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Home My WebLink About201-092Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929 MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandonment 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,207'N/A Casing Collapse Conductor N/A Surface 2,020psi Intermediate 5,410psi Liner "A"11,780psi Liner "B"11,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT I-04A MILNE POINT SCHRADER BLUFF OIL N/A 4,070' 7,207' 4,070' 1,164 N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/10/2024 3-1/2" x 7" Baker Premier, 7" Halliburton VTL & 7" Baker ZXP and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 201-092 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22068-01-00 Hilcorp Alaska LLC C.O. 477.07 Length Size Proposed Pools: 115' 115' 9.3# / L-80 / EUE 8rd TVD Burst 4,223' 11,200psi MD N/A 11,200psi 3,520psi 7,240psi 2,354' 3,999' 4,069' 2,599' 4,536' 115' 13-3/8" 9-5/8" 7" 2,599' 2-3/8"2,685' 4,536' 7,184' See Schematic 2,303' See Schematic 3-1/2" 4,125'2-3/8" 4,118 MD/ 3,622 TVD, 4,330 MD/ 3,812 TVD & 4,457 MD/ 3,927 TVD and N/A Todd Sidoti todd.sidoti@hilcorp.com 777-8443 6,834' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:36 pm, Sep 30, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.09.30 14:48:33 - 08'00' Taylor Wellman (2143) 324-568 * Approved for abandonment of the '04A' and the '04AL1' lateral wellbore sections. SB oil pool N sands remain open to perforations. SB Oil Pool is not isolated. * State witness slickline tag of OA lateral TOC (~ 4450' MD). MGR02OCT24 Lateral - mgr 1,164 4,125' SFD DSR-10/2/24SFD 10/2/2024 10-407 6,888' SFD 4,125' SFD 6,888' SFD JLC 10/3/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.07 12:22:16 -08'00' 10/07/24 RBDMS JSB 100824 Res Abandon Well: MPI-04 Date: 09/23/2024 Well Name: MPI-04 API Number: 50-029-22068-01 Current Status: SI Injector Pad: MPU I-Pad Reg. Approval Req’d? 10-403 PTD: 201-092 Regulatory Contact: Tom Fouts Job Type: Cementing First Call Engineer: Todd Sidoti Phone: (907) 632-4113 Cost Estimate: $200,000 IOR: N/A Second Call Engineer: Ryan Lewis Phone: (303) 906-5178 Current Bottom Hole Pressure: 1524 psi @ 3600’ TVD SBHPS ran 1/26/24 (8.14 PPGE) MPSP: 1164 psi Gas gradient to surface 70 Degree Deviation: ~4670’ MD Min ID: 2.813” @ 4008’ MD Background: MPI-04 was drilled and completed in 1991 as a vertical Schrader Bluff ESP lifted producer. It was converted to an injector in 2023. The objective of this program is to abandon the OA and OB laterals so that new well J-32 can be drilled. Well History: x 9/1/24 MIT-IA passed to 2033 psi. Non-Sundried Procedure Steps: Slickline & E-line: 1. MIRU SL and PT lubricator to 250 psi low / 1500 psi high. 2. Drift to deviation with dummy 3.5” plug. 3. RDMO SL. 4. MIRU EL and PT lubricator to 250 psi low / 1500 psi high. 5. RIH with 3.5” cement retainer and set at the bottom of the 9.98’ 3.5” pup joint below N sand screens @ ~4450 (see attached screen completion diagram). 6. RDMO EL. Sundried Procedure Steps: Coil & Cementers: 1. MIRU CTU and Cementers. 2. MU and RIH with BHA including stinger for 3.5” cement retainer. 3. Fill CT x TBG annulus with produced water and establish injectivity pressures from 0.5 BPM to max rate in 0.5 BPM increments. 4. Fill CT with produced water and establish injectivity pressures from 0.5 BPM to max rate in 0.5 BPM increments. 5. Batch mix 40 bbls of cement and pump down CT per following schedule. Volumes are based on 2 times length of both laterals (19.5 bbls). a. 5 bbl freshwater spacer b. 40 bbls cement c. Chase cement with produced water Res Abandon Well: MPI-04 Date: 09/23/2024 6. Target squeeze pressure is 1000 psi over baseline injectivity. Hold squeeze pressure for 30 minutes. a. Contact OE to discuss batching up another 20-40 bbls of cement and attempting re- squeeze depending on pressure and rate trends during job. 7. After 39 bbls displaced through retainer, unsting and lay remaining barrel on top. 8. Contaminate remaining cement with gel pill while taking returns to surface. Do not disturb ~20’ cement cap on top of retainer. a. If unable to take returns to surface we can stuff contaminated cement away into N sand screens and chase with 50 bbls produced water. 9. POOH chasing final gel pill at 80%, reciprocate multiple times across screens and jewelry. 10. Freeze protect tubing. 11. Wash up cementers. 12. RDMO CTU and cementers. Slickline: 1. Notify AOGCC 24 hours in advance in order to provide opportunity to witness tag and test. 2. MIRU slickline. 3. RIH with s-bailer and tag cement top at ~4450’. POOH. 4. RDMO SL. Res Abandon Well: MPI-04 Date: 09/23/2024 Res Abandon Well: MPI-04 Date: 09/23/2024 Attachments: Current Schematic Proposed Schematic _____________________________________________________________________________________ Revised By: TDF 5/20/2024 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,223’ 0.0087 JEWELRY DETAIL No Depth Item 1 4,008’ 3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’ Baker Zenith Gauge Carrier (BPHG) 3 4,118’ 7” x 3-1/2” Baker Premier Packer 4 4,180’ 3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’ 3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 16 6,834’ 2-3/8” Btm Baker Guide Shoe 17 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader NA 4,383’ 4,392’ 3,860’ 3,868’ 9 March 1995 Open Schrader NB 4,411’ 4,428’ 3,886’ 3,901’ 17 March 1995 Open Schrader NC 4,443’ 4,451’ 3,915’ 3,922’ 8 March 1995 Open _____________________________________________________________________________________ Revised By: TS 9/17/2024 PROPOSED Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 15 17 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8"Conductor 54.5 / K-55 / Welded 12.459”Surf 115'N/A 9-5/8”Surface 36 / J-55 / BTC 8.765”Surf 2,599’0.0773 7"Production 26 / L-80 / BTC 6.151”Surface 4,536'0.0382 2-3/8”Liner “A”4.6 / L-80 / ST-L 1.901”4,499’7,184’0.0039 2-3/8”Liner “B”4.6 / L-80 / ST-L 1.901”4,531’6,834’0.0039 TUBING DETAIL 3-1/2”Tubing 9.3 / L-80 / EUE 8rd 2.992”Surface 4,223’0.0087 JEWELRY DETAIL No Depth Item 1 4,008’3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’Baker Zenith Gauge Carrier (BPHG) 3 4,118’7” x 3-1/2” Baker Premier Packer 4 4,180’3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’7” Halliburton VTL Packer (3.880” ID) 7 4,348’3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 ~4,450’FH-1 Cement Retainer (Capped with ~20’ of cement) 9 4,456’Baker Seal Assembly, 5.75’ Long (4.50” ID) 10 4,457’7” Baker ZXP Packer 11 4,475’4-1/2” X Profile (3.813” Packing Bore ID) 12 4,478’4-1/2” WLEG (3.958” ID) 13 4,499’Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 14 4,510’Flow-thru Whipstock 15 7,184’2-3/8” Btm Baker Guide Shoe 16 4,531’Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 17 6,834’2-3/8” Btm Baker Guide Shoe 18 4,550’Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8"Cmt w/ 485 sx of PF C in 30” Hole 9-5/8”Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7”Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Schrader NA 4,383’4,392’3,860’3,868’9 March 1995 Open Schrader NB 4,411’4,428’3,886’3,901’17 March 1995 Open Schrader NC 4,443’4,451’3,915’3,922’8 March 1995 Open Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC I-04A MILNE PT UNIT I-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 I-04A 50-029-22068-01-00 201-092-0 W SPT 3812 2010920 2000 711 713 713 713 332 335 336 335 OTHER P Adam Earl 5/6/2023 MIT IA tested as per Sundry 323-053 to 2000psi 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 I-04A Inspection Date: Tubing OA Packer Depth 753 2240 2159 2144IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230510100747 BBL Pumped:0.9 BBL Returned:0.8 Friday, June 16, 2023 Page 1 of 1          convert to injection; jbr   MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC I-04A MILNE PT UNIT I-04A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 I-04A 50-029-22068-01-00 201-092-0 N SPT 3812 2010920 2000 159 163 161 161 306 310 314 315 OTHER P Sully Sullivan 4/28/2023 Rig moved off well before performing the pre inj. MIT. So this is the pre inj. MIT (well not flowing yet). Test to 2000 pr sundry 323-053. Tested with ambient diesel 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 I-04A Inspection Date: Tubing OA Packer Depth 13 2206 2103 2082IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230430080250 BBL Pumped:1 BBL Returned:1 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 99 99 9 9 pre inj. MIT sundry 323-053. James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 14:39:09 -08'00' 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: 04/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230414 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 3/20/2023 READ CaliperSurvey MPL-12 50029223340000 193011 4/2/2023 READ CaliperSurvey MPU I-27 50029236920000 221013 3/23/2023 READ LeakPointSurvey PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile PBU L-112A 50029231290100 222138 3/27/2023 READ MemoryRadialCementBondLog END 1-11 50029221070000 190157 3/19/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/9/2023 AK E-LINE Perf NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf BCU 19RD 50133205790100 219188 4/4/2023 AK E-LINE PPROF SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf SRU 231-33 50133101630100 223008 3/29/2023 AK E-LINE GPT Please include current contact information if different from above. T37595 T37596 T37599 T37599 T37597 T37599 T37598 T37601 T37603 T37600 T37602 T37594 T37604 T37604 T37605 MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 14:10:44 -08'00' 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: Convert to Injector 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 7,207 feet N/A feet true vertical 4,070 feet N/A feet Effective Depth measured 7,207 feet feet true vertical 4,070 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 4,223' 3,715' 3-1/2" x 7" Baker Premier 7" Halliburton VTL Packers and SSSV (type, measured and true vertical depth)7" Baker 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: Wells Manager Contact Phone: 4,118, 4,330 & 4,457 3,622, 3,812 & 3,927 323-053 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 Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 measured true vertical 950 4,069' 4,125' 11,780psi 11,780psi 3,520psi 7,240psi 11,200psi 11,200psi 3,999' BurstMD 115' 1240 Size 115' 2,354' 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 2460 0 00 727 TVD 2-3/8" 2-3/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-092 50-029-22068-01-00 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: Packer ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT SB I-04A Plugs Junk measured measured Length Liner "B" 2,685' 2,303' Casing Conductor 7,184' 6,834' 4,536' 2,599'Surface Intermediate Liner "A" 4,536' 13-3/8" 9-5/8" 7" 115' 2,599' N/A Collapse N/A 2,020psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:08 am, May 15, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.15 08:40:32 - 08'00' Taylor Wellman (2143) WCB 1-8-2024 323-053 RBDMS JSB 051623 MILNE PT UNIT SB I-04A 0-029-22068-01-00 Convert to Injector MILNE POINT / SCHRADER BLUFF OIL 201-092 Pull Tubing _____________________________________________________________________________________ Revised By: TDF 5/5/2023 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 4/19/2023 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,223’ 0.0087 JEWELRY DETAIL No Depth Item 1 4,008’ 3-1/2” HES Sliding Sleeve - Min ID 2.813’ 2 4,062’ Baker Zenith Gauge Carrier (BPHG) 3 4,118’ 7” x 3-1/2” Baker Premier Packer 4 4,180’ 3-1/2” X Nipple with RHC -Min ID 3.813” 5 4,192’ 3-1/2” WLEG – Bottom @ 4,223’ 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 16 6,834’ 2-3/8” Btm Baker Guide Shoe 17 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 Convert to Injector by ASR – 4-/19/2023 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 4/14/2022 - Friday Continue to test BOPE with 2 7/8" and 3 1/2" test joints to 250 low / 2500 high for 5 min each. Preform accumulator drawdown test.. R/U ESP sheave and ESP pulling equipment, center stack with chains and binders. Pull test plug and BPV, BOLDS - tubing on vacuum. M/U landing jt and TIW valve, Unseat hanger with 46K, up wt, 42K. Cut ESP and heat trace cables and prep to pull over sheave to spooling unit. L/D hanger and landing jt. L/D ESP completion. 4/12/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Notify AOGCC of upcoming BOP test @ 10:00hrs. N/D tree and N/U BOP's, Spot cellar box and mud boat. Continue Demob equipment from previous well. Lower mast and send carrier in to get serviced, Replaced hyd winch. Continue Demob equipment from previous well. Spot TP and Co.Man shacks. and misc equipment. Spot rig floor 4/13/2022 - Thursday Spot and level rig and pits, install rig floor and spacer spool. spot heaters. hook up electrical lines to rig. Raise mast and guy lines, move adjacent well house. remove rack stabilizers and install pins.. Hook up koomey lines and pressure up koomey, Function test BOP's. R/U Glycol heater, R/U pump lines and winterize rig. N/U riser, spacer spools and bird bath, position stack with chains and boomers. Spot catwalk and pipe sheds, spot spooling unit. R/U choke and kill lines, repair and install 6" flowline, complete rig acceptance check list. M/U test jts and fill stack, test BOP's w/ 2 7/8" and 3 1/2" test jts. to 250 low/ 2500 high for 5 min each. Continue to POOH laying down ESP completion and assembly. Recovered 1 Glm, 1 XN nipple 130 jts 2 7/8" tubing - 17 bad jts / 113 good jts. 39 CC clamps, 97 Dual channel clamps, 439 5' clamps, 3 stainless bands 4 pump clamps, 3 protectroliizers, 2 flat gaurds. R/D ESP equipment, clean and clear rig floor, and pipe shed. Install wear bushing and run in 2 lock downs. Cont cleaning up rig equipment and rack and tally DP. P/U scraper BHA. RIH with 3 1/2" DP to 4332' and tag packer with 5k. POOH and reciprocating scraper from 4,180 to 4,100'. 4/15/2022 - Saturday Continue to log well ( CBL) 3340' TOC.. R/D wireline equipment. Pull wear bushing and change out handling equipment for completion. P/U 3 1/2" , 9.3#, L-80 EUE Injection completion - WLEG, XN nipple, Packer, Zenith Gauge carrier and sliding sleeve to 2794' - Had to work thru tight spot at 2745' with 16K set down. tested tech- wire after tight spot.. Breaks not functioning properly, trouble shoot system and adjust linkage on main hydraulic pumps.. P/U 3 1/2" , 9.3#, L-80 EUE Injection completion f/ 2794' t/ 4207'. P/U tubing hanger and terminate I-wire, land hanger - up wt 37K. dn wt. 25K, st wt. 28K, EOT @ 4,222', Packer set depth 4,129'. 71 cross collar clamps ran. RILDS R/U to freeze protect well, PJSM. Pump 60 bbls inhibited brine, followed by 52 bbls DSL down annulus taking returns up tubing. 4/16/2023 - Sunday Cont. to POOH with scraper BHA. Service rig and repair hose on radiator. Cont. to POOH with scraper BHA and L/D same. M/U 7" test packer. RIH w 3 1/2" WS to 4160' and rig up power swivel. Set test packer @ 4160' and fill IA ( 11bbls). test 7" casing to 2000psi for 30 min. (good test). release packer. Break circulation to clear oil from WS. 3BPM @ 350 psi. pumped 36 bbls, returned 20 bbls. R/D power swivel. POOH w 3 1/2" WS and L/D test packer. R/U wireline and RIH with CBL to 4,320'. CBL log out of hole to surface. R/D wireline. Note, had to POOH and add centralizers to tool string due to poor log quality. 4/17/2023 - Monday An email was sent by Mel Rixse on 4-18-23, after review of the CBL, giving persmission to Hilcorp to proceed. -WCB Continue to log well ( CBL) 3340' TOC. Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 Hilcorp Alaska, LLC Weekly Operations Summary Finish freeze protecting well and R/D pump truck. Drop ball and rod, Set packer and test tubing to 2700psi for 30 min, bleed down tubing to 1000 psi and pressure test IA to 2000 psi for 30 min.. Blow down lines, Pull and break down landing jt. Install BPV, Clean pipe shed, rig floor and pits, P/U johny wacker and flush stack with new pump. Drain gas buster and blow down all lines. Demob pipe sheds and catwalk. N/D bird bath, flow line, pop-off valve and riser spools. Release rig. 4/18/2023 - Tuesday Drop ball and rod, Set packer and test tubing to 2700psi for 30 min Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A ASR 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 4/21/2022 - Friday No operations to report. 4/19/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELLHEAD BOP stack pulled, clean tbg hgr void, install new RX54 gasket. PU 4 1/2 " tree/adapter, run 1/4" tech line through adapter and land. Torque to speck, term. tech line and test 500/5000 (PASS). Pull 4" Bpv w/ T bar. All valves incorrect position and tree cap/manifold installed. WELL SHUT-IN ARRIVAL. PULL BALL & ROD, 3-1/2" RHC FROM X-NIPPLE AT 4,180' MD. PUMP 9 bbls 60/40 DOWN TUBING. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 4/20/2022 - Thursday No operations to report. No operations to report. No operations to report. 4/22/2022 - Saturday No operations to report. 4/25/2023 - Tuesday 4/23/2023 - Sunday No operations to report. 4/24/2023 - Monday PULL BALL & ROD, 3-1/2" RHC FROM X-NIPPLE AT 4,180' MD. PUMP Well Name Rig API Number Well Permit Number Start Date End Date MP I-04A LRS 50-029-22068-01-00 201-092 4/12/2023 5/6/2023 5/5/2023 - Friday No operations to report. 5/3/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 5/4/2023 - Thursday No operations to report. No operations to report. T/I/O = 711/753/332 AOGCC MIT-IA 2000 psi Witnessed by Adam Earl **Passed** 0.90 bbls diesel to pressure up, first 15 min ia lost 81 psi, second 15 min ia lost 15 psi, FWP = 713/750/330 5/6/2023 - Saturday No operations to report. 