000 4000 6000 8000 10000 12000 14000 ! 6000 18000 West(-)/East(+) [2000fl/in] BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Welipath: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Ce-ordinate(NE) Reference: Well:' Plan MPC-41, True North Ver~leal (Thy1)) Reference: 51: 36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.76Azi) Plan: MPC-41 wp04 Page: Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ft 6027347.71 ft Latitude: 70 29 7.200 N 558058.04 ft Longitude: 149 31 31.821 W North Reference: True Grid Convergence: 0.45 deg Well: Plan MPC-41 Slot Name: Surface Position: +N/-S 1627.56 ft Northing: 6028976.00 ft Latitude: 70 29 23.207 N +E/-W 120.21 ft Easting: 558165.53 ft Longitude: 149 31 28.284 W Position Uncertainty: 0.00 ft Reference Point: +NI-S 1627.56 ft Northing: 6028976.00 ft Latitude: 70 29 23.207 N +EI-W 120.21 ft Easting: 558165.53 ft Longitude: 149 31 28.284 W Measured Depth: 46.50 ft Inclination: 0.00 deg Vertical Depth: 46.50 ft Azimuth: 0.00 deg Wellpath: Plan MPC-41 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: 51: 36 10/15/1997 10:55 Height 46.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/6/2001 Declination: 26.37 deg Field Strength: 57445 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From fi'VD) +N/-S +E/-W Direction ff ft ft deg 0.00 0.00 0.00 164.76 Plan: MPC-41 wp04 Date Composed: 4/25/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information 46.50 0.00 0.00 46.50 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 0.00 733.33 8.00 230.00 731.60 -23.89 -28.48 1.50 1.50 0.00 230.00 995.39 12.00 210.00 989.70 -59.23 -56.09 2.00 1.53 -7.63 308.88 1909.46 36.00 172.00 1822.45 -414.35 -66.41 3.00 2.63 -4.16 308.21 2087.12 36.00 172.00 1950.00 -506.12 -53.51 0.00 0.00 0.00 0.00 2729.30 75.13 163.22 2317.67 -1026.24 70.96 6.00 5.91 -1.33 -13.34 9996.67 75.13 163.22 4182.50 -7751.36 2098.24 0.00 0.00 0.00 0.00 10654.89 75.13 163.22 4351.40 -8360.47 2281.85 0.00 0.00 0.00 0.00 11153.19 90.00 164.79 4415.70 -8834.14 2417.49 3.00 2.98 0.31 6.08 11166.94 89.59 164.80 4415.75 -8847.40 2421.09 3.00 -3.00 0.04 179.15 12235.58 89.59 164.80 4423.44 -9878.61 2701.34 0.00 0.00 0.00 0.00 12251.90 90.00 165.06 4423.50 -9894.37 2705.59 3.00 2.53 1.62 32.61 12277.60 90.77 165.07 4423.33 -9919.20 2712.21 3.00 3.00 0.02 0.37 13515.18 90.77 165.07 4406.68 -11114.87 3031.13 0.00 0.00 0.00 0.00 13541.33 90.00 164.92 4406.50 -11140.12 3037.91 3.00 -2.95 -0.55 -169.35 13555.05 89.59 164.92 4406.55 -11153.38 3041.48 3.00 -3.00 0.01 179.90 14800.42 89.59 164.92 4415.50 -12355.83 3365.46 0.00 0.00 0.00 0.00 MPC-G Tla MPC-G T2a MPC-G T3a MPC-G T4a Section : Start .MD.~': Incl ..... Azim, .... ,.ft ,,,deg.,.: d~::: ,. 46.50 0.00 0.00 100.00 0.00 0.00 TVD "+N/-S .... :;+E/aW .' VS DLS.~ B'uild Turn TFO ft . .' ,ft,... , :.,.iff..' ,.'.. ft .deg/108ft'deg/lOOftdeg/100ff ."deg · 46.50 °.oo o.oo o.oo o.oo o.oo o.oo o.oo 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP Amoco -( Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 WeUpnth: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Co-ordinate(N~) Reference: Well: Plan MPC-41, True North Verti~l (TVD) Reference: 51: 36 10/15/1997 10:55 46.5 Section tVS) Reference: Well (0.OON,0.00E,164.76Azi) Plan: MPC-41 wp04 Page: 2 Section 1: Start MD Incl Azim TVD +NFS +E/-W VS DIS Build Turn TIrO fl deg deg ft ff ft ff deg/100ft degll00ft deg/100ft deg 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Section 2: Start MD Incl Azim TVD +NI-S +E/-W VS DLS Build Turn TFO ft deg deg tt fl ft ft degllOOft degllOOft decj/lOOft deg 300.00 1.50 230.00 299.99 -0.84 -1.00 0.55 1.50 1.50 0.00 0.00 400.00 3.00 230.00 399.91 -3.36 -4.01 2.19 1.50 1.50 0.00 0.00 500.00 4.50 230.00 499.69 -7.57 -9.02 4.93 1.50 1.50 0.00 0.00 600.00 6.00 230.00 599.27 -13.45 -16.03 8.76 1.50 1.50 0.00 0.00 700.00 7.50 230.00 698.57 -21.01 -25.03 13.69 1.50 1.50 0.00 0.00 733.33 8.00 230.00 -731.60-- .. -23.89 -28.48 15.56 1.50 1.50 0.00 0.00 Section 3: Start .MD Incl Azim TVD. · +NI-S +E/-W VS DLS ' 'Build _ Turn TF0 fl deg deg ft ft ft ft degll00ft degll00ft deg/100ft deg 800.00 8.90 223.27 797.55 -30.63 -35.57 20.20 2.00 1.35 -10.09 -51.12 900.00 10.42 215.50 896.13 -43.62 -46.12 29.96 2.00 1.52 -7.77 -44.47 995.39 12.00 210.00 989.70 -59.23 -56.09 42.40 2.00 1.66 -5.77 -36,80 Section 4: Start MD 'Incl Aztm TVD +N/-S +E/-W VS · DLS Build Turn TFO 'fl 'deg deg ff ff 1000.00 12.09 209.48 994.21 -60.07 -56.57 43.09 3.00 1.87 -11.26 -51.79 1100.00 14.15 199.87 1091.60 -80.68 -65.88 60.53 3.00 2.07 -9.61 -51.28 1200.00 16.51 192.80 1188.05 -106.04 -73.18 83.08 3.00 2.35 -7.07 -41.92 1300.00 19.04 187.51 .. 1283.27 -136.07 -78.46 110.66 3.00 2.53 -5.29 -35.10 1400,00 21.68 183.44 1377.02 -170.69 -81.70 143.21 3.00 2.65 -4,07 -30.06 1500.00 24.41 180.23 1469.04 -209.80 -82.89 180.64 3.00 2.73 -3.21 -26.24 1600.00 27.19 177.63 1559.06 -253.30 -82.03 222.83 3.00 2.78 -2.60 -23.29 1700.00 30.01 175.49 1646.86 -301.06 -79.12 269.68 3.00 2.82 -2.14 -20.95 1800.00 32.86 173.68 1732.18 -352.97 -74.16 321.06 3.00 2.85 -1.81 -19.07 1909.46 36.00 172.00 1822.45 -414.35 -66.41 382.33 3.00 2.87 -1.54 -17.54 Section 5: Start =Mn. ,inel,:..; :~ Azim'. ' ' TVo: +N/-$ +r_d-W ..V$ OLS"." "Build.,..Turn. ' TFO'=,i,:' , · ' "fi, '.de~l'? i:'.:..'deO'., fl... ' fi. fl 'deo/100ff.'deo/100ft de~ll00ff. .,d~:.: .... 