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206-156
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 F-99 MILNE PT UNIT F-99 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 F-99 50-029-23332-00-00 206-156-0 W SPT 6557 2061560 1639 1488 1502 1486 1485 87 172 154 146 OTHER P Sully Sullivan 4/28/2023 initial test after long term shut in. tested to 2200 to get over 500 psi diff. diesel temp 90deg. 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 F-99 Inspection Date: Tubing OA Packer Depth 1108 2183 2137 2129IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230430083212 BBL Pumped:1.5 BBL Returned:1.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 14:43:09 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPF-99 (PTD# 206-156) OPERABLE Date:Tuesday, April 18, 2023 8:29:25 AM Attachments:MP F-99 SCHEMATIC 9-18-2018.pdf MPF-99 TIO Plot.docx From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, April 17, 2023 8:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: MPF-99 (PTD# 206-156) OPERABLE Mr. Wallace, MPF-99 (PTD# 206-156) was made Not Operable after missing its scheduled witnessed MIT-IA in 2022. The well is now ready to be returned to injection. The well is now classified as OPERABLE and a witnessed MIT-IA will be scheduled once the well is on stable injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Revised By TDF 9/18/2018 SCHEMATIC Milne Point Unit Well: MPU F-99 Last Completed: 9/18/2007 PTD: 206-156 TD =9,270’ (MD) / TD = 7,215’(TVD) 20” Orig. KB Elev.:45.8’/ GL Elev.:11.5’Doyon 14 Orig. KB to BF = 29.73’ Doyon 14 7” 2 3 8 Heat Trace to 3,190’ 13-3/8” 1 Min ID= 3.725 @ 7,557’ PBTD =9,225’ (MD) / PBTD = 7,198’(TVD) 5 7 4 Kuparuk Sands 6 9-5/8” 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 92 / H-40 / N/A N/A Surface 112'N/A 13-3/8”Surface 68 / L-80 / BTC 12.415 Surface 4,893’0.1497 9-5/8"Production 47 / L-80 / BTC-M 8.681 Surface 7,954’0.0732 7-5/8"Liner 29.7 / L-80 / Hydril 513 6.875 7,775’8,670’0.0459 4-1/2”Liner 12.6 / L-80 / IBT-M 3.958 7,652’9,270’0.0152 TUBING DETAIL 4-1/2”Tubing 12.6 / L-80 / TC-II 3.958 Surf 7,579’0.0152 JEWELRY DETAIL No Depth Item 1 2,108’HES HXO SCSSV Nipple 2 7,491’HES X-Nipple: ID=3.813” 3 7,511 Baker 9-5/8” x 4-1/2” S-3 Packer 4 7,536’HES X-Nipple: ID=3.813” w/ RHC 5 7,557 XN-Nipple (3.725 No-go ID) 6 7,578 WLEG –Btm @ 7,579’ 7 7,652’9-5/8” x 4” LTP 8 7,775’9-5/8” x 7-5/8” LTP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 8,678’8,693’6,992’6,997’15 7/18/2018 Open 8,714’8,730’7,006’7,012’16 7/18/2018 Open 8,743’8,763’7,017’7,025’20 7/18/2018 Open 8,844’8,864’7,056’7,064’20 5/6/2007 Open 8,894’8,934’7,075’7,089’40 5/5/2007 Open 8,980’9,090’7,106’7,146’110 9/17/2007 Open Ref Log:SLB SCMT/ GR/ CCL 5/3/2007 –Guns used in 2007: 2-7/8”Omega Powerjet 6 spf. Guns used in 2018:2-7/8" GeoDynamics with Razor charges / 6 SPF / 60 deg phasing OPEN HOLE / CEMENT DETAIL 20"260 sx of Arcticset I (Approx) 42” Hole 13-3/8” 723 sx AS Lite, 550sx Class ‘G’ in a 16” Hole 9-5/8"792 sx Class ‘G’ 12-1/4” Hole 7-5/8”” 254 sx Class ‘G’ 12-1/4” Hole 4-1/2”327 sx Class ‘G’ 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 250’ Max Hole Angle = 67° to 73° from 7,450’ – 8,750’ Hole Angle through perf interval = 69° TREE & WELLHEAD Tree Cameron 4-1/2” 5M Wellhead FMC 11” x 4-1/2”Tubing Hanger, 4-1/2” TC-II T&B 4” CIW Type H BPV Profile GENERAL WELL INFO API: 50-029-23332-00-00 Drilled and Completed by Doyon 14 - 5/7/2007 Convert to Injector by Nabors 4ES – 9/18/2007 WARNING The needle valve between the panel and the wellhead must be closed when a SCSSV or dummy is not set in the nipple down hole. Failure to do this will allow effluents to back flow into the reservoir of the control panel causing a release into the well house. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MITs for Milne Point wells F-99 and I-13 Date:Tuesday, August 30, 2022 12:19:21 PM MPU F-99 (PTD 2061560) MPU I-13 (PTD 2010750) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Tuesday, August 30, 2022 12:14 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Christiana Chigbu <Christiana.Chigbu@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: MITs for Milne Point wells F-99 and I-13 All, Milne Point wells F-99 (PTD # 2061560) and I-13 (PTD # 2010750) and were not brought on line in time for their regularly scheduled MITs this month. They have been shut in since June 2020 and Sept 2018, respectively. Tags were hung on the well heads, they are classified as inoperable, and will be tested prior to returning to injection. Please call myself or Jerimiah Galloway (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ! ! Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, February 17, 2016 2:53 PM To: Wallace, Chris D (DOA); Alaska NS - Milne - Wellsite Supervisors Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Paul Chan; Alaska NS - Milne - Field Foreman;Anthony McConkey Subject: Shut-In Injector MPF-99 (PTD # 2061560) Due for AOGCC MIT-IA All, Milne Point water injector MPF-99 (PTD#2061560) is due for an AOGCC MIT-IA on 2/19/2016.The well is currently shut-in for reservoir management and will not be brought online in time for the test.The well will be added to the Quarterly Long Term Shut-In Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 liii.nip �l.i•k. . i.i.t, SCANNED 1 Image P~ject Well History File Co~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ ~ - ~ ~' ~j Well History File Identifier Organizing (done) RE AN C/olor Items: [~'Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ~,~.,ard iuuiuiiiiiumi DIGI AL DATA Diskettes, No. Other, No/Type: t/~ ~~~~ a~~.~~~,~ iiiiumiiuiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: (~ /s/ ~ ~ I Project Proofing BY: Maria Date: ~ IIIII~IIIIIIII VIII /s/ Scanning Preparation BY: Maria ~ x Date: 30 (~/ = + % /~`% ~_ ~~~9 TOTAL PAGES (Count does not include cover sheet) /sl Production Scanning `~ """"""" Stage 1 Page Count from Scanned File: ?~~ ~ (count does inaude cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ Q ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is com late at this point unless rescanning is required. III (I'I II I II II I I III 9 P Rescanned III 111111 VIII V III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10!6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 23, 2012 TO: Jim Re 4 , Z i Regg \ l I Z P.I. Supervisor l SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F -99 FROM: Chuck Scheve MILNE PT UNIT KR F -99 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .176a— NON Comm Well Name: MILNE PT UNIT KR F - 99 API Well Number: 50 029 - 23332 - 00 - 00 Inspector Name: Chuck Scheve - Insp Num: mitCS120222075720 Permit Number: 206 - 156 - 0 Inspection Date: 2/19/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F -99 , Type Inj. W TVD 6557 ' IA 90 2030 1970 1950 PTD 2061560 . TypeTest SPT Test psi 1639 OA 80 290 250 240 Interva 4YRTST P/F P ' Tubing 2700 2700 2700 2700 Notes: 4F-E 3 2 2. 21 Thursday, February 23, 2012 Page 1 of 1 70(0/57,0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, February 19, 2012 9:58 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher; Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M Subject: OPERABLE: Injector MPF -99 (PTD #2061560) Passed AOGCC MIT -IA Attachments: MIT ACT MPF -99, 2 -19 -12 .xls All, WAG injector MPF -99 (PTD #2061560) passed an AOGCC witnessed MIT -IA on 02/19/2012. The passing MIT -IA confirms the presence of two competent barriers in the well. The well is reclassified as Operable. A copy of the MIT is included for review. «MIT ACT MPF -99, 2 -19 -12 .xls» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 2 A f ) L Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, February 17, 2012 9:52 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M Subject: UNDER EVALUATION: MPF -99 (PTD #2061560) Passed MIT -IA Before Resuming Water Injection All, WAG injector MPF -99 (PTD #2061560) has been a long term shut that exceeded its 4 year MIT -IA required by AIO 10- B. The well passed a MIT -IA to 4000 • si • n 1_ 7/ • • - • - - •• • • • water injection. The well is reclassified as Under Evaluation until an A• C witnessed MIT -IA can be performed once the well reaches thermal stabilization. Please be aware of the potential for annular fluid expansion when bringing the well on injection. A copy of the MIT -IA is included for reference. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regoaalaska.gov; doa. aogcc.orudhoe.bavCD.alaska.aov; phoebe.brooksCcD.alaska.aov; tom.maunder alaska.00v OPERATOR: BP Exploration (Alaska), Inc. ZIl-(JI ( v FIELD / UNIT / PAD: Milne Point / MPU / F Pad DATE: 02/19/12 '� OPERATOR REP: Tom Reese AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPF -99 ° Type Inj. W TVD 6,558' Tubing 2700 2700 - 2700 2700' Interval 4 P.T.D. 2061560 Type test P Test psi 1639.5 Casing 90 2030 1970 1950 - P /F_ P Notes: 3.3 bbl's to pressure up OA 80 290 — 250 240 1 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA_ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing , P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (descnbe in notes) Form 10 -426 (Revised 06/2010) MIT ACT MPF - 99 2 - 19 - 12 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reqcMalaska.aov ; doa .aogcc.prudhoe.baW6alaska.aov; phoebe.brooksaalaska.gov; tom.maundernalaska.aov OPERATOR: BP Exploration (Alaska), Inc. - 4 i8I 701 y FIELD / UNIT / PAD: Milne Point / MPU / F Pad / `I DATE: 02/17/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPF -99 - Type Inj. N TVD - 6,558' Tubing 1050 - 1050 1050 1050 ' Interval 0 P.T.D. 2061560 Type test P Test psi ' 1639.5 Casing 740 4228 - 4165 4139 ' P/F P - Notes: 5.5 bbls to reach test pressure OA 120 480 ' 400 360 ' Pre - injection MIT -IA for BP compliance Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA _ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPU F - 99 02 - 17 - 12 410 111P bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 FEB y 20 12 Mr. Tom Maunder 156 Alaska Oil and Gas Con ©� servatlon Commission 333 West 7 Avenue f Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 12 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top lob MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 WA 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 12 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 • " MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 3Q2011 Not Operable Injector Report • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 302011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip ; 1 - Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 PTD #2050900 : Surface casing leak MPF -99 (PTD #2061560 • Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 NOT OPERABLE: MPF -99 (PTD #2061560) Cancel UIC MIT -IA until on injection Page 1 of 1 • Maunder, Thomas E (DOA) From: Reynolds, Charles (Alaska) [Charles. Reynolds ©bp.com] Sent: Friday, October 07, 2011 10:07 AM To: Reynolds, Charles (Alaska); AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Stone, Christopher; McEntyre, Scott R Subject: NOT OPERABLE: MPF -99 (PTD #2061560) Cancel UIC MIT -IA until on injection All, Injector MPF -99 (PTD #2061560) is a WAG injector due for UIC compliance testing but remains shut in. There are no plans to currently utilize the well for injection due to lack of production off take. The well has been reclassified as Not Operable until it is required for injection support. There are no downhole integrity concerns known with the well. The well has been added to the quarterly report of shut -in injectors sent to the AOGCC. The plan forward for the well is as follows: 1. Production Engineer: Notify Well Integrity Coordinator when injection is needed 2. Fullbore: MITIA pre- injection 3. Well Integrity Coordinator: Reclassify well as Under Evaluation 4. Operations: Place well on injection 5. Fullbore: AOGCC witnessed MIT -IA once thermally stable Please call Well Integrity with any questions or concerns. Charles Reynolds Filling in for... D FED � 5 2.111a sty Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/7/2011 ,..,.. ~r ~ `~ ~ ~"" ,~ ..~ry~ ;, t ~ze.,' '~ ~'~~,: ~a ~~~ MICROFILMED 6/30/201 0 DO NOT PLACE ANY N EUV MATERIAL U N D ER TH IS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilrn_Marker.doc ~ a~~~- DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061560 Well NamelNo. MILNE PT UNIT KR F-99 Operator BP EXPLORATION (ALASK/~ INC API No. 50-029-23332-00-00 MD 9270 TVD 7215 Completion Date 5/7/2007 Completion Status 1-OIL Current Status WAGIN Y REQUIRED INFORMATION v ~-.~. ~4 [ ~-- Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, GYRO, IFR/CASANDRA, NEU, DEN, GEO, TAP/NMR, CC Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / type ea~rrmt rvumoer Name ~Lo Cement Evaluation ~D D Asc Directional Survey D C Lis 14578uction/Resistivity '~ ~ pt 14578 LIS Verification ~~ Log./ Cement Evaluation D C Lis 15365~G mma Ray pt 15404 LIS Verification D C Lis 15404~Induction/Resistivity D C t+sV2DF 15405 ~duction/Resistivity 15406 LE~IS Verification C Lis 15406,/fnduction/Resistivity acme meaia No start stop ch Receives comments 5 Col 1 7725 8660 Case 2/20/2007 PB1 Cement Eval w/CBL, USIT, VDL, GR, CCL 14- Jan-2007 0 9106 Open 3/27/2007 PB1 69 9106 Open 4/4/2007 LIS Veri, GR, FET, ROP 69 9106 Open 4/4/2007 LIS Veri, GR, FET, ROP 5 Col 7600 9146 Case 6!11/2007 SCMT, CCL, GR, Pres, Temp 3-May-2007 1 7621 9157 Case 8/27/2007 USIT, CCL 74 9214 Open 9/12/2007 LIS Veri, GR, FET, ROP, NPHI, NCNT, DRHO, RHOB 74 9214 Open 9/12/2007 LIS Veri, GR, FET, ROP, NPHI, NCNT, DRHO, RHOB 74 9214 Open 9/12/2007 LIS Veri, GR, FET, ROP, NPHI, NCNT, DRHO, RHOB w/Graphics PDF and EMF 74 8674 Open 9/12/2007 P61 LIS Veri, GR, FET, ROP 74 8674 Open 9/12/2007 P61 LIS Veri, GR, FET, ROP DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061560 Well Name/No. MILNE PT UNIT KR F-99 Operator BP EXPLORATION (ALASKI-) INC API No. 50-029-23332-00-00 mu yuu i vv i~ ~.ompieuon uate ~n~tuci ~.ompieuon ataius i-vim ~.uncm Maws vvr~uu~ u~~. r D C Lis 15407 nduction/Resistivity 74 8674 Open 9/12/2007 PB1 LIS Veri, GR, FET, ROP w/Graphics PDF and EMF Neutron 25 Col $~~o ~t9~' ~97~270 Open 6/18/2008 MD DGR, CTN, ALD og Neutron 25 Col 2ti ~' 4~~' ~Sf~ Open 6/18/2008 TVD DGR, CTN, ALD Log Gamma Ray 25 Col 107 7251 Open 6/18/2008 TVDDGR, GR g Induction/Resistivity 25 Col 107 9270 Open 6/18/2008 MD DGR, EWR og _ Induction/Resistivity 25 Col 107 7143 Open 6/18/2008 TVD DGR,EWR ~~~~`~, ~''~ ```~ndtretiefl/Ftesistivity-" ~ 25-~6r' 1(1,7 4270 n-~P^ ~~^ai~nnQ Mn nro c~n~n ono_ og Induction/Resistivity ~ '~ ~ 25 Col 107 7143 Open 6/18/2008 TVDD DGR, EWR, ROP C Exc Directional Survey 0 9270 Open 10/8/2008 pt Directional Survey 0 9270 Open 10/8/2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORpqM~qATION Well Cored? K.