5/9/2023 - Tuesday 5/7/2023 - Sunday No operations to report. 5/8/2023 - Monday AOGCC MIT-IA 2000 psi Witnessed by Adam Earl **Passed** The passing MIT-IA, after 5 days of injection, is a requirement in Sundry 323-053. -WCB 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: Convert to Injector 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: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,207'N/A Casing Collapse Conductor N/A Surface 2,020psi Intermediate 5,410psi Liner "A"11,780psi Liner "B"11,780psi 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: Brian Glasheen Contact Email: Contact Phone: Authorized Title: Operations Manager 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 2,303'11,200psi4,125'6,834'2-3/8" 9-5/8" 7" 2,599' 4,536' 2-3/8"2,685' MD N/A 11,200psi 3,520psi 7,240psi 2,354' 3,999' 4,069' 2,599' 4,536' 7,184' Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 4,070' 7,207' 4,070' 1,164 N/A 115' 13-3/8" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 201-092 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22068-01-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.07 MILNE PT UNIT I-04A See Schematic See Schematic 2-7/8" Perforation Depth MD (ft): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / 8rd 4,250' 2/20/2023 Halliburton VTL & Baker ZXP and N/A 4,330 MD/ 3,812 TVD & 4,457 MD/ 3,927 TVD and N/A Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian.Glasheen@hilcorp.com 907-564-5277 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 12:15 pm, Jan 27, 2023 323-053 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.01.27 11:08:02 -09'00' David Haakinson (3533) MGR10FEB23 10-404X DSR-1/30/23DLB 02/03/2023 * BOPE test to 2500 psi. Annular to 2500 psi. * CBL to be run from ~4,300' MD to confirmed TOC on 7" inner casing. CBL to be emailed: melvin.rixse@alaska.gov * AOGCC to witness MIT-IA to 2000 psi after new completion run and packer set. * AOGCC to witness MIT-IA to 2000 psi after 5 days of stabilized injection. 1,164 GCW 02/13/23 JLC 2/13/2023 2/13/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.13 14:30:34 -09'00' RBDMS JSB 021423 Convert to injector Well: MPI-04A PTD: 201092 API:50-029-22068-01-00 Well Name:MPI-04 API Number:50-029-22068-01-00 Current Status:SI Failed ESP Rig:ASR 1 Estimated Start Date:02/20/2023 Estimated Duration:5 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:201-092 First Call Engineer:Brian Glasheen 907-545-1144 (M) Second Call Engineer:Taylor Wellman 907-947-9533 AFE Number:232-00048 Current Bottom Hole Pressure: 1524 psi @ 3600’ TVD SBHP on 1/26/20232 Maximum Expected BHP: 1524 psi @ 3600’ TVD 8.14 PPGE No new perfs Max. Proposed Surface Pressure:1164 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.205” @ 4,165’ XN Nipple Brief Well Summary I-04 original well was drilled and completed in 1991 as a vertical Schrader Bluff ESP lifted producer. In July 2001 the well was sidetracked in both the Schrader Oa and Oba sands using coiled tubing. The N sands were left as initially completed with gravel pack and an ESP was run for artificial lift. In August 2005 the ESP failed and was replaced via RWO in November of 2005. The ESP ran until March of 2009 and then was replaced via RWO in October 2009. The ESP ran until March of 2012 and was replaced during RWO in February of 2014. During the RWO a caliper was run from 1050’ to surface as well as a Y-tool installed at the ESP to allow for access to the formation. That ESP failed in January of 2016 and was subsequently replaced in June of 2016 during RWO. During the RWO the ESP completion was pulled and indicated that sand had plugged the pump. A 7” casing scraper was run down to the top of the N sands gravel pack at 4330’. A clean out run was made with 2 7/8” tubing down to below the gravel pack at 4480’ with no obstructions encountered. A 7” RTTS packer was then run to 4300’, set and test to 1500 psi for 30 min. The new ESP was then run in hole. That ESP stopped lifting fluid in March of 2017. A coil tubing FCO was performed in November 2017 which was able to tag the top of the pump at 4179’ CTMD. Acid was place on top of the pump and were unable to squeeze. Multiple attempts were made to run the ESP but would not surface fluids. The well has remained SI since that time. AOR Attached for conversion to injection. 7’’ Casing tested 6/22/2016 to 1500 psi Objective x Pull ESP replace with an injection string Pre-Rig Procedure Non Sundried work: 1) OA integrity test. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS SL 1) SBHP for mud weight adjustment 2) Caliper well from 4207’ MD to surface 3) DMY St 2 GLM 4) Pull St 1 DMY GLV and leave pocket open for RWO Convert to injector Well: MPI-04A PTD: 201092 API:50-029-22068-01-00 Sundried work: Well Support- 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 3. Pressure test lines to 3,000 psi. 4. Circulate at least one wellbore volume with 9.5 ppg brine down tubing, taking returns up casing to 500 bbl returns tank. a. Returns will likely not be seen. After attempting circulation down the tubing, bullhead and load the tubing and IA. 5. RD Little Red Services and reverse out skid. 6. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. Brief RWO Procedure: 8. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 9. Check for pressure and if 0 psi. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 9.5 brine prior to setting CTS Plug. Set CTS Plug. 10. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8’’ and 3-1/2’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 12. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well as needed. 13. MU landing joint or spear and BOLDS. 14. Attempt to pull tubing. a. 2016 RWO PUW= 42k and SOW=30k b. Do not exceed 80 percent of 2-7/8” tubing tensile rating 84 Klbs (Yield at 100% 105 Klbs) Convert to injector Well: MPI-04A PTD: 201092 API:50-029-22068-01-00 c. RU spooler for ESP Cable and heat trace. 15. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8’’ tubing. a. Tubing will be reused based on pre RWO caliper. b. Ensure all clamps are recovered 2016 RWO noted c. Total clamps= i. 440 5’ mid clamps ii. 97 dual cross collars iii. 39 single channel cross collars iv. 3 protectorlizers v. 2 flat guards vi. 4 pump guards vii. 3 1-1/4" Bands on heat trace terminator head 17) MU 7” casing scraper BHA and TIH w/ 3-1/2” workstring to ±4330’ MD tag HAL packer. 18) POOH and reciprocate the 7” scraper across the following interval. a. 4100- 4180MD 19) POOH and LD scraper BHA. 20) PU 7’’ test packer and RIH on work string to ±4150’ MD. 1. Set Packer and test 7” casing to 2000 psi 2. If fails PU to 200 feet until 3250’ MD and retest. 3. Call OE if no passing test. 21) PU new 3-1/2’’ injection completion. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes WLEG L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''X Nip with RHC 9.3 L-80 RHC required 3.5''10'Pup Joint 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5'' 7'' Baker premier Packer Set ~4150' MD 9.3 L-80 3.5''10' Pup Joint 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''BHPG 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 20) Run CBL Log. Email results to AOGCC. email: melvin.rixse@alaska.gov Convert to injector Well: MPI-04A PTD: 201092 API:50-029-22068-01-00 3.5'' 1 joint 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''HAL Sliding Sleeve 9.3 L-80 3.5''10'Pup Joint 9.3 L-80 3.5''Joints 9.3 L-80 3.5''Space out PUPS 9.3 L-80 3.5'' 1 joint 9.3 L-80 3.5''PUP 9.3 L-80 3.5''Tubing Hanger 9.3 L-80 22) Space out and land the hanger. 1. Use caution not to Damage BHPG Cable while landing the hanger. 2. Note PU (Pick Up) and SO (Slack Off) weights on tally. 3. During space out do not forget to maintain constant hole fill 23) RILDS. Lay down landing joint. 24) Pump 58 bbls 9.5 ppg brine with Corrosion inhibitor down the IA followed by 52 bbls of diesel while taking returns up the tubing. 1. This is to protect the area above the packer. 25) Drop ball and rod and complete loading tubing with 9.5 ppg and hydraulically set the packer as per Vendor setting procedure 26) Pressure up and test the tubing to 2000 psi for MIT-T. Bleed off the tubing to 0 psi. Test the IA to 2000 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 27) Set CTS BPV. 28) RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to injection. AOGCC to witness MIT-IA. 9. AOGCC to witness MIT-IA to 2000 psi after 5 days of stabilized injection. Convert to injector Well: MPI-04A PTD: 201092 API:50-029-22068-01-00 Post Rig Work Slickline 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 300psi low and 2,000psi high. 3. Pull Ball and rod 4. Pull RHC profile Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. BOP Drawing 4. AOR 5. Surface Owner Affidavit _____________________________________________________________________________________ Revised By: TDF 12/2/2021 SCHEMATIC Milne Point Unit Well: MPU I-04A Last Completed: 6/23/16 PTD: 201-092 19 21 TD =7,207’(MD) / TD =4,070’(TVD) Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 9-5/8” 1 3 22 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 11 5 10 13 N Sands 18 4 2 13-3/8” 6 7 8 9 12 14 15 16 17 20 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441” Surf 4,250’0.0058 JEWELRY DETAIL No Depth Item 1175’ST 2: 2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Orifice Valve Set 6/24/16) 2 ±2,800’ Heat Trace (3,000’ spool) 34,052’ST 1: 2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Dummy Valve Set 6/24/16) 4 4,165’ 2-7/8” XN Profile (2.205” No-Go Packing Bore ID) 5 4,207’ Discharge Head 6 4,208’ Centrilift ESP: P4 124 Stages 7 4,220’ Gas Separator 8 4,225’ Tandem Seal Section 9 4,239’ Single ESP Motor (75 HP each) 10 4,246’ Phoenix Sensor w 6 fin Centralizer – Bottom @ 4,250’ 11 4,330’ 7” Halliburton VTL Packer (3.880” ID) 12 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 13 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 14 4,457’ 7” Baker ZXP Packer 15 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 16 4,478’ 4-1/2” WLEG (3.958” ID) 17 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 18 4,510’ Flow-thru Whipstock 19 7,184’ 2-3/8” Btm Baker Guide Shoe 20 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 21 6,834’ 2-3/8” Btm Baker Guide Shoe 22 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg _____________________________________________________________________________________ Revised By: DH 1/19/2023 PROPOSED Milne Point Unit Well: MPU I-04A Last Completed: 6/23/16 PTD: 201-092 14 16 TD =7,207’(MD) / TD =4,070’(TVD) 2 Orig. KB Elev.: 52.0’/ Orig. GL Elev.: 35.0’ RKB – Hanger: 23.85’ (Doyon 16) 7” 1 9-5/8” 3 5 17 “OA” Lateral PBTD =7,207’(MD) / PBTD =4,070’(TVD) “OB” Lateral 6 8 N Sands 13 4 13-3/8” 7 9 10 11 12 15 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 54.5 / K-55 / Welded 12.459” Surf 115' N/A 9-5/8” Surface 36 / J-55 / BTC 8.765” Surf 2,599’ 0.0773 7" Production 26 / L-80 / BTC 6.151” Surface 4,536' 0.0382 2-3/8” Liner “A” 4.6 / L-80 / ST-L 1.901” 4,499’ 7,184’ 0.0039 2-3/8” Liner “B” 4.6 / L-80 / ST-L 1.901” 4,531’ 6,834’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 2.867” Surface TBD 0.0087 JEWELRY DETAIL No Depth Item 1 TBD 3-1/2” HAL Sliding Sleeve 2 TBD Bottom Hole Pressure Gauge 3 ~4,150’ 7” x 3-1/2”Baker Premier Packer 4 TBD 3-1/2” X Nipple with RHC 5 TBD 3-1/2” WLEG 6 4,330’ 7” Halliburton VTL Packer (3.880” ID) 7 4,348’ 3-1/2” Halliburton Poroplus 250 micron screen (3 joints; 2.992” ID) 8 4,456’ Baker Seal Assembly, 5.75’ Long (4.50” ID) 9 4,457’ 7” Baker ZXP Packer 10 4,475’ 4-1/2” X Profile (3.813” Packing Bore ID) 11 4,478’ 4-1/2” WLEG (3.958” ID) 12 4,499’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 13 4,510’ Flow-thru Whipstock 14 7,184’ 2-3/8” Btm Baker Guide Shoe 15 4,531’ Baker Deployment Sleeve (4” GS Fishing Neck; 3.00” ID) 15 6,834’ 2-3/8” Btm Baker Guide Shoe 16 4,550’ Cement Retainer OPEN HOLE / CEMENT DETAIL 13-3/8" Cmt w/ 485 sx of PF C in 30” Hole 9-5/8” Cmt w/ 1,111 sx PF E, 244 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 260 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 400’ MD Max Wellbore Angle = 93.5 deg @ 4,971’ MD 25.23 deg @ 4,500’ MD WELLHEAD Tree 2-9/16” CIW Wellhead 11” x 2-7/8” EUE Top & Bottom FMC Tubing Hanger GENERAL WELL INFO API: 50-029-22068-01-00 Sidetracked & Liners Run by Nabors 3S – 7/11/2001 Screens & ESP Completion by Nabors 4ES – 7/19/2001 ESP Replacement by Nabors 4ES – 11/10/2005 ESP Replacement by Nabors 4ES – 10/30/2009 ESP Replacement, Add Y-Tool by Doyon 16 – 2/20/2014 ESP Replacement by ASR – 6/23/2016 LATERAL WINDOW DETAIL Top of “OA” Window @ 4,510’ MD; Bottom @ 4,515’ MD; Angle @ top of window is 25 deg Top of “OB” Window @ 4,536’MD; Bottom @ 4,542’ MD; Angle @ top of window is 25 deg Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Area of Review Summary – Milne Point Unit I-04 (PTD 201092)This Area of Review is required prior to the conversion of well MPU I-04 from a producer to a polymer injector. This AOR discusseswells with ¼ mile of the well’s entry point into the Schrader to the bottom of MPU I-04 well bore completion. Figure 1: Map showing wells within ¼ mile radius from MPU I-04.The list of all operators and surface owners within ¼ mile of MPU I-04 is below:#Operators#Surface Owners1Hilcorp Alaska, LLC1Alaska Department of Natural Resources (ADNR)Table 1: List of operators and surface ownersAn affidavit has been submitted to the following operators and surface owners:#Operators#Surface Owners1N/A1Alaska Department of Natural Resources (ADNR)Table 2: List of operators and surface owners receiving an affidavit The tables below illustrate all wells with in the ¼ mile of MPU I-04:Area of Review MPU I-04 SB Inj ConversionPTDAPIWELLSTATUSTopof SBNa(MD)TopofSBNa(TVD)TopofCement(MD)Top ofCement(TVD)Schrader NSand/Oa/Oba statusZonal Isolation201-09250-029-22068-01-00MPI-04ASI producer4376385432502890Open260 sax class G in 8-1/2'' hole204-17450-029-23224-00-00MPU H-18OBa lateral Shutin613939933652'2795'ClosedNot Open CIBP set204-17550-029-23224-60-00MPU H-18L1OA Lateral Hut in61373932N/AN/AClosedNot Open ISO sleeve with TTP inplace204-17650-029-23224-61-00MPU H-18L2NB Lateral61503932N/AN/AOpenOpen to Injection Support19009850-029-22073-00-00MPU J-04Shut in Producer:Na/Nb/Nc/Ne/Oa/Oba5523394632002571Open83 bbls Pumped of class G cementPlug bumbed float held.20419050-029-23227-00-00MPU H-16Active Producer:Oba5727386723422197Open123 bbls Class G cement floatheld.20419150-029-23227-60-00MPU H-16L1Active Producer:Oa57263866N/AN/AOpenOpen to Injection Support220-04950-029-23679-00-00MPU I-20Active Producer:Oba40123780SurfaceSurfaceOpen9-5/8" Cemented to surface22101350-029-23692-00-00MPU I-27Active Producer:Oa40853766SurfaceSurfaceOpen9-5/8" Cemented to surface22101050-029-22602-01-00MPU I-07AActive Injector:Na/Nb/Nc/Ne/Oa/Oba Prod3877378035503477OpenOpen Vertical injector inall SBSands190-09750-029-22072-00-00MPU J-03AbandonedProducer:Na/Nb/Nc/Ne/Oa/Oba481337922927'2532'ClosedRes P&A Table 3: Zonal isolation of wells within AORI-04A current location is not suitable as a producing well there is minimal injection support due to fault proximity and distance from injection asindicated by it’s low rates and pressures over time. It is planned to work this well over to convert to an injector and support H-16 producer inthe Oa/Oba sands as well as the planned addition of the N sands perforations in upcoming H-16 RWO. This will help support the current 230bopd rate from the O sands and sweep suspected unswept area in H-16 and support the expected 110 bopd from the addition of the N sands. Image( 'eject Well History' File Cover I{' 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. c~ 0 L - O.~c~ Well Histo~ File Identi,ier Color items: V Diskettes, No./ [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL ~tWINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other III IIIIIIIIIII II III Scanning Preparation j" x30 =,_.~0 BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: 'J~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: 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 ) NO NO RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked 12/10102Rev3NOTScanned.wpd STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~I ON REPO OF SUNDRY WELL OPERA'fiONS ~~~l~1 ~I GR.E NOV 1 ~ 2Q09 1. Operations Performed: . (111SS ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ~0~lQP~~E ^ Alter Casing ~ Pull Tubing ^ Perforate New Poot ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown ^ Pertorate ^ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: . Permit To Drill Number; BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 201-092 3. Address: ^ Service ^ Stratigraphic . API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22068-01-00 Property Designation: . Well Name and Number: ADL 025906 MPI-04A 9. Field / Pool(s): ~ Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured ~ 6$$$' feet true vertical ~ 4125' feet Plugs (measured) None Effective depth: measured 6$$$' feet Junk (measured) None true vertical 4125' feet Casing Length Size MD TVD Burst Coltapse Structural Conductor 80' 20" 115' 115' 2730 1130 Surface 2564' 9-5/8" 2599' 2354' 3520 2020 Intermediate Production 4501' 7" 4536' 3999` 7240 5410 Liner 2304' 2-3/8" 4530' - 6834' 3993' - 4126' 11200 11780 Perforation Depth: Measured Depth: 4383' - 6794' True Vertical Depth: 3860' - 4125' Tubing (size, grade, measured and true vertical depth): 2-~~8~~~ 6'~ L-80 4272' 3760' Packers and SSSV (type, measured and true vertical depth): ~~~ Halliburton 23-29# VTL Versa-trieve.,,,,._. _.,„~ .. 