2000.00 36.00 172.00 ;1895.70 -467.05 -59.00 435.12 0.00 0.00 0.00 0.00 2067.12 36.00 172.00 1950.00 -506.12 -53,51 474.26 0.00 0.00 0.00 0.00 Section 6: Start . .MD..'lnci. : Azlm . TVD '+NI-S +E/-W VS. "DLS . ' BUild. Turn ' .. TFO' ,, ft' deg. deg ff ff ff ff degll00ft 'deg/10Oft degll00ft ' deg 2100.00 37.92 171.26 1976.27 -525.68 -50.63 493.89 6.00 5.85 -2.25 -13.34 2150.00 40.85 170.25 2014.91 -556.99 -45.52 525.44 6.00 5.86 -2.02 -12.75 2200.00 43.79 169.35 2051.88 -590.11 -39.55 558.97 6.00 5.88 -1.80 -11.97 2250.00 46.74 168.54 2087.07 -624.97 -32.74 594.39 6.00 5.89 -1.61 -11.30 2300.00 49.69 167.81 2120.38 -661.45 -25,10 631.60 6.00 5.90 -1.46 -10.73 2350.00 52.64 167.14 2151.73 -699.46 -16.65 670.50 6.00 5.91 -1.34 -10.25 2400.00 55.60 166.52 2181.04 -738.90 -7.41 710.98 6.00 5.92 -1.24 -9.82 2450.00 58.56 165.94 2208.21 -779.66 2.58 752.93 6.00 5.92 -1.16 -9.46 2500.00 61.52 165.40 2233.18 -821.63 13.30 796.24 6.00 5.93 -1.08 -9.15 2550.00 64.49 164.89 2255.87 -864.68 24.73 840.78 6.00 5.93 -1.03 -8.88 2600.00 67.45 164.40 2276.23 -908.71 36.82 886.44 6.00 5.93 -0.98 -8.64 2650.00 70.42 163.93 2294.20 -953.60 49.56 933.09 6.00 5.94 -0.93 -8.44 2700.00 73.39 163.48 2309.72 -999.21 62.89 980.61 6.00 5.94 -0.90 -8.28 2729.30 75.13 163.22 2317.67 -1026.24 70.96 1008.81 6.00 5.94 -0.89 -8.24 BP Amoco Plnnning Report- Geogrnphic Company: BP Amoco Field: Milne Point Sm: M Pt C Pad Well: Plan MPC-41 WeUpath: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Page: Ce-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51: 36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.76Azi) Plan: MPC-41 wp04 2800.00 75.13 163.22 2335.81 -1091.66 90.69 1077.12 0.00 0.00 0.00 0.00 2900.00 75.13 163.22 2361.48 -1184.20 118.59 1173.73 0.00 0.00 0.00 0.00 3000.00 75.13 163.22 2387.14 -1276.73 146.49 1270.35 0.00 0.00 0.00 0.00 3100.00 75.13 163.22 2412.80 -1369.27 174.40 1366.96 0.00 0.00 0.00 0.00 3200.00 75.13 163.22 2438.46 -1461.81 202.30 1463.58 0.00 0.00 0.00 0.00 3300.00 75.13 163.22 2464.13 -1554.34 230.20 1560.20 0.00 0.00 0.00 0.00 3400.00 75.13 163.22 2489.79 -1646.88 258.10 1656.81 0.00 0.00 0.00 0.00 3500.00 75.13 163.22 2515.45 -1739.41 286.01 1753.43 0.00 0.00 0.00 0.00 3600.00 75.13 163.22 2541.11 -1831.95 313.91 1850.04 0.00 0.00 0.00 0.00 3700.00 75.13 163.22 2566.78 -1924.48 341.81 1946.66 0.00 0.00 0.00 0.00 3800.00 75.13 163.22 2592.44 -2017.02 369.72 2043.28 0.00 0.00 0.00 0.00 3900.00 75.13 163.22 2618.10 -2109.56 397.62 2139.89 0.00 0.00 0.00 0.00 4000.00 75.13 163.22 2543.77 -2202.09 425.52 2236.51 0.00 0.00 0.00 0.00 4100.00 75.13 163.22 2669.43 -2294.63 453.43 2333.12 0.00 0.00 0.00 0.00 4200.00 75.13 163.22 2695.09 -2387.16 481.33 2429.74 0.00 0.00 0.00 0.00 4300.00 75.13 163.22 2720.75 -2479.70 509.23 2526.36 0.00 0.00 0.00 0.00 4400.00 75.13 163.22 2746.42 -2572.23 537.13 2622.97 0.00 0.00 0.00 0.00 4500.00 75.13 163.22 2772.08 -2664.77 565.04 2719.59 0.00 0.00 0.00 0.00 4600.00 75.13 163.22 2797.74 -2757.31 592.94 2816.20 0.00 0.00 0.00 0.00 4700.00 75.13 163.22 2823.40 -2649.84 620.84 2912.82 0.00 0.00 0.00 0.00 4800.00 75.13 163.22 2849.07 -2942.38 648.75 3009.44 0.00 0.00 0.00 0.00 4900.00 75.13 163.22 2874.73 -3034.91 676.65 3106.05 0.00 0.00 0.00 0.00 5000.00 75.13 163.22 2900.39 -3127.45 704.55 3202.67 0.00 0.00 0.00 0.00 5100.00 75.13 163.22 2926.06 -3219.98 732.45 3299.29 0.00 0.00 0.00 0.00 5200.00 75.13 163.22 2951.72 -3312.52 760.36 3395.90 0.00 0.00 0.00 0.00 5300.00 75.13 163.22 2977.38 -3405.05 788.26 3492.52 0.00 0.00 0.00 0.00 5400.00 75.13 163.22 3003.04 -3497.59 816.16 3589.13 0.00 0.00 0.00 0.00 5500,00 75.13 163.22 3028.71 -3590.13 844.07 3685.75 0.00 0.00 0.00 0.00 5600.00 75.13 163.22 3054.37 -3682.66 871.97 3782.37 0.00 0.00 0.00 0.00 5700.00 75..13 163.22 3080.03 -3775.20 899.87 3878.98 0.00 0.00 0.00 0.00 5800.00 75.13 163.22 3105.69 -3867.73 927.78 3975.60 0.00 0.00 0.00 0.00 5900.00 75.13 163.22 3131.36 -3960.27 955.68 4072.21 0.00 0.00 0.00 0.00 6000.00 75.13 163.22 3157.02 -4052.80 983.58 4168.83 0.00 0.00 0.00 0.00 6100.00 75.13 163.22 3182.68 -4145.34 1011.48 4265.45 0.00 0.00 0.00 0.00 6200.00 75.13 163.22 3208.34 -4237.88 1039.39 4362.06 0.00 0.00 0.00 0.00 6300.00 75.13 163.22 3234.01 -4330.41 1067.29 4458.68 0.00 0.00 0.00 0.00 6400,00 75.13 163.22 3259.67 -4422.95 1095.19 4555.29 0.00 0.00 0.00 0.00 6500.00 75.13 163.22 3285.33 -4515.48 1123.10 4651.91 0.00 0.00 0.00 0.00 6600.00 75.13 163.22 3311.00 -4608.02 1151.00 4748.53 0.00 0.00 0.00 0.00 6700.00 75.13 163.22 3336~66 -4700.55 1178.90 4845.14 0.00 0.00 0.00 0.00 6800.00 75.13 163.22 3362.32 -4793,09 1206.80 4941.76 0.00 0.00 0.00 0.00 6900,00 75.13 163.22 3387.98 -4885.63 1234.71 5038.37 0.00 0.00 0.00 0.00 7000.00 75.13 163.22 3413.65 -4978.16 1262.61 5134.99 0.00 0.00 0.00 0.00 7100.00 75.13 163.22 3439.31 -5070.70 1290.51 5231.61 0.00 0.00 0.00 0.00 7200.00 75.13 163.22 3464.97 -5163.23 1318.42 5328.22 0.00 0.00 0.00 0.00 7300.00 75.13 163.22 3490.63 -5255.77 1346.32 5424.84 0.00 0.00 0.00 0.00 7400.00 75.13 163.22 3516.30 -5348.30 1374.22 5521.46 0.00 0.00 0.00 0.00 7500.00 75.13 163.22 3541.96 -5440.84 1402.13 5618.07 0.00 0.00 0.00 0.00 7600.00 75.13 163.22 3567.62 -5533.38 1430.03 5714.69 0.00 0.00 0.00 0.00 7700.00 75.13 163.22 3593.28 -5625.91 1457.93 5811.30 0.00 0.00 0.00 0.00 7800.00 75.13 163.22 3618.95 -5718.45 1485.83 5907.92 0.00 0.00 0.00 0.00 7900.00 75.13 163.22 3644.61 -5810.98 1513.74 6004.54 0.00 0.00 0.00 0.00 8000.00 75.13 163.22 3670.27 -5903.52 1541.64 6101.15 0.00 0.00 0.00 0.00 8100.00 75.13 163.22 3695.94 -5996.05 1569.54 6197.77 0.00 0.00 0.00 0.00 8200.00 75.13 163.22 3721.60 -6088.59 1597.45 6294.38 0.00 0.00 0.00 0.00 8300.00 75.13 163.22 3747.26 -6181.13 1625.35 6391.00 0.00 0.00 0.00 0.00 8400.00 75.13 163.22 3772.92 -6273.66 1653.25 6487.62 0.00 0.00 0.00 0.00 8500.00 75.13 163.22 3798.59 -6366.20 1681.15 6584.23 0.00 0.00 0.00 0.00 8600.00 75.13 163.22 3824.25 -6458.73 1709.06 6680.85 0.00 0.00 0.00 0.00 8700.00 75.13 163.22 3849.91 -6551.27 1736.96 6777.46 0.00 0.00 0.00 0.00 8800.00 75.13 163.22 3875.57 -6643.80 1764.86 6874.08 0.00 0.00 0.00 0.00 8900.00 75.13 163.22 3901.24 -6736.34 1792.77 6970.70 0.00 0.00 0.00 0.00 9000.00 75.13 163.22 3926.90 -6828.88 1820.67 7067.31 0.00 0.00 0.00 0.00 9100.00 75.13 163.22 3952.56 -6921.41 1648.57 7163.93 0.00 0.00 0.00 0.00 Section 7: Start MD Incl Azim TVD +NI-S +E/-W VS DLS Build Turn TFO ft deg deg ft ff ft ff deg/100ft deg/100ft deg/100ft deg BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpatb: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Page: 4 Ce-erdinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51: 36 10/15/1997 10:55 46.5 Sectleu (VS) Reference: Well (0.00N,0.00E,164.76Azi) Phn: MPC-41 wp04 Section 7: Start MD lncl Azlm TVD +N/-S +E/-W VS DIS Build Turn TFO ff deg deg fl ft ft deg/10Oft deg/10Oft deg/100ft deg 9200.00 75.13 163.22 3978.22 -7013.95 1876.48 7260.55 0.00 0.00 0.00 0.00 9300.00 75.13 163.22 4003.89 -7106.48 1904.38 7357.16 0.00 0.00 0.00 0.00 9400.00 75.13 163.22 4029.55 -7199.02 1932.28 7453.78 0.00 0.00 0.00 0.00 9500.00 75.13 163.22 4055.21 -7291.55 1960.18 7550.39 0.00 0.00 0.00 0.00 9600.00 75.13 163.22 4080.88 -7384.09 1988.09 7647.01 0.00 0.00 0.00 0.00 9700.00 75.13 163.22 4106.54 -7476.63 2015.99 7743.63 0.00 0.00 0.00 0.00 9800.00 75.13 163.22 4132.20 -7569.16 2043.89 7840.24 0.00 0.00 0.00 0.00 9900.00 75.13 163.22 4157.86 -7661.70 2071.80 7938.86 0.00 0.00 0.00 0.00 9996.67 75.13 163.22 4182.50 -7751.36 2098.24 8030.32 0.00 0.00 0.00 0.00 Section 8: Start MD InCl Azim ' TVD.