~/ N ~kScJ, i ~~; ~,~ l'~e.~e. r:~ Daily History Received? ~j Chips Received? l~/ N Formation Tops ~N Analysis Y Received? Comments: Compliance Reviewed By: Date: ~°'~~~'~ • • • HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-99PB1 Dear Christine Mahnken 09-Mar-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey 34.30' MD 0.00' MD (if applicable) Projected Survey: 9,106.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 _ _ Date 13 .ws`'~' Signed (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) 6-Oct-08 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-99 Dear Christine Mahnken: Enclosed are 2 survey hard copy(s) and one disk. MPF-99 Tie-on Survey: 8602.50' MD Window Survey: 8690.00' MD Projected Survey: 9270.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 a o ~~~ _____~ Date ~ ~>~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~ - ~.~ ~ ~ ~ WELL L®G TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPF-99+PB 1 June 17, 2008 AK-MW-SO43S43 MPF-99+PB1: 2" x S" MD Resistivity & Gamma Ray Logs: 1 Color Logs SO-029-23332-00,70 2" x S" TVD Resistivity & Gamma Ray Logs: 1 Color Logs SO-029-23332-00,70 2" x S" MD Neutron & Density Logs: 1 Color Logs SO-029-23332-00 2" x S" TVD Neutron & Density Logs: 1 Color Logs SO-029-23332-00 Digital Log Images: 1 CD Rom SO-029-23332-00,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage; Alaska 99S 18 Date: Si ned: '~ v~~ c7UCo-~~ Well Name' MILNE PT UNIT KR F-99 Insp Num: mitLG07 102 3 1 6092 1 Rel Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-23332-00-00 Permit Number: 206-156-0 P.1. Suprv ~~-- Comm nspector Name: Lou Grimaldi Inspection Date: 10/28/2007 ~ Packers Depth Pretest Initizl 15 Min. 30 Min. 45 Min. 60 Min. Well T e In . ~!' ._ essa IA azo aooo ~' 3sso saso F-99 YP J ; TVD ~ - - _. _ _ ._ __ - P T 2oe~5eo !TypeTest SPT `;~ Test psi aooo OA so Aso iso i2o _ _a_-.._ ! - - _ ___ _ - INITAL P / TUbin ' 2960 29R5 2975 ! 2975 Interval P[F __ . g _ _ ~ -----__.- :. _ _ __ _ Notes' 8.5 bbl's pumped, good test. - Monday. October 29, 2007 Page I of I • ~ Page 1 of 1 Regg, James B (DOA) ~ Zp~., - ~~~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, November 06, 2007 11:44 PM To: Regg, James B (DOA) ~~~ ~~~~~o~ Cc: NSU, ADW Well Integrity Engineer ~ Subject: RE: MPU F-99 Attachments: MIT MPU F-99 10-28-07.x1s; MPF-99 DIMS 09-19-07.pdf; MIT MPU MPF-99 09-19-07.x1s Hi Jim. Here is a copy of the DIMS report for 09-19-07 on MPF-99 (PTD 2061560}. It confiirms that two separate MITs were conducted, aMIT-T and a MIT-IA. In attempting to fill out a M(T form to correctly document these tests, I will have trouble filling out the complete form due to not how the tubing, IA; and OA reacted during the tests. I can track dawn the charts but that will show only some of the data. I have included a draft for reference. The AOGCC witnessed a post initial injection MIT-IA on 10128107. Please !et us know if this is enough infiarmation or if you would like us to track dawn a copy ofi the charts as well. Thank you for the help, Anna Dube From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, October 25, 2007 11:59 AM To: NSU, ADW Well Integrity Engineer Subject: MPU F-99 Please clarify the MIT done on MPU F-99 (PTD 2061560) dated 9/19/2007. The test results sent to us by email from Mike Hefley (9/20/07) indicated a CMIT TxIA was performed and the test reason was for a conversion from producer to WAG injection. The confusion comes from why the CMIT and not a traditional MITIA. I understood that this well may actually have been tested with separate MITs (MITT and MITIA) but that was not reflected on the form; if so, it would be corrected; and, if the separate tests could not be confirmed, an MITIA would be tested and the Commission notified for an opportunity to witness. I'd appreciate it if you could check into this. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 11 /7/2007 • i STATE OF ALASKA ALASKA OIL ANQ GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Milne Point /MPU / F Pad 10/28/07 Mel Iveson Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. We MPF-99 Type Inj. W TVD 6558' Tubing 2960 2985 2975 2975 Interval I P.T.D. 0 Type test P Test psi 4000 Casing 420 4000 3880 3850 P/F P Notes: MIT-IA post initial injection OA 30 130 130 120 8.5 bbls Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPU F-99 10-28-07.x1s • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Milne Point /MPU / F-Pad DATE: 09!19/07 OPERATOR REP: Mike Hefley AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well MPF-99 Type Inj. N TVD 7511 Tubing 0 4000 Inierval T P.T.D. 206-156 Type test P Test psi 1878 Casing 0 300 P/F P Notes: AOGCC representative declined to witness OA 250 250 MIT-T during new well completion Well MPF-99 Type Inj. N TVD 7511 Tubing 1500 Interval T P.T.D. 206-156 Type test P Test psi 1878 Casing 4000 P/F P Notes: AOGCC representative declined to witness OA MIT-T during new well completion Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPU MPF-99 09-19-07.x1s • • ----- - - _ - -- BPAMERICA ' Daily Operations Report Page 1 of 3I Operator: BP AMERICA Rig: NABORS 4ES Report: 7 Well: MPF-99 Event: WORKOVER Date: 9/19/2007 Field: MILNE POINT Well Type: DEVELOPMENT - - - -. Current WeN Status Depth MU: (tt) Casing Size: Costs in: USD Rig Accept: 09:00 9/13/2007 Est. TVD: (ft) Casing (MD): Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 12/13/2006 Auth Depth: (ft) Next Casing (MD): (ft) Daily Well: 286,745 WX Date: Hole Size: 6.750 (in) Next Casing (TVD) : (ft) Cum. Well: 699,273 Elev Ref: ROTARY KELLY BUSHIN DOL/DFS/Target: 1/6.00 Liner Size: 4.500 (in) Geologist: Liner (MD): 9,270.0 (ft) KB Elev: 45.80 (ft) Engineer: Howard West Liner Top (MD): 7,652.0 (ft) Tot. Personnel: 25 Supervisor: Hefley / Aubert Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Current Status: Rig released @ 06:00 hrs 9/20/2007. 24hr Summary: Made cable and control line connections to tubing hanger. Circulated in corrosion inhibitor and freeze protected IA. Set packer and performed MITs to 4000 psi. Set TWC, ND BOPE. NU and tested tree. Pulled TWC, set BPV. Released rig. 24hr Forecast: MIRU on MPF-57A. Comments: No accidents. No incidents. No spills. HSE & Well Control Days Since Last DAFWt;: 4s[ Ali Free Days: ti Last Csg Test Press.: 4,000 (psi) Last Envir. Incident: 3/8/2007 Last BOP Press. Test: 9/14/2007 Next BOP Press. Test: 9/21/2007 Last Safety Meeting: 9/16/2007 Last Spi ll Drill: 9/15/2007 No. Stop Cards: Regulatory Agency Insp: Non-compliance Issued: Pump _ Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) !Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() MAASSP: (psi) i Test Pressure: (psi) ~ j Kick Tolerance: (ppg) ~ I ' Kick Volume: (bbp ~ I __ _._-- Operational Parameters _____--- ROP Daily: Rotating Weignt: Daily Bit Hrs: (hr) Pump Status - Gnl6ng and Riser ROP Cum.: Pick Up Wt.: Daily Sliding Hrs:0.00 (hr) Pump Type Eff Stroke~Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: () () () () WOB (max): Circ. Rate Riser: _ _ II -- -- RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ftlmin) L RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min) Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: (ft/min) Torq. off Bottom: Jar Hrs since Inspect: (hr) ~, -- ---__ - Drilling Fluid --- Type: WATER/BRINE 10 sec gels: (Ib/100ft~) Ca: (mg/L) E8: (mV) Time/Loc: /SUC 10 min gels: (Ib/100ftz) i K+: (mg/L) Solids: (%) Depth: (ft) Fluid Loss: (cc/30min) ~ CaCl2: (%) Oil: (%) Temp: 90 (°F) HTHP Temp: (°F) ~I NaCI: (%) Water. (%) Density: 8.90 (ppg) HTHP WL: (cc/30min)' CI-: (mg/L) OillWater: / l Funnel Visc.: 26 (s/qt) Cake: i Sand: (%) Daily Cuttings: (bbl) (/32") ECD: (ppg) MBT: (ppb) HGS: (ppb) Cum. Cuttings: (bbl) PV: (cp) Lime: (ppb) LGS: (ppb) Lost Downhole: (bbl) YP: (Ib/100ftz) PM: (m L) Pf/Mf: / (mUmL) Lost Surface: (bbl) PH= Operations Summary.. From-To Hrs Phase Task Activity Code NPT Operation Op. Depth ~ (hr) !-_ ~~ 00:00-01:00 !, 1.00 RUNCM RUNCO MU P Attached control lines to tubing hanger. Tested control lines to 5000 '~ !psi for 10 minutes. 01:00-01:30 li 0.50 RUNCM RUNCO RD P 'i ! RD control line spools and tubing handling equipment. 01:30-06:00 4.50 RUNCM RUNCO MU ~P - -- _ Spliced heat trace cable to penetrator. MU heat trace cable to ~, , wellhead penetrator. Land tubing hanger. RILDS. PUW = 96K, SOW ' = 76K Printed: 9/20/2007 5:32:50 AM • BP AMERICA Daily nnPratinns Rennrt Pane 2 of 31 Operator: BP AMERICA Rig: NABORS 4ES Report: 7 Well: MPF-99 Event: WORKOVER Date: 9/19/2007 Field: MILNE POINT Well Type: DEVELOPMENT -- - -- '~ Operatio_n_s,.Summary From-To Hrs :Phase Task i Activity Code NPT Operation Op. Depth (hr} j I 06:00-07:00 1.00 RUNCM RUNCO PLUG P ,Dry rod set TWC. P/T TWC from below to 1000-psi. 07:00-11:30 4.50 RUNCM RUNCO PLUG P I P UMU Lubricator. Pull TWC. UD lubricator. ~ ~ 11:30-14:30 3.00 RUNCM RUNCO CIRREV P ' ~ Ho ok up circulating lines. Reverse circulate 120-Bbls. 120E SW @ 3.0-BPM @ 