4338' 3819' 7" Baker "SLZXP" 4463' 3933' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descnption including volumes used and final pressure: f., j~ t:1 ~j ~'t L' ~~} ~k~~ e-~%.ti~~C~~v 1? GU 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 73. Attachments: ^ Copies of Logs and Surveys run • well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily RepoR of Well Operations ~ Well Schematic Diagram • Well Status after work: ~ O+I ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Drilling Technologist • ~ Prepared By Name/Number: i~~ Si nature 9 Phone 564 28 Date Terrie Hubble, 564-4628 QIt Form 10-404 Revised 07/2009 ~~~/{(y~ lI ~~~~ Submit Original Only ~GL D ~ / :~ ~ ' ~ `i~ // ~ ~ ~/~ ~OJ~' WELLHEAD6115 5 WKM w/ ~ M P I-04A Ori~- GL = 35' (NABORS 27E) 2-7/8" 8rd TREE TOP CONNECTION 13 3/8", 54.5#/ft, K-55 Weld Set 115' 9 5/8", 36#/ft, K-55 Butt 2599~ 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) KOP @ 600 ' Max wellbore Angle: 38° @ 2200' MD Hole angle trough perfs = 90 deg. N SAND PERFORATION SUMMARY Size SPF Interval (ND) 24 gm 24 4,383' - 4392' 3860' - 3868' 24 gm 24 4,411' - 4428' 3885' - 3901' 24 gm 24 4,443' - 4451' 3914' - 3921' 4" Deployment Sleeve top of liner 4,499' Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4510' 4" Deployment Sleeve top of liner 4,531' Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4536' O SAND PERFORATION SUMMARY (SQUEEZED OFF, BELOW CEMENT RETAINER) Size SPF Interval (ND) 37 gm 37 gm 5 5 4,554' - 4,588' 4,624' - 4,655' 4,015' - 4,045' 4,078' - 4,106' Camco 2-7/8" x 1" 160' sidepocket KBMM GLM ~ Heat trace run to 3450' RA Tag @ 3,623' Camco 2-7/8" x 1" 040' 4 sidepocket KBMM GLM , 2-7/8" XN nipple 176' 4 (ID 2.205") , WeIILift DGU 4,211 ` Centrilift Tandem ESP ` 63-G-12 MVP/SSD 4,223 68-P6 SXD Tandem Gas Separator 244' 4 GRSFTX AR H6 , Tandem Seal Section ~ Model GSB3 DB UT/LT 4,249 SB/SB PFSA Motor, 76 HP, 1360 volt, 4 262' 34 amp, Model KMH , Well~ift MGU 4,269` w/6 fin Centrafizer 7" Halliburton 23-29# "VTL" Versa-trieve Packer H-S 3-1/2" X-O H-S 3-1/2" 250 micron "Poroplus" Screen (87' total, 4371' - 4458') Baker Seal Assembly 7" Baker "SLZXP" Packer (4.5" ID) 4-1/2" Halliburton X Nipple (3.813" ID) @ 4475' Tubing Tail @ 4477.5' IHole td @ I-04A L1 ~~. 81 jts. of Pre-Drilled 2-3/8" (4,560' - 7,151') 2-3/8" 4.6#, L-80 STL tubing. Baker Guide shoe @ 7,184' I Hole td @ I-04A ~~. 69jts. of Pre-Drilled 2-3/8" (4,583' - 6,794') 2-3/8 " 4.6#, L-80 STL tubing. Baker Guide shoe @ 6,834' 7", 26#/ft, L-80 Butt Shoe 4,881' DATE IREV. BY I COMMENTS 3/9/95 RWO - INSTALL ESPCP 7/22/01 B. Hasebe Nabors 4ES Completion 118//05 Lee Hulme Nabors 4ES Completion 10/29/09 REH ESP RWO w/HT - Nabors 4ES MILNE POINT UNIT WELL I-04A ~i rvn• ~n_n~a_~~nF~ BP EXPLORATION (AKl • ~ BP EXPLORATION Page 1 of 7 C~perations ~ummary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date' From - To Hours Task ~ Code NPT ~ Ph 10/23/2009 106:00 - 18:00 I 12.001 MOB I N I WAIT I PRE 18:00 - 00:00 I 6.00 ~ MOB I N I VVAIT I PRE 10/24/2009 100:00 - 06:00 I 6.001 MOB I N I WAIT I PRE 06:00 - 18:00 I 12.00 I MOB I N I WAIT I PRE 18:00 - 21:30 I 3.501 MOB I P I I PRE 21:30 - 22:00 I 0.50I MOB I P 22:00 - 00:00 I 2.00 I MOB I P 10/25/2009 I 00:00 - 03:00 I 3.00 I MOB ~ P 03:00 - 09:00 I 6.001 MOB I P 09:00 - 12:00 I 3.001 RIGU I P Spud Date: 11/15/1990 Start: 10/16/2009 End: Rig Release: 10/30/2009 Rig Number: 4ES ase ~ Description of Operations WAITING FOR CTU TO VACATE MPI PAD SO WE CAN MOVE RIG ON MPI PAD. -WAITING FOR CTU TO VACATE MPI-04 -RIGGING DOWN, CLEANING RIG -HANGING DOUBLE SHEAVE WAITING FOR CTU TO VACATE MPI PAD SO WE CAN MOVE RIG ON MPI PAD. RIG STILL OVER MPL-29. -LRS FREEZE PROTECTED MPL-29 WELL BY BULLHEADING 65-BBLS. DEAD CRUDE DOWN IA AND BULLHEADING 15-BBLS. DEAD CRUDE DOWN TUBING. WAITING FOR CTU TO VACATE MPI PAD SO WE CAN MOVE RIG IN MPI PAD. -CTU HAD MEOH SPILL. MPU ENVIROMENTAL CIEANING UP SPILL. -RIG CREW CONTINUING TO DISCUSS INPUT TO SAFE WORK PLAN. -MPU WELL OPS MOVED ESP CABLE SPOOLER TO MPG PAD FOR STAGING TO MPI PAD. -REVIEWED MPU WELL TRACKING TOOL OUTPUT FOR MPL-29 WITH DAY CREW. -GAINED INDIVIDUAL COMMITMENT FROM EACH CREW MEMBER THAT THEY ARE +100% COMMITTED TO WORKING IN A SAFE AND CONTROLLED MANNER AT ALL TIMES AND THAT THEY WILL ALWAYS LOOK OUT FOR EACH OTHER AND THAT THEY ARE EACH RESPONSIBLE FOR THEIR OWN SAFETY AS WELL. -16:00-HRS. RECEIVED RELEASE FROM MPU WELL OPS TO COMMENCE RIG MOVE TO MPI PAD. R/D FLOWLINE, SCOPE DOWN AND LOWER DERRICK. -BLOW DOWN AND UNHOOK LINES. -PULL PITS FROM SUB. -NOTIFIED AOGCC WITH 24 HOUR NOTICE OF UPCOMING PRE PEAK TRUCKS AND PUSHER ON LOCATION. HOLD PREJOB MEETIfVG FOR RIG MOVE WITH ALL PERSONNEL. LOAD SHOP AND MOVE OUT OF WAY. PRE MOVE PIPE SHED, PITS AND SUB OFF WELL. NOTIFIED PAD OPERATOR OF IMPENDING MOVE PRIOR TO MOVING SUB OFF WELL. PICKED UP HERCULITE BERM AND RIG MATS AROUND WELL CELLAR. CLEANED UP AROUND WELL CELLAR AND LOADED OUT RIG MATS AND DUNNAGE ON LOWBOY. PRE CLEANED UP AROUND WELL CELLAR AND LOADED OUT RIG MATS AND DUNNAGE ON LOWBOY. LINE UP MODULES IN ORDER OF MOVE TO ARRIVE AT MPI PAD IN PROPER ORDER. PRE MOVE RIG COMPONENTS FROM MPL PAD TO MPI PAD. TRUCK WITH SUB SPUN OUT ON TRACT 14 INTERSECTION. WAITED 20 MINUTES ON GRAVEL FOR TRACTION AND RESUMED MOVE. ARRIVED ON MPI PAD AT 09:00-HRS. PRE SPOT SUB, PIPE SHED AND PITS. PREPARE TO RAISE Printed: 11/12/2009 9:23:06 AM ~ ~ BP EXPLQRAT~ON Page 2 of 7 Qperations Summary Report Legai Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4~S Date Fr~rm - Tv ~ Haurs Task Code NPT Phase Description of 4perations 10/25/2009 09:00 - 12:00 12:00 - 12:30 12:30 - 16:30 16:30 - 17:00 17:00 - 18:30 18:30 - 19:00 19:00 - 21:30 21:30 - 22:00 22:00 - 23:30 3.00 RIGU P PRE DERRICK. DEPLOYED CoW SIGN AT ENTRANCE TO PAD. 0.50 RIGU P PRE PJSM: REVIEWED RAISING DERRICK AND SCOPING DERRICK PROCEDURES WITH ALL CREW. 4.00 RIGU P PRE RAISE DERRICK TO HALF MAST. SCOPE DERRICK TOP SECTION UP AND PIN IN PLACE. HOOK UP CIRCULATING LINES BETWEEN PITS AND SUB. HOOK UP CIRCULATING LINES FROM CHOKE TO TIGER TANK. " ACCEPTED RIG AT 15:00-HRS. *` 0.50 WHSUR P DECOMP ALL CREW: REVIEWED PLAN FORWARD AND PULL BPV PROCEDURE. LOAD LUBRICATOR INTO PIPE SHED. 1.50 WHSUR P DECOMP PUMU LUBRICATOR AND MAKEUP TO SWAB VALVE. PRESSURE TESTED LUBRICATOR AGAINST CLOSED SSV T0500-PSI WITH DIESEL. -PULL CAMERON 2-1/2" TYPE "H" BPV. -TUBING PRESSURE 300 PSI, IA PRESSURE 300 PSI AND OA PRESSURE 200 PSI. 0.50 KILL P DECOMP R/U LINESTO KILL WELL. -CIRULATING LINES WERE PRESSURE TESTED TO 3,500 PSI. RETURN LINE TO TIGER TANK WAS TESTED TO 120 PSI. 2.501 KILL I P 0.501 KILL I P 1.50I WHSUR I P 23:30 - 00:00 0.50 WHSUR P ~ 10126/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 03:00 2.00 BOPSU P 03:00 - 04:00 1.00 BOPSU P 04:00 - 10:00 I 6.001 BOPSUFi P DECOMP KILL WELL BY PUMPING 120 DEGREE SEAWATtH U N THE TUBING TAKING RETURNS OUT THE IA THROUGH HE CHOKE MANIFOLD TO THE TIGER TANK. PUMP ~ TUBING VOLUME OF 25 BBLS AT 4 BPM WITH 500 PSI. LINE UP AND BULLHEAD 25 BBLS AT 3 BPM WITH 1,000 PSI DROPPING TO 350 PSI. LINE UP AND PUMP DOWN THE TUBING TAKING RETURNS THROUGH THE CHOKE TO THE TIGER TANK AT 4 BPM WITH 350 PSI. HEAVY CRUDE RETURNS CLEANING UP TO CLEAN 8.5 PPG SEAWATER RETURNS. 40 -45 PERCENT RETURNS DURING WELL KILL. DECOMP MONITOR WELL, 0 PSI ON TUBING, 0 PSI ON IA. -BOTH TUBING AND IA ARE ON A VAC. DECOMP INSTALL CAMERON 2-1/2" TYPE "H" TWC WITH CAMERON WELLHEAD TECH AND TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES. TEST FROM BELOW BY PUMPING AT 4 BPM WITH 300 PSI FOR 10 MINUTES ON THE CHART. DECOMP N/D 2-9/16" 5M WKM TREE AND ADAPTOR FLANGE. DECOMP N/D 2-9/16" 5M WKM TREE AND ADAPTOR FLANGE AND REMOVE FROM CELLAR. -INSPECT AND FUNC710N LDS. -INSPECT HANGER THREADS, 2-7/8" EUE, 9 TURNS TO MAKE UP IN HANGER. DECOMP N/U 13-5/8" 5M HYDRIL BOP STACK. -HOOK UP CHOKE AND KILL LINES. -HOOK UP KOOMEY LINES AND TURNBUCKLES. INSTAL FLOW RISER. DECOMP M/U BOP TEST ASSEMBLY. - FILL BOPE WITH WATER AND PURGE AIR FROM SYSTEM. DECOMP TEST Rl1PG T~l oGn DQI i!1\A/ nnin ~ cnn Dc~ 4.11l~H TFST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND Kl~L rnrnea: nnuzuua a:z~:uor+nn ~ ~ BP EXPLORATION` Page 3:of ~ Operatians Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date I From - To ` Hours I Task Code NPT Phase ~ Deseription of Operations 10/26/2009 I04:00 - 10:00 I 6.00 I BOPSUFI P 10:00 - 18:00 I 8.00 I W HSUR I C 18:00 - 22:00 I 4.001 WHSUR I C 22:00 - 23:00 I 1.00 I WHSUR I C DECOMP LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALL TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. -UNABLE TO OBTAIN GOOD TEST OF 2-7/8" X 5" VBR'S, AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. LAYED DOWN 2-7/8" TEST JOINT, CLOSED BLIND RAMS, KILL AND CHOKE HCR VALVES. PRESSURED UP BOPE TO 3500-PSI AND DISCONNECTED TEST HOSE TO ISOLATE TEST PUMP. PRESSURE BLED OFF -200-PSI IN 10-MINUTES. INSPECTED BOPE STACK VISUALLY AND OBSERVED NO LEAKS. MADE DECISION TO CHANGE OUT TWC. DECOMP PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. PUMU MPU WELL SUPPORT LUBRICATOR AND MADE UP TO LUBRICATOR LOCKDOWN MANDREL. PRESSURE TESTED LUBRICATOR TO 500-PSI WITH DIESEL. UNABLE TO OBTAIN PRESSURE TEST. FOUND DUTCH LUBRICATOR LOCKDOWN MANDREL EXTENSION SEAL LEAKING. LAYED LUBRICATOR AND DUTCH LUBRICATOR LOCKDOWN MANDREL DOWN. SEPARATED LOCKDOWN MANDREL EXTENSION AND FOUND INTERNAL STOP RING NOT SET HIGH ENOUGH TO ALLOW PROPER MAKEUP OF JOINT. ADJUSTED STOP RING TO PROPER DEPTH AND REASSEMBLED LOCKDOWN MANDREL. PICKED UP AND RESET LOCKDOWN MANDREL AND LUBRICA70R. SUCCESSFULLY PRESSURE TESTED LUBRICATOR TO 500-PSI. PULL AND INSPECT TWC. OBSERVED DISPLACED AND CREASED O-RING ON TWC. WELL ON VACUUM. LAYED DOWN LUBRICATOR AND DUTCH LUBRICATOR LOCKDOWN MANDREL. MPU WELL SUPPORT SET NEW TWC WITH T-BAR. ATTEMPTED TO PRESSURE TEST SECOND . UNABLE TO O SUCCESSFUL PRESSURE TEST. -PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. PUMU MPU WELL SUPPORT LUBRICATOR AND MADE UP TO LUBRICATOR LOCKDOWN MANDREL. PRESSURE TESTED LUBRICATOR TO 500-PSI WITH DIESEL. MPU WELL SUPPORT PULLED SECOND TWC. NO APPARENT DAMAGE TO TWC OBSERVED. DECOMP -WAITING ON WEATHERFORD WIRLE LINE RETRIEVABLE PLUG AND SLB WIRE LINE UNIT. RIG CREW HUNG ESP CABLE TRUNK. KEEPING THE HOLE FULL W/ 20 BLM. DECOMP -WEEKLY SAFETY MEETING DISCUSSION INVOLVED SLIPS TRIPS AND FALLS, RECENT SLB VEHICLE ACCIDENT. WENT THROUGH SAFETY STATS WITH NAD SAFETY TRAINER JOHN SMITH. INCLUDED RIGS 4, 7 AND 9 Printed: it/12/2009 923:06AM • • BP EXPLORATION Page 4:of 7 Operations Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To I Hours Task ~ Code NPT Phase , Deseription of Operations 10/26/2009 22:00 - 23:00 23:00 - 00:00 10/27/2009 I 00:00 - 03:00 03:00 - 06:00 06:00 - 12:00 12:00 - 16:30 16:30 - 17:30 -TEST 1,500 PSI -10 CHARTED MINUTES. -GOOD TEST 1.00 WHSUR C DECOMP 1.00 WHSUR C DECOMP -SPOTTING SLB WIRLE LINE EQUIPMENT, PJSM WITH SLB WIRLE LINE CREW AND RIG CREW, WIRELINE WSL JOHN PERL. 3.00 WHSUR C DECOMP -PJSM WITH SLB WIRE LINE AND RIG CREW, WIRELINE UNIT WSL-JOHN PEARL PUMU WIRELINE TOOLS, SHEAVES, PUMP SUB, LUBRICATROR AND WIRELINE BOP. PRESSURE TEST SLB LUBRICATOR TO 500 PSI AGAINST BLIND RAMS. 3.00 WHSUR C DECOMP -MAKE UP WEATHERFORD 2-7/8" WIRELINE RETRIEVABLE PLUG. -RIH TO 135' (MIDDLE OF FIRST FULL JNT ABOVE GLM AT 160'). -FIRST AND SECOND ATTEMPTS TO SET PLUG UNSUCCESSFUL. -SET WRP SUCCESSFULLY ON THIRD ATTEMPT. 6.00 WHSUR C DECOMP PRESSURE TEST BOPE AND WRP TO 3500-PSI FOR 10-CHARTED MINUTES. -UNABLE TO GET STABLE PRESSURE TEST. PRESSURE BLED OFF 250-PSI IN 30-MINUTES. BLED OFF AND REPRESSURED SEVERAL TIMES WITH SAME RESULTS. -MADE DECISION TO REMOVE CHOKE LINE AND KILL LINE FROM BOPE STACK TO VISUALLY VERIFY THAT MANUAL CHOKE AND KILL VALVES AND HCR CHOKE AND KILL VALVES ARE NOT LEAKING. DRAINED BOP STACK. REMOVED LINES. REFILLED STACK WITH WATER. -HELD PJSM FOR SAFE ROMAVAL OF THE CHOKE AND KILL LINES TO VISUAL CHECK. -ALSO CALLED OUT CAMERON WELLHEAD TECH. TO RE-VERIFY THAT LOCKDOWN SCREWS ARE ALL PROPERLY TORQUED. -RESEARCH ALSO INDICATES THAT ADAPTER FLANGE API RING AND TUBING HANGER AND PENETRATOR SEALS WERE NOT PRESSURE TESTED AND VERIFIED PRIOR TO MOVING RIG ON WELL. CAMERON VERIFIED LOCKDOWN SCREWS ARE PROPERLY TORQUED. CAMERON HAND TORQUED THE LOCK DOWNS TO 620 FOOT PUNDS A PIECE. -RE-TEST BOPE AND WRP AFTER VERIFIYING LOCKDOWN SCREWS WERE PROPERLY TORQUED. -STILL UNABLE TO GET STABIE.PRESSURE TEST. PRESSURE BLED OFF 250-PSI IN 45 MIN. 4.50 WHSUR C DECOMP -COMMUNICATED THE RESUL.TS WITH ADW RWO ENGINEERING IN TOWN. WAITING FOR A RETURN CALL FOR PLAN FORWARD. -RECONNECTING THE CHOKE AND KILL LINES TO THE BOPE STACK. 1.00 WHSUR C DECOMP PRESSURE TEST TBG HANGER AND WRP Printed: 11/12/2009 9:23:06 AM • ~ BP EXPLORATION Page 5 of 7 Qperations Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date Fram - To Hours Task Code NPT Phase " Description of Operations 10/27/2009 17:30 - 19:00 1.50 WHSUR C DECOMP PRESSURE TEST TBG HANGER -SCREW 2-7/8" TEST JOINT INTO HANGER. -CLOSE ANNULAR ON 2-7/8" TEST JOINT. -TEST 1,500 PSI -LD DUTCH LOCK DOWN MANDRIL SYSTEM -PU NEW HANGER 19:00 - 19:30 0.50 WHSUR C DECOMP RD SLB WIRELINE LUBRICATOR ANO SHEAVES. -FILL HOLE C~ 20 BPH 19:30 - 21:30 2.00 WHSUR C DECOMP RU 2-7/8" ELEVATORS, INSTALLED LANDING JNT. ~,~ -SUCK OUT THE BOPE STACK ~~( -BACKED OUT LOCK DOWN SCREWS, PULLED 2-7/8" V )~ ~ TUBING HANGER TO RIG FLOOR, CUT AND SUCURE ESP ~ ~ CABLE. -C/O HANGER FOUND THE P P/U WEIGHT38 K 21:30 - 22:00 0.50 WHSUR C DECOMP RUN IN AND LAND NEW BLANKED OFF TUBING HANGER -RUN IN LOCK DOWN SCREWS , PUW (35 (K), SOW-30 (K). 22:00 - 00:00 2.00 B - DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KI~L ~ ~ LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR i/b G'~" ( I_~ r~ PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. ' ~ -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALL TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. 10/28/2009 00:00 - 01:30 1.50 BOPSU DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH. TEST BLINDS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, FLOOR VALVES, 2-7/8" X 5" VBR'S, ANNULAR PREVENTER. TEST VBR'S AND ANNULAR PREVENTER WITH 2-7/8" TEST JOINT. PERFORM DRAWDOWN TEST ON KOOMEY. -AOGCC WITNESS OF TEST WAS WAIVED BY JOHN CRISP. ALL TESTING WITNESSED BY NABORS TOOLPUSHER AND BP WSL. 01:30 - 03:30 2.00 WHSUR DECOMP PUMU DUTCH LUBRICATOR LOCKDOWN MANDREL. -PUMU SLB WIRELINE LUBRICATOR AND WIRLELINE VALVE, MAKE UP TO DUTCH LOCK DOWN SYSTEM -PRESSURE TEST TO 500 PSI WITH DIESEL, GOOD TEST. -PULL WEATHERFORD WIRELINE RETRIEAVABLE PLUG. 03:30 - 05:00 1.50 WHSUR DECOMP RD SLB WIRELINE LUBRICATOR,SHEAVES. -RD DUTCH MANDRAL LOCK DOWN SYSTEM 05:00 • 06:00 1.OQ WHSUR DECOMP CIRCULATING BU -STAGING UP PUMPS, STARTING AT 3 BBPM LINED UP TO THE TIGER TANK TO AVOID INTRODUCING CRUDE TO THE ACTIVE 06:00 - 07:30 1.50 WHSUR DECOMP FINISHED CIRCULATION -CAMERON BACKED OUT LOCK DOWN SCREWS -PULLED 2-7/8" TUBING HANGER -PU WT 38 (K) -BREAK OUT LAY DOWN HANGER Printed: 11/12/2009 9:23:06 AM ~ • BP EXPLORATION' Page s ot ~ Uperatians Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: WORKOVER Start: 10/16/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/30/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To ~ Hours Task ~ Cade NPT Phase Description of Qperations 10/28/2009 I 07:30 - 11:00 3.501 PULL DEGOMP POH W/ 2-7/8" TBG, ESP & CABLE. - ANDING BACK 43 STANDS OF 2-7/8" TSG IN DERRICK,LD 3 SINGLES -LD 3 SINGLES LD 2 GLMS AND 4 PUP JTS. -CONTROLLING WELL WITH 20-BPH HOLE FILL. -ESP PULLED TO SURFACE AT 11:00-HRS. -RECOVERED 129 JTS. 2-7/8" 8RD. TUBING, 1- XN NIPPLE, 2 EA. OF 2-7/8" X 1" GLM'S AND PUPS, LASALLE CROSS COUPLING CABLE CLAMPS, DECOMP BREAK OUT AND LAY DOWN ESP BHA. -DETACH ESP CABLE FROM MOTOR. -CENTRII.IFT DISASSEMBLED ESP BHA SECTION BY SECTION INSPECTING EACH SECTION. -SPOOLED UP CABLE INTO CABLE SPOOLER. -RECOVERED 74 LASALLE CLAMPS. DECOMP CLEAN AND CLEAR RIG FLOOR RUNCMP -R/D ELEPHANT TRUNK. -R/U TO RUN ESP. RUNCMP PJSM TO RUN COMPLETION -PU/MU ESP PUMP AND MOTOR ASSEMBLY. RUNCMP RUN I-WIRE TO SENSOR AND PUMP. -TEST ESP AND ESP CABLE CONNECTION -CREW MEETING WITH OPS SUPERINTENDANT, DISCUSS SAFE WORK PLAN WITH CREW. RUNCMP RIH WITH ESP COMPLETION RUN ESP ON 2-7l8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE OF 2,300 FT/LBS. -ATTACH ESP CABLE TO TUBING WITH LASALLE CLAMPS. RUNCMP RIH W ITH ESP COMPLETION, W ITH HEAT TRACE. RUN ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE OF 2,300 FT/LBS. -ATTACH ESP CABLE AND HEAT TRACE TO TUBING USING CANNON CLAMPS. RUNCMP RIH WITH ESP COMPLETION, WITH HEAT TRACE. RUN ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. -USE BEST-O-LIFE 2000 PIPE DOPE, AVERAGE MAKE UP TORQUE OF 2,3Q~ FTlLBS. -ATTACH ESP CABLE AND HEAT TRACE TO TUBING USING CANNON CLAMPS. -CHECKING CONNECTIVITY EVERY 2000' , PUMPING 1 BMP ~ 1750 PSI -FLUSHED ESP WITH 10 BBLS PUMPING 11 SPM C~3 1750 PSI -RAN 133 JOINTS 2-7/8" TBG -30 LASALLE CLAMPS , 2- SM CANNON CLAMPS, 9-PUMP CLAMPS, 12- TWO FOOT CLAMPS, 84- CROSS COUPLING CLAMPS, 519 FIVE FOOT CLAMPS, 2- STAINLESS BANDS RUNCMP CREW MEETING WITH NABORS DRILING SUPERINTENDENT ON RECENT HSE EVENT AND SAFE WORK PLAN. RUNCMP RIH WITH ESP COMPLETION, WITH HEAT TRACE. RUN 11:00 - 13:00 I 2.001 PULL 13:00 - 14:00 1.00 PULL 14:00 - 15:00 1.00 RUN( 15:00 - 19:00 4.00 RUNC 19:00 - 21:00 2.00 RUN( 21:00 - 23:00 2.00 23:00 - 00:00 1.00 10/29/2009 00:00 - 12:00 12.00 12:00 - 13:00 I 1.00 13:00 - 16:30 I 3.50 Printed: 11/12/2009 9:23:06 AM . # +! BP EXPLORATIQN Page 7 of 7 Operations ~ummary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPI-04 MPI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Da#e From - To ( F 10/29/2009 13:00 - 16:30 16:30 - 18:00 18:00 - 20:00 20:00 - 20:30 20:30 - 21:30 21:30 - 23:00 23:00 - 00:00 I 10/30/2009 I 00:00 - 02:00 02:00 - 03:00 03:00 - 06:00 Start: 10/16/2009 Rig Release: 10/30/2009 Rig Number: 4ES Spud Date: 11/15/1990 End: urs Task ~ Code NPT Phase Description af Operations 3.50 RUNCO RUNCMP ESP ON 2-7/8" 6.5#, L-80, EUE 8 ROUND TUBING. 