--'-' * +N/-S +E/-W VS 'DLS . :Build., Turn* TFO fl . . deg. . :fl ' ;. ff ft fl . degll00ft deg/100ft deg/1.00ft, deg 10000.00 75.13 163.22 4183.35 -7754.44 2099.17 8033.54 0.00 0.00 0.00 0.00 10100.00 75.13 163.22 4209.02 -7846.98 2127.07 8130.15 0.00 0.00- 0.00 0.00 10200.00 75.13 163.22 4234.68 -7939.51 2154.98 8226.77 0.00 0.00" 0.00 0.00 10300.00 75.13 163.22 4260.34 -8032.05 2182.88 8323.38 0.00 0.00 0.00 0.00 10400.00 75.13 163.22 4286.01 -8124.58 2210.78 8420.00 0.00 0.00 0.00 0.00 10500.00 75.13 163.22 4311.67 -8217.12 2238.68 8516.62 0.00 0.00 0.00 0.00 10600.00 75.13 163.22 4337.33 -8309.66 2266.59 8613.23 0.00 0.00 0.00 0.00 10654.89 75.13 163.22 4351.40 -8360.47 2281.85 8666.27 0.00 0.00 0.00 0.00 Section 9: Start MD lncl Azim TVD +NI-S +E/-W VS . DLS Build ' Turn TFO ft deg deg ft ff ft ft deg/100ft degll00ft deg/100ft deg 10700.00 76.48 163.37 4362.46 -8402.36 2294.42 8709.99 3.00 2.98 0.33 6.08 10800.00 79.46 163.69 4383.31 -8496.13 2322.15 8807.76 3.00 2.98 0.32 6.04 10900.00 82.44 164.00 4399.03 -8590.98 2349.62 8906.49 3.00 2.98 0.31 5.98 11000.00 85.43 164.31 4409.60 -8686.63 2376.76 9005.91 3.00 2.98 0.31 5.93 11100.00 88.41 164.62 4414.97 -8782.83 2403.50 9105.76 3.00 2.98 0.31 5.89 11153.19 90.00 164.79 4415.70 -8834.14 2417.49 9158.94 3.00 2.99 0.32 6.03 Section 10: Start MD Incl' ' Az ira. ,..TVD.. +Ni-S .. +E/-W .VS. 'DLS :Build.' ..TUrn' TFO :. . ff deg... . deg. : "a .. ff . ff. ff degll00ftdeg/100ft.: degl100ft 11166.94 89.59 164.80 4415.75 -8847.40 * 2421.09 9172.68 2.98 -2.98 0.07 178.60 Section 11: Start MD' . Incl Azim ' .: TVD' +NI2S '.' ' +E/'-W ' "VS DLs '.'"?BUild` Turn" ft .,deg. :. deg]' .,ft' iff .,:. ft ff .... degllOOft d~l,lOOff deg!lOOft'deg:' 11200.00 89.59 164.80 4415.99 -8879.30 2429.76 9205.74 0.00 0.00 0.00 0.00 11300.00 89.59 1 64.80 4416.70 -8975.80 2455.98 9305.74 0.00 0.00 0.00 0.00 11400.00 89.59 1 64.80 4417.42 -9072.30 2482.19 9405.73 0.00 0.00 0.00 0.00 11500.00 89.59 164.80 4418.13 -9168.80 2508.41 9505.73 0.00 0.00 0.00 0.00 11600.00 89.59 1 64.80 4418.85 -9265.30 2534.63 9605.73 0.00 0.00 0.00 0.00 11700.00 89.59 164.80 4419.56 -9361.80 2560.85 9705.73 0.00 0.00 0.00 0.00 11800.00 89.59 164.80 4420.28 -9458.30 2587.07 9805.72 0.00 0.00 0.00 0.00 11900.00 89.59 1 64.80 4421.00 -9554.80 2613.29 9905.72 0.00 0.00 0.00 0.00 12000.00 89.59 164.80 4421.71 -9651.30 2639.50 10005.72 0.00 0.00 0.00 0.00 12100.00 89.59 164.80 4422.43 -9747.80 2665.72 10105.72 0.00 0.00 0.00 0.00 12200.00 89.59 164.80 4423.14 -9844.29 2691.94 10205.71 0.00 0.00 0.00 0.00 12235.58 89.59 164.80 4423.44 -9878.61 2701.34 10241.29 0.00 0.00 0.00 0.00 Section 12: Start MD Incl Aztm TVD '+NI,S +E/-W VS . DLS BUild. Turn TFO ff deg .. deg 'ff ff '. ff' ff degllOOft deg!lOOff degliOOft deg 12251.90 90.00 165.06 4423.50 -9894.37 2705.59 10257.62 2.97 2.51 1.59 32.38 BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MFS-41 Date: 4/25/2001 Time: 08:51:36 Page: Co-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51: 36..10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E, 164:76Azi) Phn: MPC-41 wp04 Section 13: Start MD Incl Azlm TVD +NFS +EJ-W VS DLS Build . Turn TFO ft deg deg fl ft ff fl ., deg/lOOff deg/lOOft deg/lOOft deg 12277.60 90.77 165.07 4423.33 -9919.20 2712.21 10283.31 3.00 3.00 0.04 0.74 Section 14: Start MD lncl Azim TVD +N/-S +E/-W VS i DLS Build. Turn TFO ft deg . deg ff ft ft ft deg/100ft deg/100ft deg/100ft deg 12300.00 90.77 165.07 4423.03 -9940.84 2717.98 10305.71 0.00 0.00 0.00 180.00 12400.00 90.77 165.07 4421.69 -10037.46 2743.74 10405.70 0.00 0.00 0.00 180.00 12500.00 90.77 165.07 4420.34 -10134.07 2769.50 10505.69 0.00 0.00 0.00 180.00 12600.00 90.77 165.07 4419.00 -10230.69 2795.27 10605.68 0.00 0.00 0.00 180.00 12700.00 90.77 165.07 4417,65 -10327.30 2821.03 10705.67 0,00 0.00 0.00 180.00 12800.00 90.77 165.07 4416.31 -10423.92 2846.79 10805.66 0.00 0.00 0.00 180.00 12900.00 90.77 165.07 4414.97 -10520.53 2872.55 10905.65 0.00 0.00 0.00 180.00 13000.00 90.77 165.07 4413.62 -10617.15 2898.31 11005.64 0.00 0.00 0.00 180.00 13100.00 90.77 165.07 4412.28 -10713.77 2924.07 11105.63 0.00 0.00 0.00 180.00 13200.00 90.77 165.07 4410.93 -10810.38 2949.83 11205.62 0.00 0.00 0.00 180.00 13300.00 90.77 165.07 4409.59 -10907.00 2975.60 11305.61 0.00 0.00 0.00 180.00 13400.00 90.77 165.07 4408.25 -11003.61 3001.36 11405.59 0.00 0.00 0.00 180.00 13500.00 90.77 165.07 4406.90 -11100.23 3027.12 11505.58 0.00 0.00 0.00 180,00 13515.18 90.77 165.07 4406.68 -11114.87 3031.13 11520.77 0.00 0.00 0.00 180.00 Section 15: Start MD Incl Azim TVD +N/-S +FJ-W VS . DLS..= BUild Turn TFo fl deg deg . fl fl ff : fl degll00ft degll00ft deg/100ft deg 13541.33 90.00 164.92 4406.50 -11140.12 3037.91 11546.91 3.00 -2.94 -0.57 -168.98 Section 16: Start ,MD . Incl . Azlm TVD +N/-S. .... +E/.W , VS., ' · ,DLS ,~ Build , 'Turn TF0 ' ft ,deg .. deg: ft . ff .:.. fl....' 'deg/100ft...:d~/100ff deg/100ft .. deg'..' 13555.05 89.59 164.92 4406.55-11153.38 3041.48 11560.64 2.99 -2.99 0.00 180.00 Section 17: Start "' Ml) "' in¢! ': :: ;:Azim ' TVD '. '. '+N/,$ ; ":.+E/;W. ': "V$ '"' .:.:'~.. DLS' .' .. BUild". i . .'Turn TFO.': ...fi: .." 'i:..:deg :.:.deg":.:.:: : fi:' fi.'. :'.'.'::' fl. '/ :: i:: .