190-PSI down IA taking returns to Tiger Tank. Reverse I , circulate 290-Bbls. 120E corrosion inhibited SW down IA @ 3.0-BPM @ 190-PSI taking returns to Tiger Tank. MIRU LRS. 14:30-14:45 0.25 RUNC RUNCO SAFETY - i r P PJSM -All crew and LRS crew. Pump diesel freeze protect. --- - 14:45-1(1:00 1.25 RUNCM~ RUNCO CIRREV I P LRS reverse circulate 140-Bbls of 120E diesel down IA to freeze -- -- i protect well @ 2.0-BPM @ 300-PSI. 16:00-18:00 2.00 RUNCM~ RUNCO PKRST P - Drop ball & rod w%roller stem. Allow ball & rod to fall - 20 minutes. I Bring tubing pressure up to 4000-PSI for 30 charted minutes while j observing IA pressure. IAP = 300-PSI, OAP = 250-PSI. Bled tubing ~ off to 1500-PSI and LRS increased IA pressure to 4000-PSI for 30 charted minutes. 18:00-18:30 0.50 RUNC RUNCO SAFETY PP~ Held crew change and PJSM. Bled MIT pressures and sucked out fluid from stack. 18:30-19:30 1.00 RUNCM RUNCO TSTPRS P ~ Set TWC and tested from above to 1000 psi for 10 minutes. RD lines. - 19:30-21 00 j 1.50- I RUNCM RUNCO ND P j -. -_--- ND BOPE. 21:00-00:00 I 3.00 ~UNCM RUNCO NU P ( NU adapter Flange and tested void to 5000 psi. NU and tested tree to I i j 5000 psi. MPU Pad Operator approved tree orientation. --- _ -- 06:00 Update _ From-To i Hrs ~ Phase I Task Activity Code NPT i Operation ~ (hr) -- ... - _ 00 0 02 00 2.00 RUNCM RUNCO RU P ; RU and tested lubricator. Attempted to pull TWC. Could not screw - -- ~ ~ ,into TWC. 02:00-04:00 2.00 RUNCM RUNCO RD _ --- - - N ~ SEAL ; PU lubricator. Cleaned grease from tree. Lubricator rod not I I centralized over TWC threads. Screwed rod into TWC and reset - _ - ~ .lubricator. Pulled TWC, PU lubricator. 04:00-05 00 1.00 RUNCM'RUNCO SETOTR -- --- P j Reset and tested habricator. Set BPV. 05:00-06.00 1.00 _ _'__- RUNC~M,RUNCO RD P ~ ~ Secured tree and cellar. Released rig @ 06:00 hrs, 6!20/2007. I Mud Log Information Formation KUPARUK Fnrm Tn~ MD. (ft) ~ Bkgrnd Gas Trir ~-;as Lithology SAND Conn. Gas Pon> Press (ppg) _ Materials /Consumption _ _ __ _ Item Uni;~< Usage On Hand Item Un~t_~ US ,~-, On Hand DIESEL GAL 911 5670 I -- __ _. __ _ - - Personnel Company I No . Hours Company No. Hours mpany X10. Hours Co _ __ _ _ __ BP 2 NABORS 2 NABORS 20 DOYON 1 Cumulative __ - Phase Breakdown - --- _ __ Planned _ _ _ _ T Change of Scope Total Total Cost Phase - Prod % Total t o NP o otal -- -- 0 WOW /o Total -- - 0 NPT % Total ~ N/OW % Total Prod /o otal Hours USD DECOMP ° 15.00 100 0 /o i I - - - ---- 15.001 87,159.00 PRE 8.00 100.0% ! % 8.OOi 22,960.00 CLEAN 21.50 100.0%~ ! I 21.50 60,053.00 I 32 50 184 434.00 P ° _ L 63 00 344 667.00 ~ OTALS __ o - o 140 00 100.0 /0 0.00 0.0 /o 0 0.00 0.0 /0 0 _.-- 0.00 0.0 /o 'I 0.00 0a)% I 0.00 0.0% __ ~"--- -_.-- 140 00 , 699 273.00 Printed: 9/20/2007 5:32:50 AM • BP AMERICA Daily Operations Report Page ~ of 3 Printed: 9/20/2007 5:32:50 AM MEMORANDUM TO: JimRegg ~~~~~ t~~2.~r;~7 P.I. Supervisor Z FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 29, 2007 StiBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-99 MILNE PT UNIT KR F-99 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~- Comm Well Name: MILNE PT UNIT KR F-99 Insp Num: mitLG071028160921 Rel Insp Num: API Well Number: 50-029-23332-00-00 Permit Number: 206-156-0 Inspector Name: Lou Grimaldi Inspection Date: Ioi28i2oo7 -~ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F-99 TType Iris. ~ W ~ TVD ~ 6558 ~ IA 420 ~ 4000 3880 i 3850 I P.T. t206li60 iTyp T SPT i Test psi ~ 4000 ~ QA " 30 I 130 I~ 130 0 ~ - - Interval IMTAL P~F P -'' Tubing !, 2960 ~~ 2985 I 2975 ~ 2975 I i Notes: 8.5 bbl's pumped, good test. Monday, October 29, 2007 Page I of 1 ~ ~ Regg, James B (DOA) Page 1 of 1 From: Regg, James B (DOA) , i ~~Z5~D7 Sent: Thursday, October 25, 2007 11:59 AM ] 5 To: 'NSU, ADW Well Integrity Engineer' Subject: MPU F-99 Please clarify the MIT done on MPU F-99 (PTD 2061560) dated 9/19/2007. The test results sent to us by email from Mike Hefley (9/20/07) indicated a CMIT TxIA was performed and the test reason was for a conversion from producer to WAG injection. The confusion comes from why the CMIT and not a traditional MITIA. I understood that this well may actually have been tested with separate MITs (MITT and MITIA) but that was not reflected on the form; if so, it would be corrected; and, if the separate tests could not be confirmed, an MITIA would be tested and the Commission notified for an opportunity to witness. I'd appreciate it if you could check into this. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~ ~~SP ~ !ut.'