1.50 RUNCO RUNCMP M/U 2-7/8" TBG HANGER -CAMERON SET TWC IN TUBING HANGER. -SPACE OUT FOR SPLICES -INSTALL ESP/HT PINETRATORS. -CUT ESP/HEAT TRACE CABLE. -PULL CABLES OVER SHEAVE. -FEED W ELL AT 20 BPH SEAWATER. 2.00 RUNCO RUNCMP CENTRILIF7 SERVICE TECH. ATTACHED LOWER FIELD ATTACHABLE CONNECTOR AND MADE CONNECTION TO WELLHEAD PENETRATOR. -ATTACH ESP CONNECTION TO PENETRATOR AND TEST CONNECTIONS. 0.50 RUNCO RUNCMP LAND TUBING HANGER. P/U WEIGHT 35K, S/O WEIGHT OK. -RUN IN LOCK DOWN SCREWS. TORQUE LOCK DOWN SCREWS TO 450 FT/LBS. -BACK OUT AND UD LANDING JOINT. 1.00 RUNCO RUNCMP TEST CAMERON 2-1/2" TYPE "H" TWC FROM ABOVE TO BELOW BY INJECTVNG AT 4 BPM WITH 200 PSt FOR 10 MINUTES.(CHARTED) BH 40 BBLS 1.50 WHSUR P RUNCMP UNHOOK CHOKE AND KILL LINES. UNHOOK KOOMEY LINES. -N/D 13-5/8" 5M, HYDRIL BOP STACK AND STAND BACK ON STAND. 1.00 WHSUR P RUNCMP INSPECT WELLHEAD. -N/U ADAPTOR FLANGE AND 2-9/16" 5M TREE. -TEST HANGER VOID TO 5,000 PSI FOR 30 MINUTES, GOOD TEST. -TEST TREE TO 5,000 PSI WITH DIESEL FOR 10 MINI 2.00 WHSUR P RUNCMP R/U WELL SUPPORT LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PUI.L 2-1/2" CAMERON TYPE "H" BPV 1.00 WHSUR P RUNCMP INSTALL CAMERON 2-1/2" TYPE "H" BPV WITH WELLHEAD TECH. TEST FROM BELOW TO 1,000 PSI FOR 10 MINUTES BY INJECTING AT 4 BPM. 3.00 WHSUR P RUNCMP BLOW DOWN AND RIG DOWN LINES. SECURE WELL AND CELLAR. '*RIG RELEASED AT 06:00 HOURS ON 10/30/2009" -AFTER ACTION REVIEW WITH CREW Printed: iinzizous s:zs:utiann MPI-04 r~ L ~ ~ Schwartz, Guy L {DOA) ~~~~ From: Schwartz, Guy L (DOA) Se~t: Tuesday, October 27, 2009 5:16 PM To: 'Nadem, Mehrdad' Cc: 'ReemDC@bp.com ; Regg, James B (DOA) Subject: RE: MPI-p4 Page 1 of 2 ~4~- D~ Z-- Nadem, I will approve the variance as stated below for testing BOP's. The fact that the weil is on a vacuum certainly heips. Please verify if the wellhead LDS's were cycled and voids were tested before the rig arrived. Seems odd that the tubing hanger seals and or penetrators are leaking now and wasn't known beforehand. Also, I would like diagrams of the Cameron wellhead , tubing spool and hanger as soon as possible. Regards, Guy Schwartz Petroleum Engineer AOGCC 793-1226 (ofFice) 444-3433 (cell) ; ~ ~~, ~~~~ ~ J~9 ~~~~,~ 1 ~ ~ ., . ~ ,~;~;~ ~ From: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Tuesday, October 27, 2009 4:35 PM To: Schwartz, Guy L (DOA) Subject: MPI-04 Guy, Thank you for being available to discuss our BOP test plan for MPI-04. As discussed, we have been unable to test BOPS due to tubing hnager leak. We installed two TWCs, and a WRP before we contacted you ta discuss an alternate plan. Although, we received verbal approval to proceed, please send a written note fo our files. Betow is the brief summaty of our plan to test the BOPs. 1 can be ~eached at 440-0213 if you have commnets. I appreciate your help on this matter. PU landing joint and MU to the "OI.D" tubing hanger. Ciose the annular and the VBR on the Ianding joint and test in between the rams to 1,540 psi for 10 minutes. This will test the bag to above the well's MAASP. Open rams. BOLDS. PU w/completion. Secure ESP cable to tbg. LD the existing tubing hanger. MU new tbg hanger to the completion string. Land the new tubing hanger with TWC installed. RILDS. Test to 3,500 psi for 10 minutes from above with the annular preventer closed around landing jt. If test is suecessful, Continue with testing the BOPs. 10/28/~009 MPI-04 Page 2 of 2 ~ ~ Regards, Mehrdad Nadem phone:907/564-5941 Cel t: 907/440-0213 Email: nademmC bp.com 10128/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfihn _Marker. doc STATE OF ALASKA ALASK4tIL AND GAS CONSERVATION C&lsslorRECEIVEC) REPORT OF SUNDRY WELL OPERATIO~~ 03 2006 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend IS! Repair Well IS! Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver IS! Other o Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: IS! Development 0 Exploratory o Stratigraphic 0 Service 5. Permit 0 rill Number: 201-092 6. API Number: 50-029-22068-01-00 99519-6612 70 9. Well Name and Number: MPI-04A 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 6888 feet true vertical 4125 feet Plugs (measured) None Effective depth: measured 6888 feet Junk (measured) None true vertical 4125 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 115' 115' 2730 1130 Surface 2564' 9-5/8" 2599' 2354' 3520 2020 Intermediate Production 4501' 7" 4536' 3999' 7240 5410 Liner 2304' 2-3/8" 4530' - 6834' 3993' - 4126' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): 4583' - 6888' 4038' - 4125' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 4273' Packers and SSSV (type and measured depth): 7" Halliburton 23-29# VTL Versa-trieve 7" Baker "SLZXP" 4338' 4483' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFr, o 4 2006 Oil-Bbl Re resentative Dail Gas-Mcf Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run IS! Daily Report of Well Operations IS! Well Schematic Diagram 15. Well Class after proposed work: o Exploratory IS! Development 0 Service 16. Well Status after proposed work: IS! Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my knowledge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sondra Stewman Title Technical Assistant Phone 564-4750 Date epared By Name/Number: ondra Stewman, 564-4750 Submit Original Only AL TREE: 2-9/16" - 5M WKM WELLHEAD: 11" 5M WKM WI. 2-7/8" 8rd TREE TOP CONNE N 13 3/8", 54.5#/ft, K-55 Weld Set 115' 95/8", 36#/1t, K·55 Butt 2599' 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. (drift ID = 2.347". cap. = 0.00592 bpf) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) KOP @ 600 ' Max wellbore Angle: 38" @ 2200' MD Hole angle trough perfs = 90 deg. N SAND PERFORATION SUMMARY Size SPF Interval (TVO) 24 gm 24 4,383' - 4392' 3860' - 3868' 24 gm 24 4,411' - 4428' 3885' - 3901' 24 gm 24 4,443' - 4451' 3914' - 3921' 4" Deployment Sleeve top of liner Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4510' MP I-04A\L \ 4" Deployment Sleeve top of liner 4,531' Baker 3.5" FL4S x 2-3/8" FL4S Top of window @ 4536' o SAND PERFORATION SUMMARY (SQUEEZED OFF, BELOW CEMENT RETAINER) Size SPF Interval (rVD) 37 9 5 4,554' - 4,588' 4,015' - 4,045' 37 gm 5 4,624' - 4,655' 4,078' - 4,106' 7", 26#/ft, L-80 Butt Shoe 4,881' COMMENTS 3/9/95 RWO -INSTAll ESPCP 8-29-96 ESP RWO POLAR #1 Nabors 3S CTU Drilling sidetrack DATE REV. BY 7/13/01 MOO 7/22/01 B. Hasebe 118//05 Lee Hulme Nabors 4ES Completion Nabors 4ES Completion _rig. KB - SL = 52' (NABORS 27E) rig, KB - Gl = 35' (NABORS 27E) Camco 2-7/8" x 1" I 160' I sidepocket KBMM GLM RA Tag @ 3,623' Camco 2-7/8" x 1" sidepocket KBMM GLM I 4,040'1 14,176' I 14,231' I 14,244' I GRSFTX AR H6 Intake 4,244' MD = 3,734' TVD Tandem Seal Section I I Model GSB3 DB UT/l T Il 4,249' H6 PFS Aflas/HSN Motor, 83 HP, 2330 volt, 14,262' I 30 amp, Model KMH-A 2-7/8" XN nipple (10 2.250") Centrilift, 130 Stg, 400P8 Model - SSD Tandem Gas Separator PumpMate w/6 fin Centralizer 14,273' PumpMate = 3,760' TVD 7" Halliburton 23-29# "VTL" Versa-trieve Packer H-S 3-1/2" X-O H-S 3-1/2" 250 micron "Poroplus" Screen (87' total, 4371' - 4458') Baker Seal Assembly 7" Baker "SLZXP" Packer (4.5" ID) 4-1/2" Halliburton X Nipple (3.813" ID) @ 4475' Tubing Tail @ 4477.5' 1-04A L 1 Hole td @ 7173' 81 jts. of Pre-Drilled 2-3/8" (4,560' - 7,151 ') 2-3/8" 4.6#. l-80 STL tubing. Baker Guide shoe @ 7,184' 1-04A. Hole td @ 6895' 69 jts. of Pre-Drilled 2-318" (4,583' - 6,794') 2-3/8 "4.6#, L-80 STL tubing. Baker Guide shoe @ 6.834' BP EXPLORATION (AK) .. .. e BP EXPLORATION Operations Summary Report Page 1 of1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-04 MPI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/31/2005 11/1 0/2005 Spud Date: 11/15/1990 End: 11/10/2005 Date From-To Hours Task Code NPT Phase Description of Operations 11/7/2005 18:00 - 20:00 2.00 MOB P PRE Lower & Scope down derrick. RID rig equip, 20:00 - 21 :00 1.00 MOB P PRE Rig Down rig & prepare to move rig. 21 :00 - 23:00 2.00 MOB P PRE Move from MPH-14 to MPI -04. 23:00 - 00:00 1.00 RIGU P PRE Layout herculite & matting boards. Spot rig over MPI-04 wellhead. 11/8/2005 00:00 - 00:30 0.50 RIGU P PRE Con't to spot in sub, pits & pipe shed. Spot camp. Rig up rig, 00:30 - 02:00 1.50 RIGU P PRE Raise & scope up derrick. Con't to R/U. 02:00 - 04:00 2.00 WHSUR P DECOMP ACCEPTED RIG @ 0200 hrs.. R/U lines to X-mas tree & tiger tank. Take on seawater. 04:00 - 06:00 2.00 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator. Con't to Take on seawater. 06:00 - 06:30 0.50 WHSUR P DECOMP PJSM. Pressure test lines @ 1000/3500 psi, OK. 06:30 - 08:30 2.00 KILL P DECOMP PJSM. Circulate heated seawater down tubing @ 4.5 bpm 150 psi., no returns up backside. Bullhead down IIA @ 4.5 bpm. Monitor well, well dead, 08:30 - 10:00 1,50 WHSUR P DECOMP PJSM. Set two way check valve & test @ 3500 psi, OK. N/D tree & check threads in hanger, OK, 10:00 - 12:30 I 2.50 BOPSUE P DECOMP PJSM. N/U 135/8" x 5M BOPE, 12:30 - 17:30 5,00 BOPSUE P DECOMP PJSM. Conduct full test on BOPE, State Rep Chuck Sheve witnessed test of all components. Test successful, no issues. 17:30 - 00:00 6.50 PULL P DECOMP Pull TWC. BOLDS, pull hanger to floor and lay down same, POH wlESP completion laying down tubing 1 x 1. 11/9/2005 00:00 - 02:30 2.50 PULL P DECOMP POH wlESP completion laying tubing down 1 x 1, Layed down 131 jts. 2-7/8" 6.5#/ft, L80 tubing, 2 GLM's, 2 x 10 ft. 2-7/8" L80 pup joints. UD ESP assembly, 02:30 - 03:30 1.00 PULL P DECOMP Clean & clear rig floor. Swap cable reels in spooler. Remove ESP assembly and old tubing from pipe shed. 03:30 - 06:00 2.50 RUNCm,p RUNCMP Load pipe shed wlnew tubing and ESP assembly. Tally new tubing and ESP assembly. 06:00 - 06:30 0.50 RUNCm,p RUNCMP Lube & service rig. 06:30 - 09:00 2.50 RUNCOI ,p RUNCMP PJSM. Pick up & service ESP assembly. 09:00 - 14:30 5.50 RUNCOI ,p RUNCMP PJSM. Pick up & RIH wI ESP assembly and cable on 2 7/8" EUE 8 rnd, L80, 6.5# tbg. 14:30 - 17:00 2.50 RUNCOI ,p RUNCMP Make up tubing hanger & ESP penetrator, check ESP cables for continuity and insulation resistance to ground. Tested good. 17:00 - 18:00 1.00 RUNCOI ,p RUNCMP PJSM. Land hanger. P/U wt = 43K, Down wt = 35K. Set two way check & test to 3500 psi, OK. 18:00 - 19:00 1.00 BOPSUF P RUNCMP PJSM. N/D BOPE. 19:00 - 21 :30 2.50 WHSUR N HMAN RUNCMP PJSM. Attempt to N/U production tree. Tubing hanger misaligned. Alignment pin not screwed in all the way. UD tree, N/U BOPE. PIT body and break to 3500 psi. Test O.K. 19:30 - 22:30 3.00 RUNCOI f\J HMAN RUNCMP BOLDS. Unland tubing hanger, screw alignment pin in all the way, and reland same with proper allignment. RILDS. 22:30 - 00:00 1.50 BOPSUF N HMAN RUNCMP NID BOPE. 11/10/2005 00:00 - 03:00 3.00 WHSUR P RUNCMP N/U production tree. PIT tree and packoff to 5000 psi. Test O.K. P/U lubricator, pull TWC, set BPV. UD lubricator. Final check ESP cable for continuity and resistance to ground. Clear and clean cellar. Secure well. RELEASED RIG at 0300 hrs. Printed: 11/1112005 2:11:16 PM Permit to Drill 2010920 MD 6888 ~" TVD DATA SUBMITTAL COMPLIANCE REPORT 7130/2003 Well Name/No. MILNE PT UNIT SB 1-04A Operator BP EXPLORATION (ALASKA) INC 4125 f Completion Dat 7/19/2001 ~" Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22068-01-00 UIC N REQUIRED INFORMATION Mud Log N_..9o Sample N._9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ~-I'~LIS Verification (data taken from Logs Portion of Master Well Data Maint) Name Log Log Scale Media Run No Interval Start Stop OH / Dataset CH Received Number Comments Directional Survey Directional Survey 10328 ,~I~D Wellbore Profile / GR ~tET~esistivity / GR /_.~Resistivity / GR LIS Verificaiton 2/5 4510 6888 1 4540 5627 FINAL 201 93 FINAL FINAL 4510 FINAL 4840 FINAL 4840 FINAL 4840 FINAL 6888 6888 6888 6888 Open 9/24/2001 Open 5/6/2002 ch 9/7/2001 ch 9/7/2001 OH 9/24/2001 OH 9/23/2001 OH 9/24/2001 OH 9/24/2001 OH 9/24/2001 ~ 4510-6888 Directional Survey Digital Data (201-093 Inc) Directional Survey 10(.~..3.28 4510-6888 Digital Data 4840-6888 BL, Sepia 4840-6888 BL, Sepia 4840-6888 BL, Sepia LIS Verification Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ,~ Chips Received? Analysis Y / N,,.._-- R P.c.P. ivP. d ? Daily History Received? Formation Tops Permit to Drill DATA SUBMITTAL COMPLIANCE REPORT 2010920 Well Name/No. MILNE PT UNIT SB 1-04A 7/3012003 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22068-01-00 MD 6888 TVD 4125 Completion Dat 7/19/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: Transmittal Form BAKER HUGH~ Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Milne Point Unit MPI-04A Contains the fbllowing: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print l Borebole Profile i Sent By: Josef B~rg Received ~~.-~ (~~ Date: Sept 18, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED SEP 2 4 2001 Alaska Oil & Gas Cons. 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 E] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-092 3. Address ~8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22068-01 4. Location of well at surface ;--,.,-;';...,~:-,.¥.- ¥ ~ ~ ' ' , 9. Unit or Lease Name 2942' SNL, 3876' WEL, SEC. 33, T13N, R10E, UM ~ ........ ~ i LOCATION~' t;A~"-; i ~il~O I Milne Point Unit At top of productive interval I.._?_.___(.~:~ i I .$u~;~,~, ~ 1464' SNL, 2769' WEL, SEC. 33, T13N, R10E, UM ! V;.~i~ ! f 10. Well Number At total depth ~:.. MPI-04A 152' SNL, 1518' WEL, SEC. 33, T13N, R10E, UM i, _.~_--_..~.....~ ...... i _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 - 70' ADL 025906 12. Date Spudded7/1/2001 110' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'7/4/2001 7/19/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 6888 4125 FTI 6888 4125 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING, LINER AND CEMENTING RECORD .... CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE '" TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 35' 11'5' 30" ¢85 Sx Permafrost 'C' ' ............ 9-5/8" 36# J-55 35' 2599' 12-1/4" 1111 sx PF 'E', 244 sx Class 'G' 7" 26# L-80 35' 4536' 8-1/2" :)60 sx Class 'G' 2-3/8" 4.6# L-80 4530 6834' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-3/4" Open Hole 2-7/8", 6.5#, L-80 4299' None MD TVD MD TVD 4583' - 6794' 4038' - 4125' 6834' - 6888' 4126' - 4125' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED MPI-04 Original Perfs 4505' Set Flow Through Whipstock 4383' - 4392' 3860' - 3868' 4338' - 4483' Poroplus 250 Micron Screen Assembly 4411' - 4428' 3886' - 3901' 4443' - 4451' 3915' - 3922' 27. ' ' PRODUCTION TEsT ........ Date First Production Method of Operation (Flowing, gas lift, etc.) July 26, 2001 Electric Submersible Pump 'bate' of Test Hours Tested ' PFioDuoTi'ON FOR " .Oi.L".BBL. . GAs. McF " WATER.BBL CHOKE SIZE '/~/~S~01'L RATIO ........ 8/16/2001 6 TEST PERIOD 764 854 64 . I 1119 , , , Flow Tubing Casing Pressure CALCULATED OIL~BBL '" GAS. MCF WATER-DEL OIL'GRAvITY-API (CORR) '' Press. 24-HOUR RATE _28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE. CE VED AUG B 8 2001 Alaska ()il & Gas Cons. Commissio~ ............... Anchorage Form 10-407 Rev. 07-01-80 ORiGiNAL 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 of Schrader OA 4557' 4013' Base of OA / TSBC 4592' 4036' Top of Schrader OB 4653' 4059' Base of OB / TSBA5 4750' 4054' 31. List of Attachments: Summary of Daily Drilling Reports, sUrveys 32. I hereby certify that the fore~loing is true and correct to the best of my knowledge Signed TerrieHubble/' °.,.-'~~~ Title TechnicalAssistant Date~)°~"O/ MPI-04A 201-092 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. , .... INSTRUCTIONS (~ENERAL.' 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 BP EXPLORATION Pag'~i!:!':l of 6 Operations Summa Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: Date From'TO,HoUrs :ACtiVity Code NPT :Phase DescriPti°n°foperati°ns 6/29/2001 00:00 - 19:30 19.50 RIGU P PRE Move to MPU I - 4Aand rig up accept rig 1900 19:30 - 21:00 1.50 RIGU N PRE Wait on ring gasket 21:00 - 12:59 15.98 RIGU P PRE NU BOP 6/30/2001 00:00 - 10:30 10.50 STWHIP P WEXIT NU BOP change out rams 3-1/2 10:30 - 12:40 2.17 STWHIP P WEXIT slack management e-line coil 27' coil cut. 12:40 - 16:00 3.33 STWHIP P WEXIT Head up OXP, Pull test 20K, Change packoff and PT the connection. 16:00 - 19:30 3.50 S-I-WHIP P WEXIT :RIH tie in and cleanout to PBTD 4548.6 Hard spot at 4499. Pump sweeps make multiple passes thru tight spot to PBTD. 19:30 - 19:50 0.33 STVVHIP N WEXIT Repair counter on injector. 19:50 - 20:10 0.33 STVVHIP N WEXIT Log down 7" liner 20:10 - 22:30 2.33 STVVHIP N WEXIT POH 22:30 - 23:59 1.48 STWHIP N WEXIT RIH with dummy whipstock to PBTD. 7/1/2001 00:00 - 00:30 0.50 STWHIP P WEXIT LD dummy whipstock drift assembly 00:30 - 02:00 1.50 STWHIP P WEXIT PU whipstock 02:00 - 04:00 2.00 S'I'WHIP P WEXIT RIH tie in -5.5' tag PBTD. 04:00 - 04:10 0.17 STWHIP P WEXIT Close EDC and set whipstock 04:10 - 04:25 0.25 STWHIP P WEXIT Tag whipstock & Change well over to mud 04:25 - 05:35 1.17 STVVHIP P WEXlT POH 05:35 - 06:00 0.42 STVVHIP P WEXIT PU off well 06:00 - 06:30 0.50 STWHIP P WEXIT PJSM 06:30 - 07:30 1.00 STWHIP P WEXIT RIH 07:30 - 08:15 0.75 STWHIP P WEXIT tie in 08:15 - 14:00 5.75 STWHIP P WEXIT Mill window 4,536' to 4,542.5'Time drill WOB initially 500# increasing to 3000# at .05 fpm 14:00 - 14:55 0.92 STVVHIP P WEXlT POH mill in gauge. Window clean. 