=. ':degll~.de~100ff deg/100ft 'd~:i 13600.00 89.59 164.92 4406.87 -11196.78 3053.17 11605.59 0.00 0.00 0.00 0.00 13700.00 89.59 164.92 4407.59 -11293.33 3079.19 11705.59 0.00 0.00 0.00 0.00 13800.00 89.59 164.92 4408.30 -11389.89 3105.21 11805.59 0.00 0.00 0.00 0.00 13900.00 89.59 164.92 4409.02 -11486.44 3131.22 11905.58 0.00 0.00 0,00 0.00 14000.00 89.59 164.92 4409.73 -11583.00 3157.24 12005.58 0.00 0.00 0.00 0.00 14100.00 89.59 164.92 4410.45 -11679.55 3183.25 12105.58 0.00 0.00 0.00 0.00 14200.00 89.59 164.92 4411.17 -11776.10 3209.27 12205.57 0.00 0.00 0.00 0.00 14300.00 89.59 164.92 4411.88 -11872.66 3235.29 12305.57 0.00 0.00 0.00 0.00 14400.00 89.59 164.92 4412.60 -11969.21 3261.30 12405.57 0.00 0.00 0.00 0.00 14500.00 89.59 164.92 4413.31 -12065.77 3287.32 12505.57 0.00 0.00 0.00 0.00 14600.00 89.59 164.92 4414.03 -12162.32 3313.34 12605.56 0.00 0.00 0.00 0.00 14700.00 89.59 164.92 4414.74 -12258.87 3339.35 12705.56 0.00 0.00 0.00 0.00 14800.42 89.59 164.92 4415.50 -12355.83 3365.46 12805.97 0.00 0.00 0.00 0.00 Survey , Map .. ..'Map: ' Latitude ---> ,, ,<-, Longitude --> . 'MD' ,"Incl Azlm TVD. +N/.S..:+E/-W ~ .NOrthing ,:.:Easting. ::Deg~Min'.'Sec . , Deg:Min ::Sec' ff deg deg' ft ff ff ff :'ft .= .. 46.50 0.00 0.00 46.50 0.00 0.00 6028976.00 558165.53 70 29 23.207 N 149 31 28.284 W 100.00 0.00 0.00 100.00 0.00 0.00 6028976.00 558165.53 70 29 23.207 N 149 31 28.284 W 200.00 0.00 0.00 200.00 0.00 0.00 6028976.00 558165.53 70 29 23.207 N 149 31 28,284 W 300.00 1.50 230.00 299.99 -0.84 -1.00 6028975.15 558164.53 70 29 23.199 N 149 31 28.314 W 400.00 3.00 230.00 399.91 -3.36 -4.01 6028972.60 558161.55 70 29 23.174 N 149 31 28.402 W 500.00 4.50 230.00 499.69 -7.57 -9.02 6028968.36 558156.57 70 29 23.132 N 149 31 28.550 W 600.00 6.00 230.00 599.27 -13.45 -16.03 6028962.43 558149.61 70 29 23.075 N 149 31 28.756 W BP Amoco Planning Report- Geographic Cempany: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Pa~e: · Ce-erdiaate(NE) Refereace: Well: ~n M~I, Tree N~ .v~! ~) Ref~n~: 51: ~ 1~1~1~7 10:55 ~.5 ~n ~S) R~emn~: W~l (0.~N,0.~E,I~.7~) P~n: M~41 ~ Survey Map Map <-- Latitude --> <--- Longitude 2_> MD Incl Azlm TVD +N/--S +F_,/-W Non'thing Easting Deg Min Sec Deg Min Sec ff deg deg ff ft ff ft ff 700.00 7.50 230.00 698.57 -21.01 -25.03 733.33 8.00 230.00 731.60 -23.89 -28.48 800.00 8.90 223.27 797.55 -30.63 -35.57 900.00 10.42 215.50 896.13 -43.62 -46.12 995.39 12.00 210.00 989.70 -59.23 -56.09 1000.00 12.09 209.48 994.21 -60.07 -56.57 1100.00 14.15 199.87 1091.60 -80.68 -65.88 1200.00 16.51 192.80 1188.05 -106.04 -73.18 1300.00 19.04 187.51 1283.27-_- .. -136.07 -78.48 1400.00 21.68 183.44 1377.02' -170.69 -81.70 1500.00 24.41 180.23 1469.04 - -209.80 -82.89 1600.00 27.19 177.63 1559.06 -253.30 -82.03 1700.00 30.01 175.49 1646.86 -301.06 -79.12 1800.00 32.86 173.68 1732.18 -352.97 -74.16 1909.46 36.00 172.00 1822.45 -414.35 -66.41 2000.00 36.00 172.00 1895.70 -467.05 -59.00 2067.12 36.00 172.00 1950.00 -506.12 -53.51 2100.00 37.92 171.26 1976.27 -525.68 -50.63 2150.00 40.85 170.25 2014.91 -556.99 -45.52 2200.00 43.79 169.35 2051.88 -590.11 -39.55 2250.00 46.74 168.54 2087.07 -624.97 -32.74 2300.00 49.69 167.81 2120.38 -661.45 -25.10 2350.00 52.64 167.14 2151.73 -699.46 -16.65 2400.00 55.60 166.52 2181.04 -738.90 -7.41 2450.00 58.56 165.94 2208.21 -779.66 2.58 2500.00 61.52 165.40 2233.18 -821.63 13.30 2550.00 64.49 164.89 2255.87 -864.68 24.73 2600.00 67.45 164.40 2276.23 -908.71 36.82 2650.00 70.42 163.93 2294.20 -953.60 49.56 2700.00 73.39 163.48 2309.72 -999.21 62.89 2729.30 75.13 163.22 2317.67 -1026.24 70.96 2800.00 75.13 163.22 2335.81 -1091.66 90.69 2900.00 75.13 163.22 2361.48 -1184.20 118.59 3000.00 75.13 163.22 2387.14 -1276.73 146.49 3100.00 75.13 163.22 2412.80 -1369.27 174.40 3200.00 75.13 163.22 2438.46 -1461.81 202.30 3300.00 75.13 163.22 2464.13 -1554.34 230.20 3400.00 75.13 163.22 2489.79 -1 646.88 258.10 3500.00 75.13 163.22 2515.45 -1739.41 286.01 3600.00 75.13 163.22 2541.11 -1831.95 313.91 3700.00 75.13 163.22 2566.78 -1924.48 341.81 3800.00 75.13 163.22 2592.44 -2017.02 369.72 3900.00 75.13 163.22 2618.10 -2109.56 397.62 4000.00 75.13 163.22 2643.77 -2202.09 425.52 4100.00 75.13 163.22 2669.43 -2294.63 453.43 4200.00 75.13 163.22 2695.09 -2387.16 481.33 4300.00 75.13 163.22 2720.75 -2479.70 509.23 4400.00 75.13 163.22 2746.42 -2572.23 537.13 4500.00 75.13 163.22 2772.08 -2664.77 565.04 4600.00 75.13 163.22 2797.74 -2757.31 592.94 4700.00 75.13 163.22 2823.40 -2849.84 620.84 4800.00 75.13 163.22 2849.07 -2942.38 648.75 4900.00 75.13 163.22 2874.73 -3034.91 676.65 6028954.80 558140.66 70 29 23.000 N 149 31 29.021 W 6028951.89 558137.24 70 29 22.972 N 149 31 29.122 W 6028945.10 558130.21 70 29 22.906 N 149 31 29.331 W 6028932.03 558119.76 70 29 22.778 N 149 31 29.641 W 6028916.34 558109.91 70 29 22.624 N 149 31 29.935 W 6028915.50 558109.44 70 29 22.616 N 149 31 29.949 W 6028894.81 558100.29 70 29 22.413 N 149 31 30.223 W 6028869.40 558093.19 70 29 22.164 N 149 31 30.438 W 6028839.33 558088.14 70 29 21.869 N 149 31 30.593 W 6028804.70 558085.18 70 29 21.528 N 149 31 30.688 W 6028765.58 558064.29 70 29 21.144 N 149 31 30.723 W 6028722.09 558085.49 70 29 20.716 N 149 31 30.698 W 6028674.35 558088.78 70 29 20.246 N 149 31 30.612 W .. 6028622.50 558094.14 70 29 19.735 N 149 31 30.466 W 6028561.18 558102.37 70 29 19.132 N 149 31 30.238 W 6028508.55 558110.19 70 29 18.614 N 149 31 30.020 W 6028469.53 558115.99 70 29 18.229 N 149 31 29.859 W 6028449.99 558119.02 70 29 18.037 N 149 31 29.774 W 6026418.73 558124.37 70 29 17.729 N 149 31 29.624 W 6028385.65 558130.60 70 29 17.403 N 149 31 29.448 W 6028350.86 558137.68 70 29 17.060 N 149 31 29.248 W 6028314.44 558145.61 70 29 16.702 N 149 31 29.023 W 6028276.49 558154.36 70 29 16.328 N 149 31 28.774 W 6028237.13 558163.90 70 29 15.940 N 149 31 28.502 W 6028196.46 558174.21 70 29 15.539 N 149 31 28.208 W 6028154.58 558185.26 70 29 15.126 N 149 31 27.893 W 6028111.62 558197.02 70 29 14.703 N 149 31 27.557 W 6028067.69 558209.46 70 29 14.270 N 149 31 27.201 W 6028022.91 558222.54 70 29 13.828 N 149 31 26.826 W 6027977.41 558236.23 70 29 13.380 N 149 31 26.434 W 6027950.45 558244.51 70 29 13.114 N 149 31 26.197 W 6027885.18 558264.74 70 29 12.471 N 149 31 25.616 W 