~t LCU~Iu Z~f(octi`jZi ,'~~- id ~ ~ ~~7 10/25/2007 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ECEI`JED ~ ~,, ocT 1 s zoos issian 1. Operations Performed: ^ ^ AtChOrage Abandon Repair Well ^ Plug Perforations ^ Stimulate ^ Re-inter Suspended Welt ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Convert to WAG Injector ®Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-156 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23332-00-00 7. KB Elevation (ft): 45 81' r 9• Well Name and Number: . MPF-99i 8. Property Designation: 10. Field /Pool(s): ADL 025509 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9270 ~ feet true vertical 7215 feet Plugs (measured) None Effective depth: measured 9225 feet Junk (measured) None true vertical 7198 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 4858' 13-3/8" 4893' 4608' 4930 2270 Intermediate Production 7922' 9-5/8" 7954' 6717' 6870 4760 Liner 895' 7-5/8" 7775' - 8670' 6653' - 6989' 6890 4790 Liner 1618' 4-1/2" 7652' - 9270' 6608' - 7215' 8430 7500 Perforation Depth MD (ft): 8844' - 9090' Perforation Depth TVD (ft): 7056' - 7146' 4-1/2", 12.6# L-80 7579' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker S-3 Packer 7511' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~ ~~~ ~ ~ 2~~7 Treatment description including volumes used and final pressure: f~ lT I~c,~ ~.Q~~ d ~ ~ ~~'U~ 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: [] Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 307-288 Printed Name Sondra Stewman Title Drilling Technologist Sign ure r ~~ - - Prepared By Name/Number: Phone 564-5743 Date ~` ~~ Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ("1 ~ ~ ~ ~ Submit Original Only K `D~~--~ Tree: Cameron 4 1/2 " - 5M ~'t`eilhead FPAC 11" x 4 1!2" Tbg. Hanger, 4 1/?_" TC-ii T & B ~=` CIW - Type H BPV profile 20", 92 ppf, H-40 Welded & 120` Insulated 13 3/8", 68 ppf, L-80, BTC 4893` KOP ~cil 250` t~1ax. hole angle = 67 to 70 deg. f; 7450' to 8750' Hole angle thru' perfs = 69 deg. 4 1!2" 12.6#, L-80, TC-II (Tbg & Lnr) (Drift ID= 3.833" ID, Cap = .0152 bpf) 9 5!8" 47#, L-80, BTC casing (Drift ID = 8.525, Cap w/ tbg = .0652 bpf) 9 5/8" x 4 1/2" Liner Top 7652 9 5/8" x 7 5/8" Liner Top 7775 Perforation Summary Ref log: Size SPF Interval (TVD) 2 7/8" 6 8844` - 8864' 7056' - i 2 7/8" 6 8894` - 8934' 7075` - 7 2 7/8" 6 8980` - 9090' 7106` - 7 DATE REV. BY COMMENTS 05-21-07 L. Hulme Drilled and completed -Doyon 14 09-18-07 L. Hulme Conversion to Injector -Nabors 4ES Orig. lev. = 45.8' Doyon 14 Orig. to BF = 29.73' Doyon 14 .S `HXO' SCSSSV Nipple 2108` ;entrilift Heat Trace to 3200` S `X' Nipple 3.813 Pkg ID 7491' iker S-3 Packer 7511' S `X' Nipple 3.813 Pkg ID 7536' S `XN' Nipple 3.813 Pkg ID 7557` 725 No-Go ID) _EG 7579` ~/8", 47 ppf, L-80, BTC 7954` ' ", 29.7 ppf, L-80, Hyd 513 8670` I 12.6 ppf, L-80, IBT-M ~~ HES Float Collar (PBTD) V I HES Shoe MILNE POINT UNIT WELL MPF-99 API NO: 50-029-23332-00 MPF-99 BP AMERICA Page 1 of 5 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date .From - To I Hours Task Code NPT 9/13/2007 ~ 01:00 - 03:00 ~ 2.00 ~ CONS (P 03:00 - 05:00 2.00 ~ MOB 05:00 - 09:00 I 4.001 RIGU 09:00 - 10:00 I 1.001 RIGU 10:00 - 14:30 I 4.501 KILL 14:30 - 17:00 2.501 KILL 17:00 - 17:30 I 0.501 KILL 17:30 - 18:00 0.50 DHB 18:00 - 18:30 0.50 DHB 18:30 - 19:30 1.00 WHSUR 19:30 - 21:30 2.00 WHSUR 21:30 - 00:00 2.50 WHSUR 19/14/2007 100:00 - 02:30 I 2.501 WHSUR 02:30 - 04:00 I 1.501 WHSUR P P P P P P P P P P P Start: 9/13/2007 Rig Release: 9/20/2007 Rig Number: Spud Date: 12/13/2006 End: Phase , Description of Operations PRE Prepare to move to MPF-99. -Lower & scope down derrick. PRE R/D and mobilise to move to MPF-99. -While moving MPU #13 Green Flowback tank w/ PEAK bed truck, sling parted and dropped tank. PRE MIRU on MPF-99. -Notify AOGCC of upcoming BOPE testing -Lou Grimaldi - @ 07:30. -Call Veco Dispatch to send truck to move dropped tank and 1 replace with another one for killing the well. DECOMP Accept Rig @ 09:00. Hold Pre-Well Review. -Reviewed past well and went over RWO procedure for upcoming work. PJSM. Rig up hardlines to Tree. -Load pits w/ Seawater. Prep for Well Kill. DECOMP Wait for new Flowback tank. -Tank that was dropped, taken out of service. -Continue to RU and prep for well kill operations. ~ -RU lubricator, pressure test to 1000 psi. '-Pull BPV to WHP's of T/IA/OA - 300/160/40 psi. DECOMP Test pump and lines to tiger tank to 500 psi. Close choke and test lines to 2500 psi. Open IA and bleed gas to tiger tank. Pump 45 bbls Seawater @ 5 bpm, catch fluid after 23 bbls. -Close choke and bullhead 45 bbls to formation @ 4 bpm / 600 psi. -Open Choke and circulate 700 bbls of 8.5 ppg Seawater @ 5 bpm / 1300 psi on tubing, IA @ 300 psi and less. -Fluid returns to surface after 76 bbls pumped (Crude returns). No water. After 300 bbls of crude returns, started getting water / crude mixture returns. Circulate until 8.5 ppg Seawater returns received from IA. -Pumped 700 bbls, hauled off 540 bbls. Total losses= 160 bbls of Seawater. DECOMP Shut down pumping. Tubing and IA on vacuum. -Flow check well for 20 minutes. Tubing and IA still on vacuum. DECOMP P/U Tee Bar. Dry rod in TWC._ UD Tee Bar. DECOMP Test TWC @ 1000 psi / 10 min from above. -Test TWC @ 1500 si / 4 b m from below. DECOMP Bleed Hanger void. N/D Tree. DECOMP ,Shoot IA fluid level @ 110 ft. N/U Adaptor flange. N/U BOPE. DECOMP ~ R/U & test Choke manifold @ 250 low psi / 4000 high psi. -AOGCC right to witness ROPE testing waived by Lou Grimaldi. DECOMP R/U & test BOPS 250 psi low ! 