14:55 - 15:20 0.42 S'I'WHIP P PROD1 Change out milling assembly for build asSembly. 15:20 - 15:35 0.25 STWHIP P PROD1 Stab on to well and test tools. 15:35 - 16:48 1.22 STVVHIP P PROD1 RIH and tie in. correction -6'. 16:48 - 20:20 3.53 STWHIP P PROD1 Drill to 4690 end of build 20:20 - 21:20 1.00 S'I'WHIP P PROD1 POH for planned BHA change. 21:20 - 22:20 1.00 S'I'WHIP P PROD1 Change out BHA 22:20 - 22:48 0.47 STWHIP P PROD1 MU tools to injector and surface test OXP 22:48 - 23:59 1.18 STVVHIP P PROD1 RIH 7/2/2001 00:00 - 01:00 1.00 STWHIP P PROD1 RIH to 4440' tie in -4.5' 01:00 - 02:52 1.87 S'I'WHIP P PROD1 Drill to 4850 02:52 - 03:14 0.37 STWHIP P PROD1 Wiper trip 300' 03:14 - 05:25 2.18 STWHIP P PROD1 Drill to 5138 05:25 - 06:00 0.58 STWHIP P PROD1 wiper trip 590' 06:00 - 07:15 1.25 STWHIP P PROD1 Drill to 5350 07:15 - 08:05 0.83 STWHIP P PROD1 Wiper trip 800'. 08:05 - 09:45 1.67 STWHIP P PROD1 Drill to 5530 09:45 - 10:20 0.58 STWHIP P PROD1 Wipe trip 973'. 10:20 - 11:44 1.40 STWHIP N DFAL PROD1 POH for down hole short in EDC 11:44 - 14:00 2.27 STVVHIP N DF^L PROD1 Change out BHA 14:00 - 16:00 2.00 STWHIP N DF^L PROD1 RIH and drill to 5627 16:00 - 17:20 1.33 STWHIP N DPRB PROD1 Circulate and prep for open hole side track. Dip less than anticipated. 17:20 - 18:30 1.17 STVVHIP N DPRB PROD1 Close EDC and check computers 18:30 - 19:00 0.50 STVVHIP N DPRB PROD1 RIH and taking survey every 10' for 50' preparing for open hole sidetrack. 19:00 - 22:00 3.00 S'I'WHIP N DPRB PROD1 Build side tracking trough 4860 - 4890 three passes ,, Printed: 7/16/2001 1:41:32 PM BP EXPLORATION Page 2 of 6 Operations Summa Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: :Date:: From ~TO HourS ACtivityCOde NPT Phase DescriPtiOn of OperationS · ...... 7/2/2001 22:00- 23:59 1.98 STWHIP N DPRB PROD1 ' Directionally drill to 4908 71312001 00:00 - 01:30 1.50 STWHIP N DPRB PROD1 Directionally drill to 5093 01:30 - 01:44 0.23 STWHIP N DPRB PROD1 Wiper trip 550' 01:44 - 02:55 1.18 STWHIP!N DPRB PROD1 Log section for Gamma 02:55 - 04:00 1.08 STWHIPiN DPRB PROD1 .Directionally drill to 5300 BHP = 2892 psi, annular pressure 2280 psi, pump pressure 3450 psi @ 2.3 bpm ReP 214' ECD 10.9 04:00 - 04:30 0.50 STWHIP N DPRB PROD1 Wiper trip 750'. 04:30 - 06:12 1.70 STWHIP N DPRB PROD1 Directionaqlly drill to 5500 06:12 - 07:00 0.80 STWHIP N DPRB PROD1 Wiper trip 950'. 07:00 - 09:45 2.75 STWHIP N DPRB PROD1 Directionally drill to 5627 09:45 - 17:00 7.25 STWHIP P PROD1 Directionally drill 17:00 - 19:40 2.67 STWHIP P PROD1 Drill to 6270', wiper trip to shoe. 19:40 - 20:25 0.75 STWHIP P PROD1 6270', back on bottom, no problems seen on wiper. Drilling 2.3 'bpm in, 3460 psi CTP, 2.3 bpm out, ReP 230 fph. 20:25 - 21:45 1.33 STWHIP P i PROD1 6460', Wiper trip to shoe. 21:45 - 00:00 2.25 STWHIP P PROD1 Drill ahead, 2.5 in/2.5 out, 3700 CTP, 150 fph. 7/4/2001 00:00 - 01:30 1.50 STWHIP PROD1 6630', Wiper trip to shoe. 01:30 - 04:00 2.50 STWHIP PROD1 Resume drilling, wiper trip smooth. 04:00 - 05:50 1.83 STWHIP PROD1 6830', Drilling ReP slowed significantly. 800' on this mud system in last 12 hours. May need to swap mud again! Wipe to shoe. 105:50 - 06:30 0.67 STWHIP PROD1 Resume drilling 2.5 in, 2.5 out, 3400 psi CTP. Not getting good weight transfer. 06:30 - 11:30 5.00 STWHIP PROD1 6886'. Drilling difficult. Hard to get weight to bit. Also need to build 6' TVD to get back to good 20 ohm rock as per geo. Not worth doing a mud swap for 114 more feet of poor rock. Will Call this TD and begin conditioning hole. Make 2 wiper passes up to shoe, everything looks clean, but difficult to get down lask 200' of hole (Lockup/mud). PUH for tie in pass. 11:30 - 11:45 0.25 STWHIP PROD1 Log tie in pass in 7" liner. Make +2' correction. 11:45 - 13:10 1.42 STWHIP PROD1 Run back to bottom to confirm TD, and lay in new mud. 13:10 - 15:15 2.08 STWHIP PROD1 Tag bottom at 6888', consistent with the +2' correction we made at the shoe. Lay in new mud from TD. Using 9.0+ ppg mud with 6% lubtex. Other properties same as proceedure. While POOH, flagged pipe at 4000' and 1500', EOP. 15:15- 16:10 0.92 STWHIP PROD1 Lay down drilling BHA#7. 16:10 - 16:30 0.33 CASE COMP Standback injector prior to picking up liner. Note, had to set injector on CTU back deck using legs. Could not rig down CTC-UQC without having to rehead. (Several hours). Disassembled UQC partially in order to set on back deck. Need improved system in future if we are going to do this proceedure with wire. 16:30 - 17:00 0.50 CASE COMP Safety meeting prior to picking up liner. Rig crew, CTU crew, OXP, BP, Tool pusher. 17:00 - 17:15 0.25 CASE COMP Repair 2 items identified in safety meeting. 17:15 - 18:00 0.75 CASE COMP Begin picking up float eq. and pre perfed liner. Using 2-3/8" blank liner as safety joint. 18:00 - 18:25 0.42 CASE COMP Shut down operations for crew change out. 18:25 - 19:00 0.58 CASE COMP Hold PJSM with new crew. 1 new hand for DS, on his first liner job. Instructed new hand to observe, but not participate in activities. Printed: 7/16/2001 1:41:32 PM BP:EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: Date: From-To :HOURS ACtivity:COde NPT Phase;::: DesCription of OPerations :: ..... 7/4/2001 19:00 - 21:00 2.00 CASE COMP Continue with running 2-3/8" per perfed liner. 21:00 - 22:00 1.00 CASE COMP Finish running liner and deployment eq. Pickup 2-3/8" drill collar and crossovers to use as safety jt while running 3-1/8" drill collars. Deploy 12 3-1/8" drill collars, and 1 2-3/8" drill collar. 22:00 - 22:45 0.75 CASE COMP Make up OXP LQC, EDC, UQC. 22:45 - 23:40 0.92 CASE COMP Make up injecter. 23:40 - 23:55 0.25 CASE COMP RIH with liner. Made up as per proceedure. 23:55 - 00:00 0.08 CASE COMP Stop at 1500' EOP flag from previous tied in run, found 3.5' shallow. Add +3.5' correction. Continue RIH. 7/5/2001 00:00 - 00:40 0.67 CASE COMP Continue RIH with liner. Check up wt at shoe=28klbs. RIH in open hole. clean through window, clean through OH sidetrack at 4890', Started to loose weight while RIH. 10,000# RIH weight at shoe, 8500# at 5500', 8000# at 6000', 7000# at 6500'. Checked EOP flag at 4000', EOP which was 6708' with BHA, on within 2', continued RIH without slowing. Stacked out at 6730', up weight clean at 38klbs. Work to get moving again, finally got it down to 6834'. TD=6888', Top of liner at 4530.5', slightly shallow to whipstock top (about 1'). Intentionally left 54' of uncased hole below liner. 00:40 - 01:10 0.50 CASE COMP POH with liner deployment eq. 01:10 - 01:45 0.58 CASE COMP Tag up at surface, stand back injector, stand back drill collars. 01:45 - 02:30 0.75 CASE COMP Continue strapping CS hydrill. 02:30 - 03:00 0.50 CASE COMP Safety meeting prior to picking up CS hydrill. 03:00 - 07:45 4.75 CASE COMP Pick up 1" CS hydrill wash string with 1.5" OD bullnose JSN, to do bleach job on MPI-04A leg. 07:45 - 09:00 1.25 CASE COMP Make up OXP BHA, LQC, UQC. 09:00 - 10:45 1.75 CASE COMP RIH with CS hydrill BHA, no problems RIH through top of liner. Tag bottom at 6790', uncorrected CTM. Expected at 6795' ELM. Yesterday our flag correction was +3.5', so liner appears to be on depth within 1.5'. 10:45 - 16:44 5.98 CASE COMP Pumped 50 bbls of 3% KCL brine weighted to 9.2 ppg with NACL. displaced mud from liner. Followed with bleach mixture as per proceedure. 6 ppb lithium hypochlorite, at 160 degf and weighted to 9.4 ppg. Pumped 50 bbls, washed vac truck with 20 bbls and chased bleach with dilute mix. Followed with same 3% KCL brine pulled up above liner top and circulated at minimum rate. 16:44 - 18:00 1.27 CASE COMP RIH to displace bleach. 55 bbl spacer of KCL in coil, follow with Baroid drilling mud; BaradriI-N mud with 6% KCL and 31 ppb sized CaCO3, as per proceedure, weighted to 9.3 ppg. 18:00 - 20:00 2.00 CASE COMP POOH, laying in drilling mud in liner interval. Chase excess mud OOH with KCL. 20:00 - 20:45 0.75 CASE COMP Tag up at top of hydrill, stand back OXP eq, set injector down. 20:45 - 22:30 1.75 CASE COMP Standback 1" CS hydril work string. 22:30 - 23:30 1.00 STVVHIP WEXIT At surface, start rigging up Baker 7" whipstock and OXP tool to orient and set. 23:30 - 00:00 0.50 STWHIP WEXIT RIH with Baker 7" retrievable whipstock. 7/6/2001 00:00 - 01:20 1.33 STWHIP WEXIT Continue RIH with whipstock. 01:20 - 01:45 0.42 S'I'WHIP WEXIT Log tie in, make -2' correction at 4430'. 01:45 - 02:00 0.25 S'I'WHIP WEXIT RIH, tag up at 4526.5', pick up re position bottom of whipstock at 4522'. close EDC, pressure up coil. Expected whipstock to set at 2700 psi, got good indication of set at 3200 psi. Printed: 7/16/2001 1:41:32 PM BP EXPLORATION page4 of 6 Operations Summa Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: N^BORS Rig Release: Rig Name: NABORS 3S Rig Number: Date FrOm, TO HoUrs ACtiVity~Code NPT Phase DeScription of operations: , 7/6/2001 01:45 - 02:00 0.25 STVVHIP WEXIT Whipstock set with bottom at 4522', top at 4505'. PA, tag at 4515'. 02:00 - 02:20 0.33 STVVHIP WEXIT Open EDC circ sub, circ new flo pro into hole. 02:20 - 03:25 1.08 S'I'WHIP WEXIT POOH, laying in new flo pro mud. 03:25 - 04:15 0.83 S'I'WHIP WEXIT Tag up at surface with setting tool. Indicated whipstock set properly. MU milling BHA with straight motor, diamond mill and string reamer. 04:15 - 05:00 0.75 STWHIP WEXlT RIH with BHA #8 to mill window. 05:00 - 06:00 1.00 S'I'WHIP WEXlT Log tie in pass. 06:00 - 13:15 7.25 STWHIP WEXIT RIH, tag top of whipstock at 4506' (Set at 4505'). Solid tag. RIH to pinch point. Begin milling from 4510'. Mill to 4515', Drill open hole to 4521'. 13:15 - 14:00 0.75 S'I'WHIP WEXIT Ream/backream window. Make 3 passes through window, able to pull through dry 2 times. 14:00 - 14:45 0.75 STVVHIP WEXIT POOH with BHA #8 14:45 - 15:45 1.00 STWHIP WEXIT Lay down BHA #8. Mill and string reamer recovered in gauge, and mill had swirl pattern on face. 15:45 - 23:30 7.75 DRILL PROD1 Weekly BOP pressure test. 23:30 - 00:00 0.50 DRILL PROD1 MU BHA #9, to drill build section of L1 lateral. 7/7/2001 00:00 - 00:15 0.25 DRILL PROD1 Continue making up BHA #9 to drill lateral section L1. 00:15 - 00:45 0.50 DRILL PROD1 PU Injector. 00:45 - 01:45 1.00 DRILL PROD1 RIH with BH^ #9.2.5 deg mud motor, flex joint, M09 bit. (Same bit as used on A lateral section) 01:45 - 02:00 0.25 DRILL PROD1 Log tie in pass. 02:00 - 07:45 5.75 DRILL PROD1 Begin drilling build section. 2.0 bbls in/2.0 bbls out, 3400 psi CTP, drilling slow, hitting calcite stringers. Getting 41 deg build at window. Able to stay on plan. 07:45 - 08:50 1.08 DRILL PROD1 4841', Build section completed, POOH 08:50 - 09:50 1.00 DRILL PROD1 Tag up at surface with build section BHA #9. Change out for lateral section BHA. Use 1.2 deg motor, Resistivity tool, DS49 bit. (Same bit used on A lateral horizontal section.) 09:50 - 11:30 1.67 DRILL PROD1 RIH with BH^ #10. 11:30 - 12:10 0.67 DRILL PROD1 Log MAD pass over build section. 12:10 - 12:50 0.67 DRILL PROD1 4841', Back on bottom, drill directionally. 2.3 in, 2.3 out. 1 for 1 returns. 3200 psi, Drilling at 200 + fph with occasional calcite stringers. 12:50 - 13:05 0.25 DRILL PROD1 4900', Short trip. 13:05 - 14:00 0.92 DRILL PROD1 Return to drilling. 14:00 - 14:45 0.75 DRILL PROD1 Drill - Simulated high level H2S release in the celler. Rig evacuation. Drill complicated by having brown bear near muster area. Debrief drill. Drill completed satisfactorily. 14:45 - 15:00 0.25 DRILL PROD1 Wiper trip to shoe. 15:00 - 16:20 1.33 DRILL PROD1 5070', Resume drilling. 2 bpm in, 2 bpm out. 3000 psi, 261 fph ROP. 16:20 - 17:00 0.67 DRILL PROD1 5220', Sticky pickup off bottom, net getting good weight to bit. Wiper trip to shoe. 17:00 - 17:45 0.75 DRILL PROD1 Resume drilling, 2.2 in/out, no losses. 3100 psi, 231 fph ROP. 17:45 - 18:20 0.58 DRILL PROD1 5380', Wiper trip to window. 18:20 - 20:45 2.42 DRILL PROD1 Resume drilling. 20:45 - 21:30 0.75 DRILL PROD1 5600', wiper trip to window. 21:30 - 23:00 1.50 DRILL PROD1 Resume drilling, swapping to new mud. 23:00 - 23:40 0.67 DRILL PROD1 5821', wiper trip to window. 23:40 - 00:00 0.33 DRILL PROD1 Resume drilling. Midnight nepth=5930'. Printed: 7/16/2001 1:41:32 PM BP EXPLORATION Page 5 of 6 Operations SUmma Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 1'1/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 3S Rig Number: Date .From,TO uoUrs~ ActiVityCode NPT PhaSe Description of OperationS 7/8/2001 00:00 - 00:35 0.58 DRILL P PROD1 Drilling ahead at 5930'. 00:35 - 01:25 0.83 DRILL P PROD1 6050', wiper trip to shoe. 01:25 - 03:00 1.58 DRILL P PROD1 Resume drilling. 03:00 - 04:10 1.17 DRILL P PROD1 6280'. Wiper trip to shoe. 04:10 - 06:00 1.83 DRILL P PROD1 Resume drilling. 06:00 - 07:00 1.00 DRILL ~ PROD1 6479', Wiper trip to shoe. 07:00 - 07:30 0.50 DRILL N RREP PROD1 Rig pumps down, Dowell tracter out of fuel, so can't pump. Standby at shoe for repairs. 07:30 - 08:20 0.83 DRILL N FLUD PROD1 RIH, mud getting bad, can't make it back to bottom. Can only make it to 6350'. Call for new mud. 08:20 - 12:00 3.67 DRILL N FLUD PROD1 3OH to shoe to wait for mud. 12:00 - 12:50 0.83 DRILL N FLUD PROD1 RIH to spot new mud, and resume drilling. 12:50 - 14:30 1.67 DRILL 3 PROD1 6480', tag bottom and resume drilling. 2.3 in, 2.3 out, 3600 psi, 335 fph ROP. 14:30 - 16:10 1.67 DRILL 3 PROD1 6700', Short trip to shoe. 16:10 - 18:00 1.83 DRILL 3 PROD1 Resume drilling, 2.3 in, 2.3 out, 3600 psi, 290 fph. 18:00 - 19:10 1.17 DRILL 3 PROD1 6897', Wiper trip to shoe. 19:10 - 21:25 2.25 DRILL 3 PROD1 Resume drilling, snubbing at surface in order to get weight to !bit. Drilling with -14000 lbs at surface.2.3 in/out, 3700 psi. 21:10-21:30 0.33 DRILL P PROD1 7054', Short wiper trip. 21:30 - 22:30 1.00 DRILL P PROD1 Resume drilling. Midnight depth=7100' 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to shoe. 7/9/2001 00:00 - 00:45 0.75 DRILL P PROD1 Continue wiper trip to shoe. 00:45 - 02:00 1.25 DRILL P PROD1 Resume drilling, hitting occasional hard streaks, ROP slowing due to weight transfer. Drill to 7200', TD well. 02:00- 02:45 0.75 DRILL 'N DFAL PROD1 Start conditioning trips to window. During first wiper trip bit plugged off. 02:45 - 04:00 1.25 DRILL N DF^L PROD1 Open Electronic circ sub, POOH to inspect. 04:00 - 06:45 2.75 DRILL N DFAL PROD1 Change out motor. Found plugged bit, and shucked stator in motor. Rig back on well. EDC put in a bind during RU process. (Poor comunication to hand running injector) Changed out EDC. Continued RD. No apparent damage to EDC after it was removed from BHA. 06:45 - 08:30 1.75 DRILL N DFAL PROD1 RIH with DH^ #11. 08:30 - 09:00 0.50 DRILL P PROD1 At casing shoe, resume wiper trips to condition hole. Saw a ledge at each hard stringer. Probably gauge hole at the calcite stringers, with washed out sands above and below. Will try to knock off the corners w/o washing out the sands any more. 09:00 - 10:30 1.50 DRILL P PROD1 Wiper trip from TD to shoe. Make tie in pass. 10:30 - 11:00 0.50 DRILL P PROD1 At window. Park coil, SI pumping, Hold safety stand down to discuss incident on rig with EDC. Potential for harm to personnel or equipment was a real possibility. Discussed with crews that since they change out tommorrow and the next day, they need to keep their eye on the ball for the next couple of days. 11:00 - 14:15 3.25 DRILL P PROD1 Run back in hole to condition for liner. Hole looked good to bottom, swap to new mud with 6% lubtex. Final on depth tag, TD=7207'. Spot new mud on bottom and lay in. 14:15 - 15:15 1.00 DRILL P PROD1 At liner. No problems on last trip up. Tie in again. Log TTail and packer. 15:15 - 16:30 1.25 DRILL P PROD1 POOH, flag at EOP 4000, 1400. 16:30 - 17:45 1.25 DRILL P PROD1 Tag up with BHA #11, Lay down motor and MWD. Stand back injector. =, Printed: 7/16/2001 1:41:32 PM BP EXPLORATION page 6 of 6 Operations Summa Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: '11/15/1990 Event Name: REENTER+COMPLETE Start: 6/30/2001 End: Contractor Name: N^BORS Rig Release: Rig Name: N^BORS 3S Rig Number: Date: From,:TO: Hours Activity COde NPT :phase: : Description of operations'':: , 7/9/2001 17:45 - 18:15 0.50 DRILL P PROD1 Standby for crews tour change out. 18:15 - 18:45 0.50 DRILL P : PROD1 Safety meeting prior to picking up liner. 18:45 - 19:05 0.33 DRILL P . PROD1 Make up 2-3/8" STL safety joint. 19:05 - 00:00 4.92 DRILL P PROD1 Make up 2-3/8" pre perforated liner as per proceedure. 7/10/2001 00:00 - 00:40 0.67 DRILL P PROD1 Continue picking up 2-3/8" liner. 00:40 - 01:30 0.83 DRILL P PROD1 Set final 2-3\8 drill collar in 2-3/8" combi pipe slip rams. Close both sets of rams. PU injector, and MU OXP tool. 01:30 - 02:25 0.92 DRILL P PROD1 RIH with liner assembly. Weight check at shoe = 28klbs. Stop at flag at 1400' EOP. Found at 4640', shoud be at 4638.5', make -1.5' correction. Continue RIH depth vs wt; 4500'=10000#, 5000'=8000#, 5500'=6000#, 6000'=4000#, 6500'=0-2000", 7000'=0-2000#. Stop @ 7183.5', shut EDC, pump to release GS deployment tool. PU at 26klbs. Liner deployed ok, as per proceedure. (8' deeper than plan, but still above window, and below TTail) 02:25 - 03:15 0.83 DRILL P PROD1 Pull out of hole with coil. 03:15 - 07:00 3.75 DRILL P PROD1 Tag up at surface, set back injector, lay down drill collars and OXP. 07:00 - 10:20 3.33 DRILL P PROD1 Pick up CS hydril work string to bleach slotted liner. 10:20 - 11:00 0.67 DRILL P PROD1 Pick up injector and OXP to bleach slotted liner. 11:00 - 11:40 0.67 DRILL P PROD1 RIH with coil to bleach liner. 11:40 - 13:00 1.33 DRILL P PROD1 Tag TD, spot 50 bbls bleach accross slotted liner interval while PUH. Chase with 20 bbls of brine rinse out of bleach vac truck. 13:00 - 17:00 4.00 DRILL P PROD1 Circulate above liner top while waiting for bleach to work. 17:00 - 19:00 2.00 DRILL P PROD1 Displace bleach in liner with brine while POOH. 19:00 - 19:30 0.50 DRILL P PROD1 Safety meeting 19:30 - 00:00 4.50 DRILL P PROD1 Standback injector. Hole staying full. LD CSH in singles. 