6027792.88 558293.37 70 29 11.561 N 149 31 24.795 W 6027700.57 558321.99 70 29 10.650 N 149 31 23.974 W 6027608.27 558350.61 70 29 9.740 N 149 31 23.154 W 6027515.96 558379.24 70 29 8.830 N 149 31 22.333 W 6027423.66 556407.86 70 29 7.920 N 149 31 21.512 W 6027331.35 556436.48 70 29 7.010 N 149 31 20.691 W 6027239.04 558465.11 70 29 6.100 N 149 31 19.870 W 6027146.74 556493.73 70 29 5.190 N 149 31 19.050 W 6027054.43 558522.35 70 29 4.280 N 149 31 18.229 W 6026962.13 558550.98 70 29 3.370 N 149 31 17.408 W 6026869.82 558579.60 70 29 2.460 N 149 31 16.588 W 6026777.52 558608.22 70 29 1.550 N 149 31 15.767 W 6026685.21 558638.85 70 29 0.640 N 149 31 14.946 W 6026592.90 558665.47 70 28 59.730 N 149 31 14.126 W 6026500.60 558694.09 70 28 58.819 N 149 31 13.305 W 6026408.29 558722.71 70 28 57.909 N 149 31 12.484 W 6026315.99 558751.34 70 28 56.999 N 149 31 11.664 W 6026223.68 558779.96 70 28 56.089 N 149 31 10.843 W 6026131.38 558808.58 70 28 55.179 N 149 31 10.023 W 6026039.07 556837.21 70 28 54.269 N 149 31 9.202 W 6025946.76 556865.83 70 28 53.359 N 149 31 8.382 W BP Amoco Planning Report- Geographic Cempany: BP Am(xx) Fkld: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36' Ce-ordinate(NE) Reference: Well: Plan MPC-41, Tree North Vertical (TVD) Reference: 51: 36 10/15/1997 10:55 46.5 Scetlen (V$) Reference: Well (0.00N,0.00E,164.76Azi) Plan: MPC-41 wp04 Page: 7 Survey Map Map <--- Latitude ---> <--- Longitude MD Incl Azim TVD +N/-S +E/-W Northing Easting. Deg Min Sec DegMln Sec ff deg deg ft ff fl ff ft 5000.00 75.13 163.22 2900.39 -3127.45 704.55 6025854.46 558894.45 70 28 52,449 N 149 31 7.561 W 5100.00 75.13 163.22 2926.06 -3219.98 732.45 6025762.15 558923.08 70 28 51.539 N 149 31 6.741 W 5200.00 75.13 163.22 2951.72 -3312.52 760.36 6025669.85 558951.70 70 28 50,629 N 149 31 5,921 W 5300.00 75.13 163.22 2977.38 -3405.05 788.26 6025577.54 558980.32 70 28 49,719 N 149 31 5,100 W 5400.00 75.13 163.22 3003.04 -3497.59 816.16 6025485.24 559008.95 70 28 48.809 N 149 31 4.280 W 5500.00 75.13 163.22 3028.71 -3590.13 844.07 6025392.93 559037.57 70 28 47,898 N 149 31 3,459 W 5600.00 75.13 163.22 3054.37 -3682.66 871.97 6025300.62 559066.19 70 28 46,988 N 149 31 2,639 W 5700.00 75.13 163.22 3080.03 -3775.20 899.87 6025208.32 559094.82 70 28 46,078 N 149 31 1,819 W 5800.00 75.13 163.22 3105.69 -3867.73 927.78 6025116.01 559123.44 70 28 45,168 N 149 31 0,999 W 5900.00 75.13 163.22 3131.36 -3960.27 955.68 6025023.71 559152.06 70 28 44,258 N 149 31 0,178 W 6000.00 75.13 163.22 3157.02 -4052.80 983.58 6024931.40 559180.69 70 28 43,348 N 149 30 59,358 W 6100.00 75.13 163.22 3182.68 -4145.34 1011.48 6024839.10 559209.31 70 28 42,438 N 149 30 58,538 W 6200.00 75.13 163.22 3208.34 -4237.88 1039.39 6024746.79 559237.93 70 28 41,528 N 149 30 57,718 W 6300.00 75.13 163.22 3234.01 -4330.41 1067.29 6024654.48 559266.55 70 28 40,618 N 149 30 56,897 W 6400.00 75.13 163.22 3259.67 -4422.95 1095.19 6024562.18 559295.18 70 28 39,708 N 149 30 56,077 W 6500.00 75.13 163.22 3285.33 -4515.48 1123.10 6024469.87 559323.80 70 28 38,797 N 149 30 55,257 W 6600.00 75.13 163.22 3311.00 -4608.02 1151.00 6024377.57 559352.42 70 28 37,887 N 149 30 54,437 W 6700.00 75.13 163.22 3336.66 -4700.55 1178.90 6024285.26 559381.05 70 28 36.977 N 149 30 53,617 W 6800.00 75.13 163.22 3362.32 -4793.09 1206.80 6024192.96 559409.67 70 28 36,067 N 149 30 52,797 W 6900.00 75.13 163.22 3387.98 -4885.63 1234.71 6024100.65 559438.29 70 28 35.157 N 149 30 51,977 W 7000.00 75.13 163.22 3413.65 -4978.16 1262.61 6024008.34 559466.92 70 28 34.247 N 149 30 51,157 W 7100.00 75.13 163.22 3439.31 -5070.70 1290.51 6023916.04 559495.54 70 28 33,337 N 149 30 50,337 W 7200.00 75.13 163.22 3464.97 -5163.23 1318,42 6023823.73 559524.16 70 28 32,427 N 149 30 49,517 W 7300.00 75.13 163.22 3490.63 -5255.77 1346.32 6023731.43 559552.79 70 28 31.517 N 149 30 48,697 W 7400.00 75.13 163.22 3516.30 -5348.30 1374.22 6023639.12 559581.41 70 28 30,606 N 149 30 47,877 W 7500.00 75.13 163.22 3541.96 -5440.84 1402.13 6023546,82 559610.03 70 28 29,696 N 149 30 47,057 W 7600.00 75.13 163.22 3567.62 -5533.38 1430.03 6023454.51 559638.66 70 28 28,786 N 149 30 46.237 W 7700.00 75.13 163.22 3593.28 -5625.91 1457.93 6023362.20 559667.28 70 28 27,876 N 149 30 45,417 W 7800.00 75.13 163.22 3618.95 -5718.45 1485.83 6023269.90 559695.90 70 28 26.966 N 149 30 44,597 W 7900.00 75.13 163.22 3644.61 -5810.98 1513.74 6023177.59 559724.53 70 28 26,056 N 149 30 43,777 W 8000.00 75.13 163.22 3670.27 -5903.52 1541.64 6023085.29 559753.15 70 28 25,146 N 149 30 42,957 W 8100.00 75.13 163.22 3695.94 -5996.05 1589.54 6022992.98 559781.77 70 28 24,236 N 149 30 42,137 W 8200.00 75.13 163.22 3721.60 -6088.59 1597.45 6022900.68 559810.39 70 28 23,325 N 149 30 41,318 W 8300.00 75.13 163.22 3747.26 -6181.13 1625.35 6022808.37 559839.02 70 28 22,415 N 149 30 40,498 W 8400.00 75.13 163.22 3772.92 -6273.66 1653.25 6022716.06 559867.64 70 28 21,505 N 149 30 39,678 W 8500.00 75.13 163.22 3798.59 -6366.20 1681.15 6022623.76 559896.26 70 28 20,595 N 149 30 38,858 W 8600.00 75.13 163.22 3824,25 -6458.73 1709.06 6022531.45 559924.89 70 28 19,685 N 149 30 38,039 W 8700.00 75.13 163.22 3849.91 -6551.27 1736.96 6022439.15 559953.51 70 28 18,775 N 149 30 37,219 W 8800.00 75.13 163.22 3875.57 -6643.80 1764.86 6022346.84 559982.13 70 28 17.865 N 149 30 36.399 W 8900.00 75.13 163.22 3901.24 -6736.34 1792.77 6022254.54 560010.76 70 28 16,955 N 149 30 35,580 W 9000.00 75.13 163.22 3926.90 -6828.88 1820.67 6022162.23 560039.38 70 28 16.044N 149 30 34.760W 9100.00 75.13 163.22 3952.56 -6921.41 1848.57 6022069.92 560068.00 70 28 15,134N 149 30 33.940W 9200.00 75.13 163.22 3978.22 -7013.95 1876.48 6021977.62 560096.63 70 28 14.224 N 149 30 33.121W 9300.00 75.13 163.22 4003.89 -7106.48 1904.38 6021885,31 560125.25 70 28 13,314 N 149 30 32.301W 9400.00 75.13 163.22 4029.55 -7199.02 1932.28 6021793.01 560153.87 70 28 12,404N 149 30 31.482W 9500.00 75.13 163.22 4055.21 ~291.55 1960.18 6021700.70 560182.50 70 28 11.494 N 149 30 30.662W 9600.00 75.13 163.22 4080.88 -7384.09 1988.09 6021608.40 560211.12 70 28 10.584N 149 30 