7/11/2001 00:00 - 01:30 1.50 DRILL P PROD1 Set BPV. 01:30 - 04:30 3.00 DRILL P PROD1 ND DOPE. NU tree cap. Release rig 04:30 hrs 7/11/01. Printed: 7/16/2001 1:41:32 PM BP EXPLORATION page 1 of 1 Operations ,Summary Report Legal Well Name: MPI-04 Common Well Name: MPI-04 Spud Date: 11/15/1990 Event Name: COMPLETION Start: 7/17/2001 End: 7/19/2001 Contractor Name: NABORS Rig Release: 7/19/2001 Rig Name: NABORS 4ES Rig Number: Date From:-m° HoUrS ActiVity Code~ NPT :Phase. · DescriPtion of OperationS: 7/17/2001 03:00 - 08:00 5.00 MOB P PRE RDMO FROM MPC-41. 08:00 - 12:00 4.00 MOB P PRE RIGGED UP 100%, RIG ACCEPTED AT 1200 NOON 12:00 - 00:00 12.00 KILL P DECOMP BULL HEAD ANNULUS WITH 100 BBL 10.4 PPG BRINE, PUMP AT 2 BPM AT 750 PSI SHUT DOWN PUMP PRESSURE DROPPED TO 300 PSI, BLED BACK 30 BBL 10.4 PPG BRINE. BULL HEAD 100 BBL 10.9 PPG BRINE DOWN ANNULUS AT 700 PSI SHUT IN FOR 15 MIN AT 0000 HOURS MONITER WELL 7/18/2001 00:00 - 03:30 3.50 KILL P DECOMP BLED OFF & MONITORED ANNULUS. PRESS. BUILT TO 40 PSI IN 15 MIN. VVT. UP FROM 10.9 TO 11.3 PPG. BULLHEAD 100 BBLS. 11.3 PPG DN ANNULUS 4 1/2 BPM @ 950 PSI. 03:30 - 04:30 1.00 KILL P DECOMP PRESS.WENT TO 0 PSI IN 30 MIN. MONITOR WELL. 04:30 - 06:00 1.50 KILL P DECOMP ANNULIS DEAD. BULLHEAD W/60 BBLS.11.0 PPG DN TBG 4 1/2 BPM @ 750 PSI. MONITOR WELL. WELL DEAD. 06:00 - 07:00 1.00 WHSUR P DECOMP ND TREE. 07:00 - 09:00 2.00 BOPSUR P DECOMP NU BOPE. 09:00 - 12:00 3.00 BOPSUR P DECOMP PT BOPE. LP 250 PSI. HP 2500 PSI. ANNULAR TEST 1500 PSI. TEST OK. WITNESSING WAIVED BY CHUCK SHEVE AOGCC. 12:00 - 13:00 1.00 BOPSUR P DECOMP PULLTWC. 13:00 - 14:30 1.50 PULL P DECOMP UNLAND TBG. HANGER. OVERPULL 34K. PUMPED 40 BBLS. 11.0 PPG DN TBG. MONITOR WELL 30 MINS. 14:30 - 20:00 5.50 PULL P DECOMP PULL & LD 4 1/2 TBG. & AND SEAL ASSM. 20:00 - 00:00 4.00 REST P DECOMP MADE UP SEAL ASSM. SCREENS & VTL PACKER. RIH P/U 2 7/8 TBG. 7/19/2001 00:00 - 01:00 1.00 RUNCOItP COMP COMPLETE RIH W/HALCO VTL PACKER, SCREENS & SEAL ASSM. 01:00 - 03:00 2.00 RUNCOr P COMP STING INTO BAKER PACKER. SPACE' OUT. FILL TBG. DROP BALL. SET VTL PACKER @ 4337'. TEST ANNULUS 1000 PSI. TESTED GOOD. 03:00 - 05:00 2.00 RUNCOr F' COMP STING OUT OF VTL PACKER. POOH. 05:00 - 09:00 4.00 RUNCO~ P COMP OOH. CLEAR FLOOR. PJU TO RUN ESP. PULL CABLE AND SECURE TO ESP. 09:00 - 11:30 2.50 RUNCO~ I~ COMP RIH W/2 7/8 TBG. & ESP. TEST ESP @ 2000' TESTED OK. 11:30 - 14:00 2.50 RUNCO~ P COMP SPACE OUT. SPLICE EFT CONNECTOR. TESTED OK. 14:00 - 15:00 1.00 RUNCO~ COMP PU WT. 38 K. SO WT.32K. LAND HANGER. RILDS. INSTALL AND TEST TWC. 15:00 - 16:30 1.50~ BOPSUF:P COMP ND BOPE. 16:30 - 18:00 1.50 WHSUR P COMP ~NU TREE. TEST HANGER AND TREE TO 5000 PSI. TESTED GOOD. 18:00 - 19:00 1.00 WHSUR P COMP RU LUBRICATOR. PULL 'RNC. SET BPV. RELEASE RIG. Printed: 7/23/2001 11:09:09AM Obp BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Maine Point Slie: M Pt I Pad Well: MPI-04 Wellpath: MPI-O4APB1 hie: 8/1/2001 Time: 16:07:48 Page: 1 Ce-elnllaate(NE) Reference: Well: MPI-04, True Norl~ Vertical (TVD) Reference: MPI-04 70.0 Section (VS) Reference: Well (0.00N,0.00E,28.42Azi) Snrvey Caicnlation Metked: Minimum Curvature Db: Oracle Field: Maine Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ga) Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008388.01 ft Latitude: 70 26 1.282 N 550245.83 ft Longitude: 149 35 25.422 W North Reference: True Grid Convergence: 0.39 deg Well: MPI-04 Slot Name: 04 MPI-04 Well Posltion: +N/-S 1056.45 ft Northing: 6009452.79 ft Latitude: 70 26 11.670 N +E/-W 1255.97 ft Easting: 551494.53 ff Longitude: 149 34 48.561 W Position Uncertainty: 0.00 ft Weilpath: MPI-04APB1 Drilled From: MPI-04 500292206871 Tie-on Depth: 4529.00 ft Current Datum: MPI-04 Height 70.00 ff Above System Datum: Mean Sea Level Magnetic Data: 8/1/2001 Declination: 26.19 deg Field Strength: 57456 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 28.42 Survey: MWD Start Date: 7/2/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 'MD '' TVD '" : .... " ' ' ' ' 4520.00 3992.3? KOP 5627.00 4085.06 TD Survey :!" :Ml) ':Azlm ' =TVD,:: SST¥~ ~ ,, N/S: :' MapN : MnPE" ' DLS': VS ',deg" ; 'fi,::'::' ':':fi:i:': ,It',:::,,::; It , : deg/!OOff ft' :' 4529.00 25.17 51.56 3992.37 3922.37 1516.04 1153.52 6010976.61 552637.45 0.00 1882.35 4560.00 32.20 51.70 4019.54 3949.54 1525.26 1165.18 6010985.92 552649.04 22.68 1896.01 4590.00 43.80 47.40 4043.15 3973.15 1537.29 1179.15 6010998.04 552662.92 39.64 1913.23 4820.00 54.40 40.60 4062.78 3992.78 1553.63 1194.78 6011014.49 552678.44 39.23 1935.05 4650.00 65.80 34.10 4077.72 4007.72 1574.31 1210.45 6011035.27 552693.97 42.36 1960.69 4680.00 75.30 25.40 4087.71 4017.71 1598.64 1224.40 6011059.90 552707.75 41.81 1988.91 4723.00 77.90 31.50 4097.69 4027.69 1635.59 1244.33 6011096.78 552727.42 15.06 2030.71 4753.00 81.90 28.40 ' 4102.95 4032.95 1661.18 1259.07 6011122.46 552741.98 16.77 2060.23 4780.00 85.70 30.20 4105.86 4035.86 1684.58 1272.20 6011145.95 552754.95 15.56 2087.06 4810.00 90.40 28.80 4106.88 ,. 4036.88 1710.67 1286.96 6011172.14 552769.52 16.35 2117.03 4640.00 93.30 26.00 4105.91 4035.91 1737.28 1300.76 6011198.85 552783.14 13.43 2147.00 4870.00 93.90 23.20 4104.03 4034.03 1764.50 1313.22 6011226,15 552795.41 9.53 2176.87 4921.00 90.50 18.10 4102.07 4032.07 1812.17 1331.18 6011273.93 552813.04. 12.01 2227.34 4957.00 89.70 12.60 4102.01 4032.01 1646.87 1340.71 6011308.70 552822.32 15.44 2262.40 4990.00 90.00 8.20 4102.10 4032.10 1879.32 1346.66 6011341.18 552828.06 13.36 2293.77 5021.00 88.80 5.80 4102.42 4032.42 1910.09 1350.44 6011371.97 552831.62 8.66 2322.62 5052.00 88.20 2.10 4103.23 4033.23 1941.00 1352.57 6011402.89 552833.54 12.09 2350.82 5088.00 88.40 357.20 4104.30 4034.30 1976.97 1352.35 6011438.86 552833.07 13.62 2382.35 BP Amoco Baker Hughes INTEQ Survey Report I.NTEQ Company: BP Amoco Date: 8/1/2001 Time: 16:07:48 Page: 2 FieM: Milne Point Co-ordinate(NE) Reference: Well: MPI-04, True North Site: M Pt I Pad Vertical (TVD) Reference: MPI-04 70.0 WeB: MPI-04 Section (~S) Reference: Well (0.00N,0.00E,28.42Azi) Wellpa~: MPI-04APB1 Snmrey Calenlatlon Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD SSTVD N/S F_JW MapN MapE DLS VS ff deg deg ff ff ff ff ff ff deg/100ft ff 5117.00 88.00 355.80 4105.21 4035.21 2005.90 1350.58 6011467.77 552831.10 5.02 2406.96 5152.00 88.00 352.30 4106.43 4036.43 2040.68 1346.96 6011502.53 552827.24 9.99 2435.82 5181.00 88.70 348.70 4107.27 4037.27 2069.27 1342.18 6011531.08 552822.26 12.64 2458.68 5214.00 89.50 345.80 4107.79 4037.79 2101.45 1334.89 6011563.20 552814.76 9.12 2483.52 5250.00 88.50 341.10 4108.42 4038.42 2135.94 1324.64 6011597.62 552804.27 13.35 2508.97 5290.00 87.90 346.40 4109.67 4039.67 2174.31 1313.46 6011635.91 552792.82 13.33 2537.39 5325.00 89.20 351.90 4110.56 4040.56 2208.66 1306.88 6011670.21 552786.00 16.14 2564.47 5363.00 90.20 356.70 4110.76 4040,76 2246.46 1303.10 6011707.98 552781.97 12.90 2595.92 5402.00 91.60 1.80 4110.15 4040,15 2285.44 1302.59 6011746.95 552781.19 13,56 2629.95 5430.00 93.10 4.80 4109.00 4039.00 2313.36 1304.20 6011774.88 552782,61 11.97 2655.28 5461.00 93.70 8,30 4107.16 4037.16 2344.10 1307,73 6011805.64 552785.92 11.44 2683.99 5493.00 94.10 13.30 4104.98 4034.98 2375.45 1313.71 6011837.03 552791,68 15.64 2714.41 5524.00 94.30 16.40 4102.71 4032.71 2405.33 1321.63 6011866.98 552799.40 9.99 2744.46 5555.00 97.60 16.90 4099.50 4029.50 2434.87 1330.47 6011896.55 552808.03 10.77 2774.64 5580.00 102.40 19.90 4095.15 4025.15 2458.22 1338.23 6011919.98 552815.63 22.54 2798.87 5627.00 102.40 19.90 4085,06 4015.06 2501.39 1353.86 6011963.22 552830.95 0.00 2844.27 REFERENCE INFORMATION 3450 3500 3550 3600 ~3750 1~3800 '~3850 '¢~3900 ~3950 4000 4050 2700 2400 5OO 6O0 7OO 800 ¢00 1000 1100 1200 130( 140[ 1500 160( 1708 1800 1900 200O 2100 220O 2300 2400 2500 2600 2700 2800 2900 3000 3100 4200 ] : : : ]850 1900 1950 2000 2050 2100 2150 220 225O 2300 2350 240O 2450 250O 2550 2600 2850 27O0 2750 280O 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 350O 3550 3680 365B 3700 3750 3800 Vertical Section at ~1/2001 4:14 PM BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco FIeM: Milne Point Site: M Pti Pad Well: MPI-04 Wellpath: MPI-04A Date: 8/1/2001 Time: 16:09:39 Page: l Co~rdhtate(NE) Reference: Well: MPI-04, True North Vertical (TVD) Reference: MPI-04 70.0 ~¢tion (VS) Reference: Well (0.00N,0.00E,40.00Azi) Snrvey Calenlatlen Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ga) Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008388.01 ft 550245.83 ft Latitude: 70 26 1.282 N Longitude: 149 35 25.422 W North Reference: True Grid Convergence: 0.39 deg Well: M PI-04 Slot Name: 04 MPI-04 Well Position: +N/-S 1056.45 ft Northing: 6009452.79 ft Latitude: 70 26 11.670 N +EI-W 1255.97 ff Easting: 551494.53 ff Longitude: 149 34 48.561 W Position Uncertainty: 0.00 ft Welipath: MPI-04A Drilled From: MPI-04APB1 500292206801 Tie-on Depth: 4840.00 ft Current Datum: MPI-04 Height 70.00 ff Above System Datum: Mean Sea Level Magnetic Data: 6/5/2001 Declination: 26~24 deg Field Strength: 57454 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +NI-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 40.00 Survey: MWD Start Date: 7/412001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation , , MD TVD , 4840.00 4105.91 KOP 6888,00 4124.81 TD Survey ''MD, ' Incl',' Azim , TVD SSTVD 'N/S , ,E]W' MapN ,MapE DLS VS" ff' deg ~: deg. ff ' 'ff "... ft.: :ff ff degll00ff ft 4840.00 93.30 26.00 4105.91 4035.91 1737.28 1300.76 6011198.85 552783.14 0.00 2166.95 4880.00 90.60 26.90 4104,55 4034.55 1773.07 1318,56 6011234.75 552800,69 7.11 2205.81 4911.00 88.10 31.70 4104.91 4034.91 1800.09 1333.72 6011261,68 552815,67 17.46 2236.25 4940.00 92.10 28.40 4104.85 4034.85 1825.19 1348.24 6011287.07 552830,01 17,88 2264.81 4971.00 93.50 25,00 4103.34 4033.34 1852.84 1362.15 6011314,82 552843.73 11.85 2294.93 5006.00 93.40 18.20 4101.23 4031,23 1885.31 1375.01 6011347.36 552856.35 19.40 2328.07 5040.00 92.30 12,60 4099.54 4029.54 1918.03 1384.02 6011380.15 552865.14 16.77 2358.93 5070.00 92.60 9.40 4098.26 4028.26 1947.45 1389,74 6011409.60 552870.66 10.70 2385.14 5102.00 91.70 4.00 4097.06 4027.06 1979.20 1393.47 6011441.37 552874.16 17.10 2411.86 5131.00 89.60 0.00 4096.73 4026.73 2008.17 1394.48 6011470.35 552874.98 15,58 2434.70 5170.00 89.60 355.70 4097.00 4027.00 2047.13 1393.01 6011509.30 552873.24 11,03 2463.61 5205,00 90.10 350.40 4097.09 4027,09 2081.86 1388.78 6011543.99 552868.77 15.21 2487,49 5244.00 90.80 343,40 4096,78 4026.78 2119.82 1379.95 6011581.89 552859.68 18.04 2510.89 5275.00 91.80 338.80 4096.08 4026.08 2149.14 1369.91 6011611.13 552849.44 15.18 2526.90 5305.00 90.10 334.90 4095.58 4025.58 2176.71 1358.12 6011638.62 552837.46 14.18 2540.44 , , 5335.00 88.20 332.00 4096.03 4026.03 2203,54 1344.72 6011665.35 552823.87 11.56 2552.38 5365,00 88.70 334.40 4096.84 4026.84 2230.31 1331.20 6011692.02 552810.17 8.17 2564.19 5395.00 91.00 337.90 4096,92 4026,92 2257.74 1319.07 6011719.36 552797.85 13.96 2577.41 BP Amoco BAg[II. HUGMES Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 8/1/2001 Time: 16:09:39 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPI-04, True North Site: M Pt I Pad Vertical (TVD) Reference: MPI-04 70.0 Well: MPI-04 Section (VS) Reference: Well (0.00N,0.00E,40.00Azi) Weilpath: MPI-04A Survey Calculation Method: Minimum Curvature Dh: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ft deg des ft ft ft ft ft ft deg/100ft ft 5427.00 91.30 342.10 4096.27 4026.27 2287.79 1308.13 6011749.34 552786.71 13.16 5455.00 90.90 347.00 4095,74 4025.74 2314.77 1300.67 6011776.26 552779.07 17.55 5491.00 90,30 351.80 4095.36 4025.36 2350.14 1294.05 6011811.59 552772.20 13.44 5521.00 90.80 355.10 4095.07 4025.07 2379.94 1290.63 6011841.36 552768.58 11.13 5551.00 92.60 1.20 4094.18 4024.18 2409.90 1289.66 6011871.30 552767,40 21.19 5582.00 91.40 6.10 4093.10 4023.10 2440.81 1291.64 6011902.22 552769.16 16.26 5611.00 89.40 9.60 4092.90 4022.90 2469.53 1295.60 6011930.97 552772.92 13.90 5646.00 90.40 16.80 4092,96 4022.96 2503.58 1303,58 6011965.07 552780.67 20.77 5682.00 89.70 20.20 4092.93 4022.93 2537.71 1315,00 6011999.28 552791.86 9.64 5711.00 89.30 25.80 4093,18 4023.18 2564.40 1326,33 6012026.04 552803.00 19.36 5742.00 88.30 31.00 4093.83 4023.83 2591.65 1341.07 6012053.39 552817,54 17.08 5774.00 89,80 33.90 4094.36 4024.36 2618.65 1358.23 6012080.50 552834.52 10.20 2593.40 2609,27 2632.12 2652.74 2675.07 2700.01 2724.56 2755.78 2789.27 2816.99 2847.34 2879.05 5803.00 88,30 38.70 4094.84 4024.84 2642.01 1375.39 6012103.98 552851.52 17.34 5834.00 89,00 44.40 4095.57 4025.57 2665,19 1395,94 6012127.30 552871.90 18.52 5865.00 90.00 47.60 4095.84 4025.84 2686.72 1418.23 6012148.98 552894.04 10.81 5902.00 91.30 51.90 4095.42 4025.42 2710.62 1446,46 6012173.07 552922.11 12.14 5936.00 91.50 58.10 4094,59 4024.59 2730.11 1474,29 6012192.75 552949.80 18.24 5971.00 91.50 62.00 4093.67 4023.67 2747.57 1504,60 6012210.42 552979.98 11.14 6000.00 91.60 68.00 4092.89 4022.89 2759.82 1530,86 6012222.84 553006,16 20.68 6039.00 90.00 73.50 4092.34 4022.34 2772,67 1567,67 6012235.95 553042.86 14.69 6076.00 89.10 78.30 4092,63 4022.63 2781,68 1603,54 6012245.21 553078.67 13.20 6110.00 88.90 83.20 4093.23 4023.23 2787.14 1637,08 6012250.90 553112.17 14.42 6146.00 88.70 87.70 4093.98 4023.98 2790.00 1672.95 6012254.00 553148.02 12.51 6180.00 87.00 83,40 4095.26 4025.26 2792,63 1706,82 6012256.87 553181,86 13.59 6213,00 87.00 76.10 4096.99 4026,99 2798.49 1739,22 6012262.95 553214.22 22,09 6242.00 87.30 71.50 4098.43 4028.43 2806.57 1767.03 6012271.22 553241.97 15.88 6274.00 88.00 67.40 4099.74 4029.74 2817.79 1796,96 6012282.65 553271.82 12.99 6304.00 87.70 61.80 4100.87 4030.87 2830.64 1824.03 6012295,69 553298.80 18.68 6334.00 88.40 56.60 4101.89 4031.89 2845.99 1849.78 6012311.21 553324.43 17.48 6364.00 89.50 59,00 4102.44 4032.44 2861,97 1875.15 6012327.37 553349,70 8.80 6395.00 88.60 63.20 4102.96 4032,96 2876.95 1902.28 6012342.53 553376,72 13,85 6425,00 87.30 67.80 4104.03 4034.03 2889.38 1929,56 6012355.14 553403.91 15.92 6455.00 87.70 71.30 4105.34 4035.34 2899.85 1957.64 6012365.81 553431.91 11.73 6485.00 87,10 78.40 4106.70 4036.70 2907.68 1986.54 6012373,83 553460,76 23.73 6515.00 85.50 81,30 4108,64 4038.64 2912,95 2016.01 6012379.31 553490.19 11.02 6548.00 86.30 86.50 4111.00 4041,00 2916.45 2048,73 6012383.03 553522.87 15,90 6575.00 89.10 90.70 4112.08 4042.08 2917.11 2075.69 6012383.88 553549.83 18.68 2907.98 2938,95 2969.77 3006.23 3039.04 3071.90 3098.16 3131.66 3161.62 3187.37 3212.61 3236.40 3261.72 3285,78 3313.62 3340.86 3369.17 3397.73 3426.64 3453,69 3479.76 3504.34 3527.32 3551,03 3568.86 6606.00 87,70 95.90 4112.95 4042.95 2915.32 2106.61 6012382.31 553580.76 17.36 6636.00 86,70 101.20 4114.41 4044.41 2910.87 2136,23 6012378.06 553610.41 17.96 6672.00 85.70 106.90 4116.80 4046.80 2902.16 2171,06 6012369.59 553645.30 16.04 6703.00 85.70 111,80 4119,13 4049.13 2891,92 2200,22 6012359.55 553674.52 15.76 6749.00 86.10 119.40 4122.42 4052.42 2872.11 2241.57 6012340.03 553716.00 16.50 6785,00 87.90 123.80 4124.31 4054.31 2853.27 2272.18 6012321.41 553746.74 13.19 6817.00 88.60 128.40 4125.28 4055.28 2834.43 2298.02 6012302.75 553772.70 14.53 6849.00 90.90 131.30 4125.42 4055.42 2813,93 2322.58 6012282.42 553797.40 11.57 6888.00 90.90 131.30 4124.81 4054.81 2788.19 2351.87 6012256.89 553826.87 0.00 3587.37 3603.00 3618,71 3629.61 3641,01 3646.26 3648,44 3648,52 3647.64 REFERENCE INFORMATION C~ocdlnate (N/E) Relelence: Well Centre: MPI-04, True Nodh Vedical ~rVD) Reference: Syslem: Mean Sea Level SecUon (VS) Reference Slot 04 (0 00N,0 00E) Measured De0~h Reference: MPi-04 ?0 00 Calculalion Method M~nlmum Curvalure 3450 3500 3550 3600 4050 4150 ?25O0 ~2300 42oo j I Vertical Section at 40.00° [5Oft/in] 8/1/2001 4:14 PM 500 600 700 §00 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 230O 2400 2500 2600 27O0 2600 2900 3000 3100 il ALASKA OIL AND GAS CONSERVArI~ION CO~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27~7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPI,04A BP Exploration (Alaska) Inc. Permit No: 201-092 Sur Loc: 2942' SNL, 3876' WEL, See. 3'3, T13N, R10E, UM Btmhole Loc. 83' SNL, 1653' WEL, Sec. 33, T13N, R10E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. . Daniel T. Seamount, Jr. Commissioner BY ORDER OF TH._~E COMMISSION DATED this ~ / ST/day of May, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Ot" STATE OF ALASKA S(b ALASKA LAND GAS CONSERVATION COMMI ,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of work B Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 70' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025906 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2942' SNL, 3876' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 1464' SNL, 2769' WEL, SEC. 33, T13N, R10E, UM MPI-04A Number 2S100302630-277 At total depth 9. Approximate spud date 83' SNL, 1653' WEL, SEC. 33, T13N, R10E, UM 05/29/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 114. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025517, 3625' MDI No Close Approach 2560 6696' MD / 4070' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 4546' MD Maximum Hole Angle 91 ° Maximum surface 1400 psig, At total depth (TVD) 3860' / 1775 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplinq Len,qth MD TVD MD TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2176' 4520' 3914 6696' 4070' Uncemented Slotted Liner 19. To be oompleted for Redrill, Re-entry, and Deepen Operations. Present well oondition summary Total depth: measured 4900 feet Plugs (measured) MAY Z 6 Z 0 01 true vertical 4329 feet Effective depth: measured 4795 feet Junk (measured) Alaska Oil & Gas Cons. Commission true vertical 4234 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 80' 13-3/8" 485 sx Permafrost 'C' 115' 115' Surface 2564' 9-5/8" 1111 sx Permafrost 'E', 244 sx 'G' 2599' 2354' Intermediate Production 4846' 7" 260 sx Class 'G' 4881' 4312'. Liner Perforation depth: measured 4383' - 4392', 4411' - 4428', 4443' - 4451', 4554' - 4588', 4624' - 4655' true vertical 3860' - 3868', 3886' - 3901', 3915' - 3922', 4015' - 4046', 4078' - 4107' '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie HuDDle, 564-4628 21. I hereby certify that the f. oreaoing is true a~d ~orrect to the best of my knowledge _ Signed Mark Johnson ~ ~.. ~e CT Drilling Engineer Date i: :!!:; i:. ',!':; i?:;i;... :':". :".'": ":. ?.:,.':.:?:~!.:i:";;"..:.'.',.::'!;.'.::.!:':.,), ;:~:.:';';.:,.:, :::'!.:','.::::::..//i"':::::?/:!.;::~ :::...::~,.'::'~} ~:;i::~,:~ ~iS~ii~i~!':.::U,'~e;!Oi!!;y"'!!:, ,i:.,..~, .'::? :',:'': ;~'!; :'::,'i:.,.::::' ..'!.!' ."::,.:' .:',:: :,':,.::! ;"' ':;'.::,::'?.':..;',.ii':'.....,i;;::': .;:!':.:: ::':" Permit Nu~mber"_ ' ' I Nun r ............... I ' APProval' D~aie~' "j' S~e' Co~/er"iett~r "' ' """ / , o 150- 029-22068-01 J F;j'. ~ J. 0 ~ J for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,,~L3.5K psi for CTU Other: ORIGINAL SIGNED b; ,' D Taylor Seamou~-,, by order of _Approved By f'~ r"~ I ~"~ 1~ ~, I A I Commissioner the commission Date I Form 10-401 Rev. 12-01-85 Submit In Triplicate Summary of Operations: BPX Milne Point MPI-04A & L1 Sidetracks - Coiled Tubing Drilling MPI-04 will be sidetracked with two horizontal wellbores (MPI-04A and L_~ to target Schrader Bluff OB and OA reserves respectively. Coiled Tubing Drilling (CTD) will perform the sidetracks. Prior to CTD arrival, Nabors 4ES will pull the existing ESP completion and abandon the Schrader OA & OB perforation intervals (sundry form 10-403 to be submitted by 4ES ddlling engineer). TD Drill and Complete 1-04A pro.qram: Planned for May 29, 2001 1) Set whipstock at ~4540' (in 7" casing at 25° wellbore inclination) 2) Mill window through 7" and mill 10' of openhole. 3) Drill horizontal sidetrack 1-04A from window to 6696' TD targeting Schrader Bluff OB sand interv per attached directional plan. 4) Complete with slotted liner from TD to ,,,20' inside of 7" casing. CTD Drill and Complete 1-04A L1 Lateral pro,qram: Planned for June 8,2001 5) CTD set flowthrough whipstock at ~4515' (in 7"casing at 25° wellbore inclination) 6) Mill window through 7" and mill 10' of openhole 7) Drill horizontal lateral 1-04A L1 from window to 6655' TD targeting Schrader Bluff OA sand interval as per attached directional plan. 8) Complete with slotted liner from TD to ~20' inside of 7"casing Mud Program: · Steps l& 2:8.5 ppg KCL/NaCl biozan brine · Steps 3-8: FIo-Pro (9.3 - 9.9 ppg) Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to PBU DS-4 Grind & Inject · Class I wastes will go to Pad 3 for disposal. Casing Program: ~ · 1-04A - 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from 6696' TD to approximately 4520' · 1-04A L1 - 2 7/8", 6.16#, L-80, STL slotted/pre perforated liner will be run from 6655' TD to approximately 4495' Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plans for 1-04A_ & 1-04A L_~I. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Resistivity logging in sections of the openhole Hazards · No significant faults are expected to be crossed, lost circulation risk is Iow. Res. pressure is 8.8 ppg. 1-04 had an H2S reading of <2 ppm 2/01. Milne Point production has historically been sweet. Highest H2S on the pad is <2 ppm. Reservoir Pressure · Res. pressure is approx. 1775psi @ 3860ss (8.8 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 1400 psi. 1-04A and 1-04A L1 Potential Drilling Hazards Post on Rig . , Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut down the operation and discuss the situation before making the next operational move. SAFETY FIRST. H2S is not expected on this well. 1-04 had an H2S reading of <2 ppm 2/01. Milne Point production has historically been sweet. Highest H2S on the pad is <2 ppm. 2. BHP is expected to be approx. 1775psi (8.8ppg) @ 3860'ss. 3. Maximum anticipated well head pressure w/full column of gas is 1400psi. 4. Lost circulation risk is Iow with no significant faults expected to be penetrated. TREE: 2-9/16"- 5~ WKM WELLHEAD: 11" 5M WKM w/ 2-7/8" 8rd TREE TOP CONNECTION 2.1/2" "H" Profile. 1-04 ,~. L = 52' (NABORS 27E) Orig. KB - GL = 35' (NABORS 27E) 13 3/8", 54.5~, I 115' I K-55 Weld SetI . I KOP @ 500' Max Hole Angle: 38.9° @ 2100' MD 9 5,8", 36~, 12599' I K-55 Butt Raychem Heat Trace Camco 2 7/8" x 1" I 1 35' sidepocket KBMM GLM I RA Tag @ 3,623' 2-7/8" 6.5~ L-80 EUE 8rd tbg .00579 bbts/ff. 7" 26~ L-80 buttress casing .O383 bbls/ff. Camco 2 7/8" x 1" sidepocket KBMM GLM 4076' Pump Intake @ 3668' TVD N SAND PERFORATION SUMMARY 124 I 4,383"4,392'13,86°'- 3,868' 124 I 4,411'-4,428'j3,885'-3,901' 124 I 4'443"4'451'13'914"3'921' I 124 spf,24 gm I O SAND PERFORATION SUMMARY INTERVAL TVD 4,554' - 4,588' 4,624' - 4,655' 5 spf, 37 gm 4,015' - 4,045' 4,078' - 4,106' DATE 3/9/95 REV. BY DBR COMMENTS RWO - INSTALL ESPCP 8-29-96 MDO ESP RWO POLAR#1 Centrilift KUDU, PCP, [ 4165' 60 TP 1300 / Centriliff GSTDBILAFLASHSNPFS, { 4188' seal section Centdlift sedes, GMF 50 hp motor, 1170 v./27 4202' amps. 4209' Centrilift PHD 7" OTIS "VST' VERSA-TRIEVE Pkrl4 I H-S 3-1/2" Blank Pipe (73') ,260' H-S 12 Guage H-S Screen (100', 2.99" ID) 4359' Frac Pack (N-sands) 20140 Mesh Gravel 3-1/2" H-S 12 Gauge Tell-Tale Screen (11', 2.99") 3-1/2" X NIPPLE (2.313"1D) . Wireline Entry Guide(2.44" ID) I 4,497, PBTD ] 4,795' 7", 26#/ft, L-80 Butt Shoe MILNE POINT UNIT WELL 1-04a APl NO: 50-029-22068 BP EXP,LORATION {AK) WELLHEAD: 11" 5M WKM wi~ ="~,~, Orig. KB - GL = 35' (NABORS 27E) 2-7/8" 8rd TREE TOP CONNECTION ~ --= --= --= 2.1/2" "H" Profile. I K-55 Weld Set KOP @ 500' Max Hole Angle: 38.9° @ 2100' MD 95/8-, I .... ' K-55 Butt ~ Frac pack of N sands RATao@3,623'~, i i~--------7 and ESP installation / after CTD sidetrack 7" 26~ L-80 buttress casing ~ ~' is completed. .0383 bbls/ft. / N.__SAN D___.P E RFC RATIO N._~~ U M MAR~Y == SIZE SPF INTERVAL TVD ' i 24 4,383' - 4,392' 13,860' - 3,868' I'i 24 4,411' - 4,428' ! 3,885' - 3,901' I' 24 4,443' - 4,451'i 3,914'- 3,921' ~ 24spf, 24 gm ' ~-----Top ,~f liner at ~4495' m~ OA whipstock at 4515' md ~...~..~ ::': .~:::::: :: ::~. ~: : ~- -'. ~1~ilIIiIIIIIt1II{~12 7/8" pre drilled liner ~OA San~dh~ A . ~---Top of liner at -4520' md 08 whipstock at 4540' md ~ :: :: : , ~ ":~{'~II{IlI~2 7~8" pre drilled liner Cement retainer at 4550' md .. ~,,~:', ~'~iI~ilil~)lfl~iIi~)~E)Ii~iilI~IIIIIIIiIi~iIiJXIiiIIIIIi]: O SAND PERFORATION SUMMARY~ i~ Abandoned under cmt retainer - SIZE SPF INTERVAL TVD 5 4,554'-4,588' 4,015'-4,045' ~ PBTD I 4,795' 5 4,624'-4,655' 4,078'-4,106' 7",26~/ft, L-80 Butt I 4.881' 5 spf, 37 gm Shoe DATE, , REV. BY COMMENTS MILNE POINT UNIT 3~9~95 DBR RWO -I'NSTALL ESPCP WELL 1-04a 8-29-96 MDC ESP RWO POLAR#1 APl NO: 50-029-22068 5i14/01 MOJ Proposed post CTD 'sidetrack , , , BP EXPLORATION {AK) -- Mmv4 (MMV4) I ~, u Magnetic North: 26.25° Created By: Brij Polnis Date: 5/11/2t301 ' MPI-04 IMPI-O4P81! ~'1· m BP Amoco 0 ~'Q II1 ~' ~'t11~$ Magnetic Field, ......... . bp H~J~H~ ~--~'~1/~ Strength: 57440,T ] Con,ac, Inlormation: Dip Angle: 80.77° ~ Direct: (907) 267-6613 '"~'"~¢"~"~"" !LNTE, Date: 5/~1~200~ I Baker Hughes INTEQ: (907) Model: BGGM2000 1 267-6600 '"""'~ ."'*'~'G:..; '",.',',,-?. .. Ref. O~m~: M PI,.04 REFERENCE INFORMATION Co-ordi~te (N/~) Ref~et~e: Well Oen~e: MPI.04. True No~h Verlfcal (TVD) I~ferer~e: System: Mean gea Level ' . . . ; I ' ' ~ (VS) Referetx;e: Slot- 04 (O.OON.O.OOE) Measured D~pth Reference: MPI-04 70.00 _~ I -- Calculation Method: Minimum Curvature ;-=:.: .......... ~. ............ Ml.e~ 07~4 t1~ 3e7~.71 tiN.el 112~.]l 40~0 4~ 2t43.01 ' ~ 1~2~ ~124 3173.t2 II~L~12S?.~1 10~ -B$.(~ ~2~8.~ I IOSL4~ IIJ~ /I~S 31~sJ1 274~.~J 1STS.to iO~D~ Io.~ $1~e.$1 · lSS.M 87.74 t]1.23 40~0.0~ 2e~1.~4 2137.41 10.~ S2.SO 3394.~ G " ' i ,. i~ ~ 0 ....... w. "'" """~"~" ,.~.~,.~ ............. A i .~ ..... 1--- t t t .... -I----1---~- ~.-~,.. ,,.,',~.~ .%; ~;:~ ~ ~ :,,,~' ~ + i ~- -: -:- 3/IsJt ~eas~ s : ' ' i I i · o~.. ~-s.~ ~ 0 ~ ! ~z; : t :---= ,~-t 'I' ' ' ! ~ ~ -I i .... ,. i I ............ ' , i ~5o~ "' I : '' i . I" ~ ' : ' ......., I ..... .... q ! q4 31 I t I i I · ; ~I ~ , ~ ~ ~ ~ ~ , ~ [ -' . .......... _L ........ o ..... ~ ~ ~ ' ~ ~~ ~ ; ; ! ~0 7~ S~ ~0 1~ 11~ 12~ 13~ 14~ 15~ 1~ 17~ 1~ 1~2~21~ ~'~ ~37 ' 0~~5~5 '~' ' -3~i4 ..... ' "!"" ' !"" ....." ' .... .... I"" .... ~ ~i~ '~~~'-'~-- -- ~ - ~--- ~ } .~. , I ,,~!. !:-:l'~.:~~~,T,,.., ~:: '-~':: ~' ~'1". ---: ..: -.":' :.'': ~'.: . ~: ~! ~;~ ..'. /",..,' --- q--:--h --I ---K -t---~,- -:'~-~ ~~:4~_~:--~-~ --I --t ........... ~- -~---t--~'-~:-q---t .... ~-~-:-t ..... t-----~' j I ~ I ~ I N i i I I I I I I I I I , I I 4 I i [ i ~ i ~L I J I I I I I I I I' I I I I I I I: I I : I I I 1800 1850 ~00 to50 2ooo 2050 2~00 2~ 0 22oo ~50 2~00 2~50 24oo 24e0 25oo 2550 26oo 2650 2?00 2?50 26oo 26~0 ~ 2~50 ~000 s050 s~oo s~50 ~200 ~250 ~soo s~50 :~00 ~$0 ~500 ~550 ~600 ~50 s?oo Vertical Section at 40.00° [5Oft/in] R/1119001 R:O.q PM ObP BP Amoco Bake(r ltughes INTEQ Planning Repo(t roll BAKER HUGHES INTEQ Company: BP Amoco Field: Milne iPoint Site:' : 'MPtlPad :' ,Well:., ':. MPI-04.' Wellpath: .Plang2 (CTD) MPI-04A Date: 5/1112001 Time: 14:57:47 Page: 1 C~i~) R~: L Well: MPI-O4, True North Vertical (']'~D) Ra~'ereace: .System: Mean Sea Level Section (~S) Reference: Well (0.00N,0.0OE,40.00Azi) Sum,~ Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ft 6008388.01 ft Latitude: 70 26 1.282 N 550245.83 ft Len~itude: 149 35 25.422W North Reference: True Grid Convergence: 0.39 deg Well: MPI-04 Slot Name: 04 MPI-04 Well Posifion: +NI-S 1056.45 ft Northing: 6009452.79 ft Latitude: 70 26 11.670 N +E/-W 1255.97 ft Easting: 551494.53 ft Len~itude: 149 34 48.561 W Position Uncertainty: 0.00 ft Wellpath: Plan#2 (CTD) MPI-04A Drilled From: MPI-04 500292206801 Tie-on Depth: 4546.00 ft Current Datum: MPI-04 Height 70.00 ff Above System Datum: Mean Sea Level Magnetic Data: 5/9/2001 Declination: 26.25 deg Field Strength: 57440 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 40.00 Plan: Plan #2 Date Composed: 5/9/2001 CTD Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets · " .".':'. ~":.,;'...'...'i ".'. :,'.'"'~;' ."::"":? f"' :'~:~,:~ :';":,'.".: · '. i....."'." '",i';':. ::: ...~::ft'.,, ..'..' ...'::.i:~':'::i;:"':.~;.ft, :.;?..i..,'.,~?: :'...'?::"::.ft, ":,." ....;...:..:~ft.'.~".!,:. 4~ :f:.::.:?: !,:ft::-:,'/'::!: L. :):::/. ::.'~ :: ¢/: 9 ;.':. :.' '... :: :/:,,!..." :': ':.~.:/': './../, ':', :".,. ':.. MPI-04A T2.4 4064.00 2786.17 1792.75 6012251.00 553267.83 70 26 39.070 N 149 33 55.927 W MPI-04A T2.5 4067.00 2825.43 2066.35 6012292.15 553541.12 70 26 39.455 N 149 33 47.895 W MPI-04A T2.6@TD 4070.00 2756.25 2166.59 6012223.66 553641.83 70 26 38.774 N 149 33 44.952 W MPI-04AT2.3 4055.00 2943.08 1511.17 6012405.95 552985.20 70 26 40.614 N 149 34 4.193 W MPI-04AT2.2 4045.00 2336.56 1147.84 6011796.99 552626.11 70 26 34.649 N 149 34 14.863 W MPI-04AT2.1 4033.00 1726.09 1236.24 6011187.21 552718.71 70 26 28.645 N 149 34 12.271 W MPI-04A Polygon2.1 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W -Polygon 1 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W -Polygon 2 0.00 3358.48 1057.92 6012818.17 552529.14 70 26 44.700 N 149 34 17.499 W -Polygon 3 0.00 3250.46 1653.66 6012714.28 553125.55 70 26 43.636 N 149 34 0.008 W -Polygon 4 0.00 2937.08 2446.64 6012406.41 553920.60 70 26 40.552 N 149 33 36.728 W -Polygon 5 0.00 2510.29 2259.85 6011978.38 553736.78 70 26 36.355 N 149 33 42.216 W -Polygon 6 0.00 2569.64 1614.17 6012033.27 553090.77 70 26 36.941 N 149 34 1.172 W -Polygon 7 0.00 2302.76 1443.45 6011765.24 552921.91 70 26 34.316 N 149 34 6.185 W -Polygon 8 0.00 1522.14 1373.59 6010984.23 552857.45 70 26 26.639 N 149 34 8.241 W -Polygon 9 0.00 1340.23 1059.22 6010800.17 552544.37 70 26 24.851 N 149 34 17.469 W -Polygon 10 0.00 1296.80 974.42 6010756.16 552459.88 70 26 24.424 N 149 34 19.959 W Ob. BP Amoco o( -,,--. HUGHES Bak r Hughes INTEQ Planning Rep ~ ~ INTF~Q I lqo Company: BP Amoco · Field: Milne Point site: '. MPtlPad , ,, Well:' MPI-04 Wellpath: plan#2 (CTD) MPI-04A Date: ,~ 5/11/2(X)1 Time: 14:57:47 Page: ./.. 2 Co-ordln~te(N~) Reference: Well: MPI-04, Tree North · · Vertical (1'I/])) Reference: System: Mean Sea LeVel . Section (VS) Reference: Well (0.00N,0:00E,40.00Azi)'. ,. Smwey CalcalationMetbed: , Minimum Curvature ..."Db--' OraCle ., Annotation 4500.00 3896.13 TIP (~ 3937.75 KOP 4020.00 I ~ 4786.09 4032.99 2 4986.09 4042.00 3 5236.09 4044.30 4 6086.09 4057.09 5 6146.09 4060.82 6 6196.09 4064.37 7 6546.09 4067.05 8 6696.09 4070.24 TD Plan Section Information · .. ft deg deg ft +NI-S +E/-w; DLS' Build Turn TFO Target ft deg/100ft deg/100ft deg/100ft deg 4500.00 25.23 51.68 3896.13 1508.37 1143.84 0.00 0.00 0.00 0.00 ~4546.00 25.13 51.48 3937.75 1520.53 1159.18 0.29 -0.22 -0.43 220_3D 4686.09 80.00 35.00 4020.00 1602.18 1227.56 ~ 39.17 -11.76 "4786.09 85.09 26.32 4032.99 1687.39 1278.02 10.00 5.09 -8.68 -60.00 4986.09 89.79 6.85 4042.00 1877.92 1334.70 10.00 2.35 -9.73 -77.00 5236.09 89.17 341.86 4044.30 2124.72 1310.31 10.00 -0.25 -10.00 -91.50 6086.09 89.43 66.87 4057.09 2829.85 1629.63 10.00 0.03 10.00 90.50 6146.09 83.43 66.87 4060.82 2853.37 1684.68 10.00 -10.00 0.00 180.00 6196.09 88.43 66.87 4064.37 2872.96 1730.53 10.00 10.00 0.00 0.00 6546.09 90.72 101.79 4067.05 2906.98 2073.41 10.00 0.65 9.98 86.50 6696.09 86.86 116.29 4070.24 2858.20 2214.77 10.00 -2.58 9.67 105.00 Survey ..... · ...':, :..;:: ..:,' F.,/W:'.'...'. '"i" .. :'~..'.i;MaPN...~.".::;::.;.;' ..'". 'MapF. '. 'DLS .: ".;.;'".:i:"::.'." VS'..": ff..'?"".'.'"..'.'.""................~ ..... . deg"":'. ': . .: ... .".'.'., .:'.' ......."." :.~. .' .ff. .. . ::i..." ":..:. ':"....'ff'":.":'.:....... ' ..:..:',.'..'.':~?.'.'ff,....... '.'?'.";:':';........"...' .""......'..:." .. ff.. .i' ' deg/100fti.;'i.. .?<~ ft,:.'::., :..;-:::.'. 4500.00 25.23 51.68 3896.13 1508.37 1143.84 6010968.88 552627.82 0.00 1890.72 0.00 TIP 4525.00 25.18 51.57 3918.75 1514.98 1152.19 6010975.54 552636.12 0.29 1901.15 220.30 MWD 4546.00 25.13 51.48 3937.75 1520.53 1159.18 6010981.14 552643.07 0.29 1909.90 220.40 KOP 4550.00 26.64 50.28 3941.35 1521.63 1160.53 6010982.25 552644.42 40.02 1911.62 340.32 MWD 4575.00 36.26 44.90 3962.66 1530.47 1170.09 6010991.16 552653.91 40.02 1924.53 341.40 MWD 4600.00 46.02 41.55 3981.46 1542.47 1181.30 6011003.23 552665.04 40.02 1940.93 346.01 MWD 4625.00 55.85 39.16 3997.20 1557.26 1193.83 6011018.11 552677.47 40.02 1960.31 348.54 MWD 4650.00 65.72 37.28 4009.39 1574.39 1207.30 6011035.33 552690.82 40.02 1982.09 350.05 MWD 4675.00 75.61 35.66 4017.66 1593.34 1221.30 6011054.37 552704.68 40.02 2005.60 350.97 MWD 4686.09 80.00 35.00 4020.00 1602.18 1227.56 6011063.25 552710.88 40.03 2016.40 351.54 I 4700.00 80.70 33.78 4022.33 1613.50 1235.31 6011074.62 552718.55 10.00 2030.05 300.00 MWD 4725.00 81.96 31.60 4026.10 1634.29 1248.65 6011095.51 552731.75 10.00 2054.56 300.20 MWD 4750.00 83.24 29.43 4029.32 1655.65 1261.24 6011116.95 552744.19 10.00 2079.01 300.53 MWD 4775.00 84.52 27.27 4031.99 1677.53 1273.04 6011138.90 552755.84 9.99 2103.35 300.76 MWD 4786.09 85.09 26.32 4032.99 1687.39 1278.02 6011148.80 552760.75 9.99 2114.11 300.99 2 4800.00 85.40 24.96 4034.14 1699.89 1284.02 6011161.34 552766.66 10.00 2127.54 283.00 MWD 4825.00 85.98 22.52 4036.02 1722.70 1294.05 6011184.22 552776.53 10.00 2151.47 283.11 MWD 4850.00 86.55 20.08 4037.65 1745.95 1303.11 6011207.52 552785.43 10.00 2175.10 283.30 MWD 4875.00 87.14 17.65 4039.03 1769.57 1311.19 6011231.20 552793.34 10.00 2198.38 283.45 MWD 4900.00 87.73 15.22 4040.15 1793.52 1318.25 6011255.19 552800.24 10.00 2221.27 283.59 MWD 4925.00 88.32 12.79 4041.01 1817.78 1324.29 6011279.47 552806.12 10.00 2243.72 283.70 MWD 4950.00 88.92 10.36 4041.61 1842.24 1329.31 6011303.99 552810.96 10.00 2265.70 283.78 MWD 4975.00 89.52 7.93 4041.95 1866.92 1333.28 6011328.69 552814.76 10.01 2287.16 283.92 MWD 4986.09 89.79 6.85 4042.00 1877.92 1334.70 6011339.70 552816.10 10.01 2296.50 283.96 3 5000.00 89.75 5.46 4042.06 1891.75 1336.19 6011353.54 552817.50 10.00 2308.05 268.50 MWD 5025.00 89.69 2.96 4042.18 1916.68 1338.03 6011378.48 552819.18 10.00 2328.33 268.51 MWD 5050.00 89.62 0.46 4042.33 1941.67 1338.77 6011403.47 552819.74 10.00 2347.95 268.52 MWD ~ BAKER ( BP Amoco HUGHES Baker Hughes INTEQ Planning Rep INTEQ Company: BP Amoco Field: Milne Point Site: , M Pt I Pad Well: MPI-04 ' ,' WetlFatb: Plan#2 (CTD) MpI-04A Date: 5/11/2001 , · . Time: 14:57:47 Pa~: 3 Ce;e~baate(NE) l~eference: Well: MPI-04, True North Vertical (1'I/])) Refereace:' System: Mean Sea Level Section CvS) Referenee: Well (0.00N~0.00E,40,00Azi) Sar~ey CaIcalation Mel~od: Minimum Curvature Db: Oracle Survey MD ]nd AziTM SSTVD N/S E/W MapN MapE ' DLS VS TFO Tool · , ft deg deg ff ff ,, -ff ff ff deg/10Oft' ft ' dog 5075.00 89.56 357.96 4042.50 1966.66 1338.43 6011428.46 552819.22 10.00 2366.88 268.53 MWD 5100.00 89.50 355.46 4042.71 1991.62 1336.99 6011453.40 552817.61 10.00 2385.07 268.55 MWD 5125.00 89,44 352.96 4042.94 2016.49 1334.47 6011478.25 552814.92 10.00 2402.50 268.57 MWD 5150.00 89.38 350.46 4043.20 2041.22 1330.87 6011502.96 552811.15 10.00 2419.13 268.59 MWD 5175.00 89.32 347.96 4043.49 2065.78 1326.19 6011527.48 552806.30 10.00 2434.94 268.62 MWD 5200.00 89.26 345.46 4043.80 2090.10 1320.45 6011551.76 552800.39 10.00 2449.88 268.65 MWD 5225.00 89.20 