29.842W 9700.00 75.13 163.22 4106.54 -7476.63 2015.99 6021516.09 560239.74 70 28 9,673 N 149 30 29.023W 9800.00 75.13 163.22 4132.20 -7569.16 2043.89 6021423.78 560268.37 70 28 8.763 N 149 30 28.203W 9900.00 75.13 163.22 4157.86 -7661.70 2071.80 6021331.48 560296.99 70 28 7.853 N 149 30 27,384W 9996.67 75.13 163.22 4182.50 -7751.36 2098.24 6021242.03 560324.13 70 28 6.971 N 149 30 26.607W 10000.00 75.13 163.22 4183.35 -7754.44 2099.17 6021238.96 560325.08 70 28 6,941 N 149 30 26.580W BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41 Da~e: 4/25/2001 Tirae: 08:51:36 Ce~rdinate(NE) Refereace: Well: Plan MPC-41, Tree North Vertical (lw~)) Refereace: 51: 36 10/15/1997 10:5546.5 Section (VS) Reference: Well (0.00N,0~00E,164.76Azi) Plan: MPC-41 wp04 Page: 8 Survey Map Map <---- Latitude ---> <-- Longitude --> ! MD lncl Azlm TVD +NI-S +E./-W Northing Easting Deg Min Sec Deg Mbt See fl deg deg ft fl ft ft fl 10100.00 75.13 163.22 4209.02 -7846.98 2127.07 6021146.65 560353.71 70 28 6.031 N 149 30 25.761 W 10200.00 75.13 163.22 4234.68 -7939.51 2154.98 6021054.35 560382.33 70 28 5.121 N 149 30 24.941 W 10300.00 75.13 163.22 4260.34 -8032.05 2182.88 6020962.04 560410.95 70 28 4.211 N 149 30 24.122 W 10400.00 75.13 163.22 4286.01 -8124.58 2210.78 6020869.74 560439.58 70 28 3.300 N 149 30 23.303 W 10500.00 75.13 163.22 4311.67 -8217.12 2238.68 6020777.43 560468.20 70 28 2.390 N 149 30 22.483 W 10600.00 75.13 163.22 4337.33 -8309.66 2266.59 6020685.13 560496.82 70 28 1.480 N 149 30 21.664 W 10654.89 75.13 163.22 4351.40 -8360.47 2281.85 6020634.44 560512.48 70 28 0.980 N 149 30 21.216 W 10700.00 76.48 163.37 4362.46 -8402.36 2294.42 6020592.66 560525.38 70 28 0.568 N 149 30 20.847 W 10800.00 79.46 163.69 4383.31 _. ~8496.13 10900.00 82.44 164.00 4399.03 ' -8590.98 11000.00 85.43 164.31 4409.60 - -86~6.63 11100.00 88.41 164.62 4414.97 -8782.83 11153.19 90.00 164.79 4415.70 -8834.14 11166.94 89.59 164.80 4415.75 -8647.40 11200.00 89.59 164.80 4415.99 -8879.30 11300.00 89.59 164.80 4416.70 -8975.80 11400.00 89.59 164.80 4417.42 -9072.30 11500.00 89.59 164.80 4418.13 -9168.80 11600.00 89.59 164.80 4418.85 -9265.30 11700.00 89.59 164.80 4419.56 -9361.80 11800.00 89.59 164.80 4420.28 -9458.30 11900.00 89.59 164.80 4421.00 -9554.80 12000.00 89.59 164.80 4421.71 -9651.30 12100.00 89.59 164.80 "4422.43 -9747.80 12200.00 89.59 164.80 4423.14 -9844.29 12235.58 89.59 164.80 4423.44 -9878.61 12251.90 90.00 165.06 4423.50 -9894.37 12277.60 90.77 165.07 4423.33 -9919,20 12300.00 90.77 165.07 4423.03 -9940.84 12400.00 90.77 165.07 4421.69 -10037.46 12500.00 90.77 165.07 4420.34 -10134.07 12600.00 90.77 165.07 4419.00 -10230.69 12700.00 90.77 165.07 4417.65 -10327.30 12800.00 90.77 165.07 4416.31 -10423.92 12900.00 90.77 165.07 4414.97 -10520.53 13000.00 90.77 165.07 4413.62 -10617.15 13100.00 90.77 165.07 4412.28 -10713.77 13200.00 90.77 165.07 4410.93 -10810.38 13300.00 90.77 165.07 4409.59 -10907.00 13400.00 90.77 165.07 4408.25 -11003.61 13500.00 90.77 165.07 4406.90 -11100.23 13515.18 90.77 165.07 4406.68 -11114.87 13541.33 90.00 164.92 4406.50 -11140.12 13555.05 89.59 164.92 4406.55 -11153.38 13600.00 89.59 164.92 4406.87 -11196.78 13700.00 89.59 164.92 4407.59 -11293.33 13800.00 89.59 164.92 4408.30 -11389.89 13900.00 89.59 164.92 4409.02 -11486.44 14000.00 89.59 164.92 4409.73 -11583.00 14100.00 89.59 164.92 4410.45 -11679.55 14200.00 89.59 164.92 4411.17 -11776.10 14300.00 89.59 164.92 4411.88 -11872.66 14400.00 89.59 164.92 4412.60 -11969.21 2322.15 6020499.11 560553.84 70 27 59.646 N 149 30 20.033W 2349.62 6020404.49 560582.05 70 27 58.713 N 149 30 19.226W 2376.76 6020309.06 560609.93 70 27 57.772 N 149 30 18.429W 2403.50 6020213.08 560637.42 70 27 56.826 N 149 30 17.644W 2417.49 6020161.89 560651.81 7ff 27 56.321 N 149 30 17.234W .. 2421.09 6020148.66 560655.51 70 27 56.191N 149 30 17.128W 2429.76 6020116.83 560664.43 70 27 55.877 N 149 30 16.873W 2455.98 6020020.55 560691.40 70 27 54.928 N 149 30 16.104W 2482.19 6019924.26 560718.37 70 27 53.979 N 149 30 15.334W 2508.41 6019827.98 560745.34 70 27 53.030 N 149 30 14.565W 2534.63 6019731.70 560772.31 70 27 52.081N 149 30 13.795W 2560.85 6019635.42 560799.28 70 27 51.132 N 149 30 13.025W 2587.07 6019539.14 560826.25 70 27 50.182 N 149 30 12.256W 2613.29 6019442.85 560853.22 70 27 49.233 N 149 30 11.486W 2639.50 6019346.57 560880.19 70 27 48.284N 149 30 10.717W 2665.72 6019250.29 560907.16 70 27 47.335 N 149 30 9.948W 2691.94 6019154.01 560934.13 70 27 46.386 N 149 30 9.178W 2701.34 6019119.77 560943.79 70 27 46.048 N 149 30 8.902W 2705.59 6019104.05 560948.17 70 27 45.893 N 149 30 8.777W 2712.21 6019079.27 560954.98 70 27 45.649 N 149 30 8.583W 2717.98 6019057.68 560960.92 70 27 45.436 N 149 30 8.414W 2743.74 6018961.28 560987.43 70 27 44.486 N 149 30 7.658W 2769.50 6018864.87 561013.95 70 27 43.536N 149 30 6.902W .2795.27 6018768.47 561040.46 70 27 42.585 N 149 30 6.146W 2821.03 6018672.07 561066.97 70 27 41.635 N 149 30 5.390W 2846.79 6018575.67 561093.49 70 27 40.685 N 149 30 4.634W 2872.55 6018479.27 561120.00 70 27 39.735 N 149 30 3,878W 2898.31 6018382.87 561146.52 70 27 38.784N 149 30 3.122W 2924.07 6018286.46 561173.03 70 27 37.834N 149 30 2.367W 2949.83 6018190.08 561199.54 70 27 36.884N 149 30 1.611 W 2975.60 6018093.66 561226.06 70 27 35.933 N 149 30 0.855W 3001.36 6017997.26 561252.57 70 27 34.983 N 149 30 0.099W 3027.12 6017900.86 561279.09 70 27 34.033 N 149 29 59.343W 3031.13 6017886.25 561283.21 70 27 33.889 N 149 29 59.226W 3037.91 6017861.05 561290.19 70 27 33.640 N 149 29 59.027W 3041.48 6017847.82 561293.86 70 27 33.510 N 149 29 58.922W 3053.17 6017804.52 561305.89 70 27 33.083 N 149 29 58.579W 3079.19 6017708.18 561332.68 70 27 32.133 N 149 29 57.816W 3105.21 6017611.84 561359.43 70 27 31.184N 149 29 57.053W 3131.22 6017515.50 561386.20 70 27 30.234N 149 29 56.289W 3157.24 6017419.17 561412.96 70 27 29.264N 149 29 55.526W 3183.25 6017322.83 561439.73 70 27 28.335 N 149 29 54.763W 3209.27 6017226.49 561468.50 70 27 27.385 N 149 29 54.000W 3235.29 6017130.15 561493.27 70 27 26.435 N 149 29 53,237W 3261.30 6017033.81 561520.04 70 27 25.486 N 149 29 52.474W BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41 Date: 4/25/2001 Time: 08:51:36 Co-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51 .: 36 10/15/1997 10:55 46.5 Section CvS) Reference: Well (0.00N,0.00E,164.76Azi) Plan: MPC-41 wp04 Page: 9 Survey Map Map" <~- Latitude --> <--- Lon~itude ---> MD lncl Azim TVD +N/-S +E/-W Northing Easttng Deg Min Sec Deg Min Sec ft deg deg ff ft ft ft fl 14500.00 89.59 164.92 4413.31 -12065.77 3287.32 6016937.48 561546.80 70 27 24.536 N 149 29 51.711 W 14600.00 89.59 164.92 4414.03 -12162.32 3313.34 6016841.14 561573.57 70 27 23.586 N 149 29 50.948 W 14700.00 89.59 164.92 4414.74 -12258.87 3339.35 6016744.80 561600.34 70 27 22.637 N 149 29 50.185 W 14800.42 89.59 164.92 4415.50 -12355.83 3365.46 6016648.06 561627.20 70 27 21.683 N 149 29 49.419 W DATE I CHECK NO. I H 1 881 25 OOLBB125 VENDOR ALASKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT I~ET 041801 CK041801 100. O0 100. O0 PYMT (;OMMENTS: Per,nit to Deill HANDL'.[NG INST: S/H- Tee~ie Hubl)ie X4628 IE A]'rACHEO CHECK IS I. PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 1 OO. OO 1 OO. OO ORDER :::'~,'.,~,, :.*,~,' '.,: ~ ':' ". ~' .':~ ~'.' :; , ...... ,i ':, .'," ,~'::,~ ,~'~ ~, ' '.' I XPLORATION ALASKA., lNG ~ ~.'~.i..;,,:.:~', ,~'../... · · ::: .... ',. H.'1'8'. ,.%~,,, ,,,, -...:, ~.. ~ ......-..' ,. '. ,.....',,,?/~,~,: ~ .. [, ,... ....;:... , .,,:.~:, .:,. :'~A~A~iA~'O~:~,'~;: ',. ~,~ ~S ," ,: .~:~.:(',~:,~.,,,..,. ~,".:, ,;~:.,,;: ,/,' ,,.~ ';,,;'~:~:;~ . '~. , ,'. · .... .- · .~2 · ~'"' ~;"~.'q ',~;/,'~ .' ', : . " · ~ '~, · ' '~"' '" .... "'.' , ~ ;' '::" ~:~r' '~ '" ":'. ]' .... ~ ~,~-,,t , ~ :: ',.,., '. .... '",'; *':'""::'. ' .... " "~" ,,~"', ~' ';;"." ~F,;' ~" '."" ' : .... "': ' '' '.~'C~VE~60H~ .;", ', "~%"'.,:., : .'.:,, '::'.'.:,~' '~ I ~=~.: :,:.':~':::" ;" .::[:~ L:: :'~; ;'.';; :~:': ~ ~:;, ,, :~;~;F ::: :",.,~t: :,? ,:;",., :: ],: · .' · ·" " . '..::: :' ~62~89 :::J ':";' ': ':. ;': .2: :,,::'"" : .~;~: ,' '%,: :: .,T/' '. ' .... : ::...::~,.; &::': ,.,,,~::,:,,,:. ,~,,: ,,. ,.::,:,.,.,~:: :: .... ,~,, .~ ,,:, ,~ .... :.,. ,:: ...:, ,.. , ::.,~, ., ~:::"'"":~, .'", ~":' '::? '=;" :?~{"..' :~:'t~: ~:'~' '' ::~ , .':,~::,, ,'~:::.W~. ~ .:'.., '.~;:,~:' ~ :' ::, ::,,',r. ':',::... ', .' ', ,:': , ..,.. ;....,,, , .,.;;:,.,r · , ;, [.,¢. ,.,, ,,, , ,, ,,~ ,....,,.,..~,,;., ,,,:,,,.,¢;.:,, ~ : , ,,. · , .... ::n,,;q:, .:,:,, :. ,. ,;:,>:::,;.,: : , : :. ,/, ~ . : ;, .. 11' ~881, 2 S,' ~:Ohi, 80~BqS~: OOP, hhl, WELL PERMIT CHECKLIST COMPANY FIELD & POOL .~"'~-.~'/~-/~ INIT CLASS /'~-z.-- /-~,~ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. APPR D T 12. ENGINEERING GEOLOGY APPR WELL NAMF_~/~- ?7/ PROGRAM: exp ~ Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available, in ddlling unit ............ If deviated, is wellbore plat included ............. ... GEOLAREA N Y N N. Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can. be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons ..... ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ........ ...... 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to =~"-O r,~ psig. 27. Choke manifold complies w/APl RP,53 (May 84) ......... 28. Work will occur without operation shutdown... ........ 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y/,N/ ,~, ~ ,,r'? 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ............. //Y N ' 34. Contact name/phone for weekly progress reports [exploratory or, By] Y N dev ~ reddl ~ serv~ wellbore seg ann. disposal para req_ UNIT# ~//~_~ <~ ON/OFF SHORE __~ ANNULAR DISPOSAL35, With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N 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 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: 0 Z 0 Z --I -I- c:~nsoffice\wordian~diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this. .nature is accumulated at the end of the file under APPE .N. DIXi No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Oct 31 08:17:24 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/10/31 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10166 R. FRENCH J. PYRON MPC-41 500292301400 BP Exploration (Alaska), Inc. Sperry Sun 31-OCT-01 MWD RUN 2 AK-MM-10166 D. LABRECQUE J. PYRON MWD RUN 3 AK-MM-10166 D. LABRECQUE J. PYRON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 4 AK-MM-10166 T.GALVIN D. FERGUSON MWD RUN 5 AK-MM-10166 T. GALVIN D. FERGUSON 10 13N 10E 694 2298 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 45.17 16.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 110.0 9.875 7.000 11200.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY {DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. THE GAP IN SROP FROM 8550' MD, 3810' TVD TO 8562' MD, 3813' TVD IS DUE TO PERFORMING OPEN HOLE SIDETRACK. 4. MPC-41 IS TIED INTO MPC-41PB1 AT THE KICK OFF POINT. MPC-41 IS TIED INTO MPC-41PB2 AT THE KICK OFF POINT. MPC-41 KICKS OFF FROM MPC-41PB1 AT 8550' MD, 3810' TVD. MPC-41 KICKS OFF FROM MPC-41PB2 AT 11750' MD, 4417' TVD. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHNOOR OF BP EXPLORATION ALASKA, INC. DATED 9/7/01. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 5 REPRESENT WELL MPC-41 WITH API % 50-029-23014-00. THIS WELL REACHED A TOTAL DEPTH OF 12087' MD, 4436' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ START DEPTH 75 0 100 0 100 0 100 0 100 0 100 0 120 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12018 0 12025 0 12025 0 12025 0 12025 0 12025 0 12087 5 EQUIVALENT UNSHIFTED DEPTH BlT RUN NO MERGE TOP MERGE BASE 1 75.0 6046.5 2 6047.0 8550.0 3 8550.5 11212.0 4 11212.0 11750.0 5 11750.5 12087.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD API OHMM OHMM OHMM OHMM HR 1 68 1 68 1 68 1 68 1 68 1 68 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR Min 75 2.12 12 54 0 09 0 06 0 06 0 04 0 09 Max 12087.5 3011.61 120.56 2000 2000 2000 2000 176.35 Mean Nsam 6081.25 24026 242.723 23913 66.2076 23887 17.4078 23851 19.566 23851 21.8888 23851 44.0851 23851 1.66663 23851 First Reading 75 120 75 100 100 100 100 100 Last Reading 12087.5 12087.5 12018 12025 12025 12025 12025 12025 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 12087.