342.97 4044.14 2114.16 1313.65 6011575.76 552793.43 9.99 2463.94 268.59 MWD 5236.09 89.17 341.86 4044.30 2124.72 1310.31 6011586.30 552790.01 9.99 2469.88 268.62 4 5250.00 89.16 343.25 4044.50 2137.99 1306.14 6011599.54 552785.75 10.00 2477.37 90.50 MWD 5275.00 89.14 345.75 4044.87 2162.07 1299.46 6011623.58 552778.91 10.00 2491.52 90.48 MWD 5300.00 89.12 348.25 4045.25 2186.43 1293.84 6011647.89 552773.12 10.00 2506.57 90.44 MWD 5325.00 89.10 350.75 4045.64 2211.01 1289.29 6011672.43 552768.40 10.00 2522.47 90.40 MWD 5350.00 89.09 353.25 4046.04 2235.76 1285.81 6011697.16 552764.75 10.00 2539.19 90.37 MWD 5375.00 89.07 355.75 4046.44 2260.64 1283.41 6011722.02 552762.18 10.00 2556.71 90.33 MWD 5400.00 89.06 358.25 4046.85 2285.60 1282,11 6011746.97 552760.70 10.00 2574.99 90.29 MWD 5425.00 89.05 0.75 4047.26 2310.59 1281.89 6011771.95 552760.31 10.00 2594.00 90.25 MWD 5450.00 89.04 3.25 4047.67 2335.57 1282.76 6011796.94 552761.01 10.00 2613.69 90.20 MWD 5475.00 89.04 5.75 4048.09 2360.49 1284.72 6011821.87 552762.80 10.00 2634.04 90.16 MWD 5500.00 89.03 8.25 4048.51 2385.30 1287.77 6011846.69 552765.68 10.00 2655.01 90.12 MWD 5525.00 89.03 10.75 4048.93 2409.95 1291.90 6011871.37 552769.64 10.00 2676.54 90.08 MWD 5550.00 89.03 13.25 4049.35 2434.40 1297.10 6011895.85 552774.67 10.00 2698.61 90.04 MWD 5575.00 89.03 15.76 4049.78 2458.59 1303.36 6011920.09 552780.76 10.00 2721.17 89,99 MWD 5600.00 89.04 18.26 4050.20 2482.50 1310.67 6011944.04 552787.90 10.00 2744.18 89.95 MWD 5625.00 89.04 20.76 4050.62 2506.06 1319.01 6011967.65 552796.08 10.00 2767.60 89.91 MWD 5650.00 89.05 23.26 4051.04 2529.23 1328.38 6011990.89 552805.29 10.00 2791.37 89.87 MWD 5675.00 89.06 25.76 4051.45 2551.97 1338.75 6012013.70 552815.50 10.00 2815.45 89.83 MWD 5700.00 89.07 28.26 4051.86 2574.24 1350.10 6012036.04 552826.69 10.00 2839.81 89.78 MWD 5725.00 89.08 30.76 4052.27 2595.99 1362.41 6012057.88 552838.85 10.00 2864.39 89.74 MWD 5750.00 89.09 33.26 4052.67 2617.19 1375.66 6012079.16 552851.95 10.00 2889.14 89.70 MWD 5775,00 89.11 35.76 4053.06 2637.79 1389.82 6012099.85 552865.97 10.00 2914.02 89.66 MWD 5800.00 89.12 38.26 4053.44 2657.75 1404.86 6012119.92 552880.87 10.00 2938.98 89.62 MWD 5825.00 89.14 40.76 4053.82 2677.03 1420.76 6012139.31 552896.64 10.00 2963.97 89.59 MWD 5850.00 89.16 43.26 4054.19 2695.60 1437.49 6012157.99 552913.24 10.00 2988.95 89.55 MWD 5875.00 89.19 45.76 4054.55 2713.43 1455.01 6012175.94 552930.63 10.00 3013.87 89.51 MWD 5900.00 89.21 48.26 4054.90 2730.47 1473.29 6012193.11 552948.80 10.00 3038.68 89.47 MWD 5925.00 89.23 50.76 4055.24 2746.70 1492.30 6012209.47 552967.69 10.00 3063.33 89.44 MWD 5950.00 89.26 53.26 4055,57 2762.09 1512.00 6012224.99 552987.28 10.00 3087.78 89.41 MWD 5975.00 89.29 55.76 4055.89 2776.60 1532.36 6012239.64 553007.53 10.00 3111.98 89.37 MWD 6000.00 89.32 58.26 4056.19 2790.21 1553.32 6012253.39 553028.40 10.00 3135.88 89.34 MWD 6025.00 89.35 60.76 4056.48 2802.90 1574.86 6012266.22 553049.85 10.00 3159.44 89.31 MWD 6050.00 89.38 63.26 4056.76 2814.63 1596.93 6012278.10 553071.84 10.00 3182.62 89.28 MWD 6075.00 89.41 65.76 4057.02 2825.39 1619.50 6012289.02 553094.33 10.01 3205.36 89.25 MWD 6086.09 89.43 66.87 4057.09 2829.85 1629.63 6012293.55 553104.43 10.01 3215.30 89.22 5 6100.00 88.04 66.87 4057.40 2835.31 1642.42 6012299.10 553117.18 10.00 3227.70 180.00 MWD 6125.00 85.54 66.87 4058.80 2845.12 1665.37 6012309.06 553140.06 10.00 3249.97 180.00 MWD 6146.09 83.43 66.87 4060.82 2853.37 1684.68 6012317.45 553159.31 10.00 3268.70 180.00 6 6150.00 83.82 66.87 4061.25 2854.90 1688.25 6012319.00 553162.87 10.00 3272.17 0.00 MWD 6175.00 86.32 66.87 4063.40 2864.68 1711.16 6012328.94 553185.70 10.00 3294.38 0.00 MWD 6196.09 88.43 66.87 4064.37 2872.96 1730.53 6012337.35 553205.02 10.00 3313.18 360.00 7 6200.00 88.45 67.26 4064.48 2874.48 1734.13 6012338.90 553208.61 10.00 3316.66 86.50 MWD 6225.00 88.61 69.76 4065.12 2883.64 1757.38 6012348.22 553231.79 10.00 3338.62 86.49 MWD 6250.00 88.77 72.25 4065.69 2891.77 1781.01 6012356.51 553255.36 10.00 3360.04 86.43 MWD 6275.00 88.93 74.75 4066.19 2898.87 1804.98 6012363.77 553279.28 10.00 3380.88 86.37 MWD ObP BP Amoco Baker Hughes INTEQ Planning Repot-t BAKER HUGHES INTEQ Company: BP Amoco . Date: 5/11/2001 Time: 14:57:47 Page: 4 Reid: Milne Point ~ Co-orainate(NE) Reference: Well: MPI-04, True North Site: M Pt I Pad ~ Vertical ti'VD) Reference: System: Mean Sea Level Well: MPI-04 Seetion'(VS) Reference: Well (0~00N,0.00E,40.00Azi) Wellpath: Plan#2 (CTD) MPI-04A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel A~im SSTVD N/S E/W MapN MapE DLS VS TFO Tool ff deg deg ff ff ff ff ff deg/100ft ff deg 6300.00 89.09 77.24 4066.63 2904.92 1829.23 6012369.99 553303.48 10.00 3401.10 86.32 MWD 6325.00 89.25 79.74 4066.99 2909.91 1853.72 6012375.15 553327.94 10.00 3420.67 86.27 MWD 6350.00 89.41 82.23 4067.28 2913.82 1878.41 6012379.23 553352.60 10.00 3439.54 86.24 MWD 6375.00 89.58 84.73 4067.50 2916.66 1903.24 6012382.24 553377.41 10.00 3457.67 86.21 MWD 6400.00 89.75 87.22 4067.65 2918.42 1928.18 6012364.17 553402.33 10.00 3475.05 86.19 MWD 6425.00 89.91 89.72 4067.72 2919.09 1953.17 6012385.01 553427.31 10.00 3491.62 86.17 MWD 6450.00 90.08 92.21 4067.72 2918.67 1978.16 6012384.76 553452.30 10.00 3507.37 86.17 MWD 6475.00 90.25 94.70 4067.65 2917.16 2003.11 6012383.43 553477.26 10.00 3522.25 86.17 MWD 6500.00 90.41 97.20 4067.51 2914.57 2027.98 6012381.01 553502.14 10.00 3536.25 86.17 MWD 6525.00 90.58 99.69 4067.29 2910.90 2052.70 6012377.51 553526.89 9.98 3549.33 86.18 MWD 6546.09 90.72 101.79 4067.05 2906.98 2073.41 6012373.74 553547.62 9.98 3559.64 86.20 8 6550.00 90.62 102.17 4067.00 2906.17 2077.23 6012372.95 553551.45 10.00 3561.47 105.00 MWD 6575.00 89.97 104.58 4066.88 2900.39 2101.55 6012367.34 553575.81 10.00 3572.68 105.00 MWD 6600.00 89.32 107.00 4067.03 2893.58 2125.61 6012360.70 553599.91 10.00 3582.93 105.02 MWD 6625.00 88.68 109.41 4067.47 2885.78 2149.35 6012353.06 553623.70 10.00 3592.21 105.00 MWD 6650.00 88.03 111.83 4068.18 2876.98 2172.74 6012344.42 553647.14 10.00 3600.50 104.96 MWD 6675.00 87.39 114.25 4069.18 2867.20 2195.72 6012334.81 553670.20 10.00 3607.79 104.84 MWD 6696.09 86.86 116.29 4070.24 2858.20 2214.77 6012325.94 553889.30 10.00 3613.13 104.75 TD 3S CTD BOP Detail '~ CT Injector Head ~__~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ I~ 7''Riser Otis 7" WLA Quick I' ' Connect ---- I 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I BlindlShear I { 2 3,8" Comb, Pipe/Sl,~ Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic 2" Side outlets 2 718" Combi Pipe/Slip 2 318" Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve 2 flanged gate valves Tubing Spool 7" Annulus MOJ 12/29/00 9 5/8" Annulus F! 1 881~2 04/19/01 00188132 VENDOR ALASKAO I LA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT [NET 041801 CK041801~ 100. O0 100. O0 PYMT (;OMMENTS- Peeltit to Dell 1 i'ee HANDLIlN~ INST' S/H - Teeeie Hub le X4&28 .,. HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~lIlI'-*lI ~ 100. 00 1 OO. OO B :ION,(ALAS~. ),.INC...ST .AT,O.^L .~.~ P.O. E ~,~ Ami IATe 0- · .: ', '.~ ~: , . '. ':ANC ~...~::.' L:?.:..~;..:;:;¥;.:..~.,,~.... ..... ... '.~ ~." " PA'~':'.:. ... ;';.:,j:~. : ,' :'! N.O- :H 1 8.8' · CONSOLIDATED COMMERCIAL ACCOUNT '~:~ "~i~. NOT VALID' AFTER 120 DAYS .': ,,!'" ,' I,P, 8 I,:[ 2,' ,:Or, & 2O~,,°,qSm: OOaht, WELL PERMIT CHECKLIST COMPANY ~/~ FIELD & POOL WELL NAME/~/~'"~ PROGRAM: exp__ INIT CLASS /_7~.~,- /'--,~, ~/ # ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31 32. 33. 34. GEOLOGY . ;APPR D T Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to.tie-in long string to surf csg .... .... CMT will cover all known productive horizons ..... ': .... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate weilbore separation proposed .............. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR 'DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; ' ' (C) will not impair mechanical integrity of the Well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: COMMISSION: dev .. , __ redrli ,~ serv __ wellbore sag , , , , ann. disposal para req ~ GEOL AREA UNIT//: /'/",.~.~,~' ON/OFF SHORE If diverter required, does it meet regulations .......... ~ t,.~l~ Drilling.fluid program schematic & equip list adequate.. ~ . . ~..N, __ ~ i .. BOPEs, do they meet regulation . ..... . .......... ~ N ..... .. r--,. ~ . BOPE press rating appropriate; test to ,"z,~ Choke manifold complies w/APl RP-53 (May 84) ..... .... ~;~ N ~ , . " Work will occur without Operation shutdown... ........ Is presence of H2S gas probable ................. Y Permit can be issued WIG .hydrogen sulfide measures ...... Y N ./' ' ' . Data presented on potential overpressure zones ....... Y seismic analysis of shallow gas zones ........ ..... Y/~I .~'_/~.,.,~--/, ' . Seabed condition survey (if off-shore), ............ Contact name/phone for weekly progress reports [exploratory onl/y] Y N Y N Yu / ...... , ,, ENGINEERING:. UICIAnnular Comments/Instructions: 0 Z 0 -I Z -I 'I- c:~nsoffice\wordian~diana\checklist (rev. 111011100) , '. 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 rite under APPEN. DIXi .. No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 02/01/31 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/01/31 168201 01 2-7/8" USMPR *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block %MNEM.UNIT Data Type STRT.FT 4540.0000: STOP.FT 5627.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing ADsent Value BP Exploration, Inc. MPI-04A-PB1 Milne Point Unit 2942' SNL, 3876' WEL North Slope Alaska Baker Hughes INTEQ 2-7/8" USMPR 02-Jul-01 500292206871 ~Parameter Information Block %MNEM.UNIT Value SECT. TOWN.N RANG. PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 ~Remarks Description 33 : Section T13N : Township R10E : Range MSL : Permanent Datum 0 : Elevation Of Perm° Datum RKB : Log Measured from 70 : Feet Above Perm. Datum KB : Drilling Measured From 70 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Casing Depth DIRECTIONAL : Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX,RACHX, RPCLX) presented is realtime data. (4) Well MPI-04A-PB1 was drilled as a sidetrack on Well MPI-04 at 4542' MD (3934' SSTVD). (5) Baker Hughes INTEQ utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 4660' MD (4011' SSTVD) to 5627' MD (4015' SSTVD). (6) The interval from 4660' MD to 4690' MD was relogged at MWD Run #6. (7) The interval from 5600' MD (4021' SSTVD) to 5627' MD 4015' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehole, as per BPX instructions. (9) A Magnetic Declination correction of 26.19 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX = ROPS = TVD = TCDX = RACLX = Gamma Ray MWD-API [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True Vertical Depth (SSTVD), (feet) Downhole Temperature [MWD], (deg F) Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCLX = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) RACHX = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCHX = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A No Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 78 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPI-04A-PB1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1o The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 3 RACH RACHX 0.0 4 RACL RACLX 0.0 5 RPCH RPCHX 0.0 6 RPCL 7 TCDX RPCLX TCDX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Nun~ber of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool 0.0 0.0 Code Samples Units Size 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 3 RACH COMP 68 1 OHMM 4 4 RACL COMP 68 1 OHMM 4 5 RPCH COMP 68 1 OHMM 4 6 RPCL COMP 68 1 OHMM 4 7 TCDX COMP 68 1 degF 4 Total Data Records: 71 Tape File Start Depth = 4540.000000 Tape File End Depth = 5627.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 85 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 02/01/31 54 bytes 4124 bytes 168201 01 Length 28 **** REEL TRAILER **** MWD 02/01/31 BHI 01 Tape Subfile: 3 2 records... Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS 132 bytes 132 bytes DEPTH GRAX ROPS RPCH RPCL TCDX 4540.0000 64.3500 -999.2500 -999.2500 -999.2500 -999.2500 4540.5000 461.5530 -999.2500 -999.2500 -999.2500 -999.2500 4600.0000 99.3010 -999.2500 -999.2500 -999.2500 -999.2500 4700.0000 60.6230 165.3820 22.2100 21.6170 66.2000 4800.0000 89.1720 60.8340 6.5890 6.8520 71.6000 4900.0000 60.6990 191.2720 19.8290 17.7440 73.4000 5000.0000 66.5560 182.5720 23.7660 22.0460 75.2000 5100.0000 57.5040 165.8990 17.1180 16.7410 75.2000 5200.0000 89.9070 156.2650 10.6360 11.8550 78.8000 5300.0000 85.7990 193.2280 5.8280 5.8620 80.6000 5400.0000 90.1710 179.7490 5.0310 5.5140 80.6000 5500.0000 93.2540 192.9120 9.5420 10.3460 80.6000 5600.0000 -999.2500 181.7080 -999.2500 -999.2500 77.0000 5627.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 4540.000000 Tape File End Depth = 5627.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet RACH -999.2500 -999.2500 -999.2500 22.0660 7.1220 16.4230 21.0320 16.4830 13.4600 5.8530 5.8620 11.1720 -999.2500 -999.2500 RACL -999.2500 -999.2500 -999.2500 16. 6260 7.9440 13.0790 16.4600 13. 6320 12.4250 6.5670 6.4590 11.4120 -999.2500 -999.2500 Tape Subfile 3 is type: LIS **** REEL HEADER **** MWD 01/09/18 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/09/16 168201 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las -Version Information VERS. 1.20: WP~AP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 4510.0000: STOP FT 6888.0000: ~T~P FT 0.5000: NULL -999.2500: COMP COMPANY: WELL WELL: FLD FIELD: LOC LOCATION: CNTY COUNTY: STAT STATE: SRVC SERVICE COMPANY: TOOL TOOL NAME & TYPE: DATE LOG DATE: API API NYUMBER: -Parameter Information Block #MNEM.UNIT Value SECT. 33 : TOWN.N T1 3N : RANG. RI 0E : PDAT. MSL : EPD .F 0 : LMF . RKB : FAPD.F 70 : DMF . KB : EKB .F 70 : EDF .F N/A : EGL .F N/A : CASE.F N/A : OS1 . DIRECTIONAL : -Remarks CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacin9 Absent Value BP Exploration, Inc. MPI-04A Milne Point Unit 2942' SNL, 3876' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 04-Jul-01 500292206801 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX,RPCHX, RACHX,RPCLX) presented'is realtime data. (4) Baker Hughes INTEQ on Run 1 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 4840' MD (4036' SSTVD) to 6888' MD (4055' SSTVD). (5) The interval from 6859' MD (4055' SSTVD) to 6888' MD (4055' SSTVD) was not logged due to sensor to bit offset. (6) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehole, as per BPX instructions. (7) A Magnetic Declination correction of 27.24 degrees has been applied to the Directional Surveys. MNEMONICS: GR3%X ROPS TVD TCDX RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Downhole Temperature [MWD], (deg F) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA N/A N/A N/A N/A DIRECTIONAL N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A No Depth Shift applied. Gamma Ray MWD is the PDC. Tape Subfile: 1 81 records... Minimum record length: Ma.×imu.m record].en~th: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPI-04A FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP RACH RACH RACL RACL RPCH RPCH TCD TCD TCDX TCDX ROPS RACHX RACLX RPCHX RPCLX TCDX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACH COMP 68 1 4 R3tCL COMP 68 1 5 RPCH COMP 68 1 6 TCD COMP 68 1 7 TCDX COMP 68 1 API F/HR 0.0 0.0 0.0 0.0 0.0 0.0 Total Data Records: 154 Tape File Start Depth = 4510.000000 Tape File End Depth = 6888.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 168 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TPJtILER **** MWD 01/09/16 168201 01 **** REEL TRAILER **** MWD 0~/09/~8 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ....... 28 Tape Subfile 2 DEPTH RPCH 4510.0000 -999.2500 4510.5000 -999.2500 4600.0000 -999.2500 4700.0000 22.1660 4800.0000 6.5800 4900.0000 22.2980 5000.0000 19.3130 5100.0000 13.5470 5200.0000 15.5170 5300.0000 16.9430 5400.0000 24.2340 5500.0000 20.7160 5600.0000 19.9390 5700.0000 12.3420 5800.0000 18.6870 5900.0000 10.3110 6000.0000 12.0020 6100.0000 9.3740 6200.0000 12.2400 6300.0000 12.5760 6400.0000 10.5550 6500.0000 12.2600 6600.0000 11.8470 6700.0000 is type: LIS GR TCD 48.2240 -999.2500 48.3820 -999.2500 99.3010 -999.2500 60.6230 21.5940 89.1720 6.8460 93.1770 17.3080 57.0030 19.1880 92.2210 15.2530 70.8000 16.5420 74.9630 17.2880 68.4040 22.8930 64.9000 19.7140 61.4550 19.9280 68.5600 13.7960 62.8600 18.7190 79.7270 12.4220 76.7600 11.6250 85.5830 8.8860 78.1650 10.3250 79.7270 12.1360 81.9130 10.8740 79.9220 13.0830 80.1950 13.1650 66.7650 ROP TCDX -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 165.4460 66.2000 60.9470 71.6000 12.3240 78.8000 211.8570 80.6000 180.8580 80.6000 159.6080 82.4000 160.4310 82.,~000 86.2260 84.2000 48.9330 82.8150 164.8050 84.2000 220.1320 85.1000 141.4170 86.0000 211.8570 86.0000 193.6230 86.0000 208.8600 86.0000 198.4570 84.2000 261.9170 82.4000 146.5690 84.2000 181.7080 84.2000 130.5090 86.0000 131.0720 RACH -999.2500 -999.2500 -999.2500 21.9660 7 1190 14 9780 19 8190 18 0260 17 4230 17 0330 23 9510 19 7080 20 4200 14 4820 19.4580 14 8460 12 1000 8 9640 9 7660 12 5230 11 8720 13 7450 14 9360 18 0240 RACL -999.2500 -999.2500 -999.2500 16.6210 7.9450 11.9420 16.7020 16.5180 16.5350 16.2860 18 1760 16 3320 17 8260 15 3200 16 4890 15 7050 10 2870 8 0090 8 4080 10 6080 10 8610 13 0620 14 5080 15 0130 17 · 0320 17 · 1530 87 · 8000 6800.0000 94.7200 138.9530 9.6570 9.9680 87.8000 6888.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 4510.000000 Tape File End Depth = 6888.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS 10.2900 -999.2500 10.3220 -999.2500