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 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 ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 75.0 5999.5 RPM 100.0 5992 . 0 R?S 100.0 5992 . 0 RPD 100.0 5992 . 0 FET 100.0 RPX 100.0 ROP 120.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 5992.0 5992.0 6046.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 31-MAY-01 Insite 4.05.5 66.16 Memory 6047.0 .0 76.4 TOOL NUMBER PB02038HWBRG6 PB02038HWBRG6 9.875 Spud Mud 8.40 117.0 9.8 450 9.8 4.500 4.288 7.000 4.500 72.0 75.9 72.0 72.0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD010 FT/H 4 1 68 MWD010 API 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HR Min 75 4.86 12 54 0 09 0 06 0 06 0 04 0 09 Max 6046.5 1014.02 116.89 2000 2000 2000 2000 6.18 First Mean Nsam Reading 3060.75 11944 75 278.708 11854 120 61.3222 11850 75 29.7697 11785 100 33.9932 11785 100 36.2936 11785 100 74.704 11785 100 0.525262 11785 100 Last Reading 6046.5 6046.5 5999.5 5992 5992 5992 5992 5992 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 6046.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPM RPS RPX FET RPD GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5992 5 5992 5 5992 5 5992 5 5992 5 6000 0 6047 0 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS {C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record STOP DEPTH 855O 0 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 02-JUN-01 Insite 4.05.5 66.16 Memory 8550.0 73.8 77.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 Spud Mud 9.30 73.0 8.6 300 5.0 4.200 3.074 6.100 3.200 65.0 91.3 65.0 65.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 MWD020 FT/H 4 1 68 4 2 MWD020 API 4 1 68 8 3 MWD020 OHMM 4 1 68 12 4 MWD020 OHMM 4 1 68 16 5 MWD020 OHMM 4 1 68 20 6 MWD020 OHMM 4 1 68 24 7 MWD020 HR 4 1 68 28 8 Name Service Unit .Min DEPT FT 5992.5 ROP MWD020 FT/H 21.29 GR MWD020 API 23.2 RPX MWD020 OHMM 1.68 RPS MWD020 OHMM 1.64 RPM MWD020 OHMM 1.67 RPD MWD020 OHMM 1.79 FET MWD020 HR 0.14 Max 8550 570.52 112 58 17 51 18 08 18 81 19 74 16 06 Mean Nsam 7271.25 5116 241.332 5007 67.9326 5101 5.34458 5116 5.36745 5116 5.55919 5116 5.74475 5116 0.924685 5116 First Reading 5992.5 6047 6000 5992.5 5992.5 5992.5 5992.5 5992.5 Last Reading 8550 8550 8550 8550 8550 8550 8550 8550 First Reading For Entire File .......... 5992.5 Last Reading For Entire File ........... 8550 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 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 ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8550 5 8550 5 8550 5 8550 5 8550 5 8550 5 8562 0 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: 11151 11158 11212 STOP DEPTH 11151 5 11151 5 11151 5 11151 5 5 0 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 04-JUN-01 Insite 4.05.5 66.16 Memory 11210.0 70.3 86.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 11200.0 LSND 9.20 65.0 8.6 3OO 5.5 3.600 2.842 5.000 4.200 72.0 93.0 72.0 72.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min DEPT FT 8550.5 ROP MWD030 FT/H 2.12 GR MWD030 API 26.4 RPX MWD030 OHMM 1.18 RPS MWD030 OHMM 1.14 RPM MWD030 OHMM 1.13 RPD MWD030 OHMM 1.27 FET MWD030 HR 0.13 Max 11212 3011.61 120 56 38 75 38 51 98 68 79 45 32 36 Mean 9881.25 206.459 74.2491 4.87338 5.11613 5.6765 5.78751 0.923473 Nsam 5324 5301 5216 5203 5203 5203 5203 5203 First Reading 8550.5 8562 8550.5 8550.5 8550.5 8550.5 8550.5 8550.5 Last Reading 11212 11212 11158 11151.5 11151.5 11151.5 11151.5 11151.5 First Reading For Entire File .......... 8550.5 Last Reading For Entire File ........... 11212 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPM RPS RPD FET RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11152.0 11152 0 11152 0 11152 0 11152 0 11158 5 11212 5 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: STOP DEPTH 11750 0 11750 0 11750 0 11750 0 11750 0 11750 0 11750 0 12-JUN-01 Insite 4.05.5 66.16 Memory 11750.0 85.5 96.5 TOOL NUMBER PB02041GRHA4 PB02041GRHA4 6.125 Baradril-N 9.00 46.0 8.8 29000 5.0 .180 .139 .160 70.0 93.0 70.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .210 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 Name Service Unit Min Max DEPT FT 11152 11750 ROP MWD040 FT/H 8.92 1788.96 GR MWD040 API 40.7 90.85 RPX MWD040 OHMM 0.28 977.54 RPS MWD040 OHMM 0.36 25.58 RPM MWD040 OHMM 0.16 1894.24 RPD MWD040 OHMM 0.68 2000 FET MWD040 HR 0.55 176.35 Mean Nsam 11451 1197 111.869 1076 66.2623 1184 7.8195 1197 7.98603 1197 28.2614 1197 91.1179 1197 19.4472 1197 First Reading 11152 11212.5 11158.5 11152 11152 11152 11152 11152 Last Reading 11750 11750 11750 11750 11750 11750 11750 11750 First Reading For Entire File .......... 11152 Last Reading For Entire File ........... 11750 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 11750.5 RPM 11750 5 RPS 11750 5 RPX 11750 5 GR 11750 5 12018 ROP 11750 5 12087 FET 11750 5 12025 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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): STOP DEPTH 12025 0 12025 0 12025 0 12025 0 0 5 0 13-JUN-01 Insite 4.05.5 66.16 Memory 12087.0 83.3 90.3 TOOL NUMBER PB02041GRHA4 PB02041GRHA4 6.125 Baradril-N 9.10 46.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.8 29000 4.6 .180 .139 .160 .210 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 93.0 70.0 70.0 Name Service Unit Min DEPT FT 11750.5 ROP MWD050 FT/H 7.97 GR MWD050 API 52.12 RPX MWD050 OHMM 2.16 RPS MWD050 OHMM 2.28 RPM MWD050 OHMM 2.44 RPD MWD050 OHMM 2.59 FET MWD050 HR 0.7 Max 12087.5 329.62 112 35 22 97 20 42 18 55 13 71 2 14 Mean 11919 114.462 79.4226 4.17844 4.40133 4.62782 4.57727 1.35778 Nsam 675 675 536 55O 55O 55O 55O 55O First Readinc 11750 11750 11750 11750 11750 11750 11750 11750 Last Reading 12087.5 12087.5 12018 12025 12025 12025 12025 12025 First Reading For Entire File .......... 11750.5 Last Reading For Entire File ........... 12087.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/10/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File