4000 psi high. -Test Annular to 3500 psi. -Test jts used= 2 7/8", 3 1/2" & 4 1/2". -PASS. -Koomey test to full close, 3000 psi to 1700 psi. -Pressure up to 1900 psi in 43 secs. ' -Pressure up to full 3000 psi 2 min, 50 secs. DECOMP Reshoot IA fluid level @ 400 ft. -P/U OPSO-Lopso. R/U lubricator & test to 1000 psi. -T/I/O = 0, 0, 0 psi. Printed: 10/3/2007 2:20:14 PM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT 'I _.._ __ _ _ _ _ _ ~ I 9/14/2007 ! 02:30 - 04:00 1.50 WHSUR 04:00 - 05:00 1.00 PULL 05:00 - 06:00 I 1.001 PULL 9/15!2007 06:00 - 12:00 I 6.00! PULL 12:00 - 15:00 I 3.001 PULL 15:00 - 16:00 1.00 CLEAN 16:00 - 16:30 0.50 CLEAN 16:30 - 17:00 0.50 CLEAN 17:00 - 19:30 2.50 CLEAN 19:30 - 20:30 1.00 CLEAN 20:30 - 00:00 3.50 CLEAN 00:00 - 01:30 I 1.501 CLEAN I P 01:30 - 02:30 1.00 CLEAN P 02:30 - 07:00 4.501 CLEAN P 07:00 - 09:30 I 2.501 CLEAN I P 09:30 - 10:30 I 1.001 CLEAN I P 10:30 - 14:30 4.001 CLEAN P 14:30 - 16:00 I 1.501 CLEAN I P 16:00 - 20:00 I 4.001 CLEAN i P 20:00 - 20:30 I 0.501 CLEAN I P Start: 9/13/2007 Rig Release: 9/20/2007 Rig Number: Page2of5~ Spud Date: 12/13/2006 End: Phase Description of Operations DECOMP -Pull TWC. R/U to Pull ESP completion assy. DECOMP P/U & M/U landing jt, TIW valve and XO for Tbg Hanger. -Back out Lock down screws. -Screw into Tbg Hanger 8 1/2 turns. -Pull Tbg Hanger to floor w/ 62K PU wt. UD Tbg Hanger. DECOMP Test ESP. Pull ESP cable over sheave. -Attach cable to Spooler. DECOMP M/U TIW valve. Load IA w/ 48 bbls of Seawater. -Flowcheck well, fluid Level dropping. -Open TIW valve and remove from Tbg. -POH standing back 2 7/8" Tbg in Derrick. -Continuous hole fill as POH. -Losses @ -12 bbls / Hr. DECOMP Drain, test & UD ESP assembly. Flush & VD shroud. -Losses @ -7 bbls / Hr. CLEAN Clean and clear rig floor. Prep for running FCO BHA. CLEAN Drain Stack. Install 9" I.D. wear ring. CLEAN R/U 2 7/8" PAC handling equipment. CLEAN P/U & M/U 2 7/8" PAC Muleshoe on 61 jts of 2 7/8" PAC DP. -Maintain continous hole fill. CLEAN Adjust brakes. Service Rig. CLEAN RIH w/ 79 stands of 2 7/8" tubing from Derrick. -Maintain continuous hole fill while RIH. -Tag fill @ 9,135' and (77 stds & 1 single). CLEAN Attempt to reverse circulate and wash down from 9,135' md. -3 bpm / 700 psi. Losses @ 6 bph while circulating. -Attempt to wash & circulate the long way. -5 bpm / 800 psi. CLEAN Reverse circulate 2 Tbg volumes. -Losses @ 10 bph while circulating. CLEAN POH w/ 2 7/8" FCO assembly, standing 2 7/8" EUE tbg in Derrick. CLEAN Continue POOH, laying down 2 7/8" PAC DP. -Losses @ 2 bph as POOH. CLEAN Clear Rig floor of PAC handling equipment. -P/U & M/U 9 5/8" Csg scraper w/ 10' - 2 7/8" pup w/ 4' muleshoe. CLEAN Flowcheck well. -RIH w/ 2 7/8" Tbg & 9 5/8" Csg scraper (8" O.D.). - Assembly run in on 79 stands and 1 single (from completion which was pulled). CLEAN P/U 6 additionai joints of 2 7/8" tubing. P/U wt of 53K, S/O wt of 42K. -P/U single #7 and 19' in on #8, tag TOL @ 7,659' MD. -Laydown single of Tbg. Work scraper across packer setting depth of 7,600' md. -M/U head pin and reverse circulate. -Pumped 150 bbls @ 4 bpm / 600 psi (3 tubing vollumes until returns clean). -Flowcheck well, 3 bbls lost during reverse circulation. CLEAN POH standing back 2 7/8" Tbg in Derrick. -losses @ 0.5 bph CLEAN UD Csg scraper BHA. Printed: 10/3/2007 2:20:14 PM BP AMERICA Page 3 of 5 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: WORKOVER Start: 9/13/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/20/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code'. NPT ' Phase Description of Operations . 9/15/2007 ! 20:30 - 21:30 I 1.00 I~ CLEAN P CLEAN _ _ _ -.__--- Clean & clear Rig floor. 21:30 - 00:00 ~ ~ ZONISO 2.50 P OTHCMP M/U RTTS. RIH on 2 7/8" Tbg. 9/16/2007 i 00:00 - 01:30 ! 1.50 i ZONISO P OTHCMP Continue to RIH w/ RTTS on 2 7/8" Tbg. 01:30 - 03:00 1.50 03:00 - 03:30 0.50 03:30 - 06:00 2.50 06:00 - 14:00 8.00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 18:00 ZONISO P ZONISO P ZONISO P ZONISO I P 0.501 ZONISO' 0.50 ~ PERFO P 0.50!, PERFO 1.501 PERFO 1.00 ~ PERFO P 18:00 - 18:30 ! 0.50! PERFOB~ P 18:30 - 19:00 i 0.501 PERFO~ P 19:00 - 22:00 i 3.00! PERFO P 22:00 - 23:00 I 1.001 PERFOBI P 23:00 - 23:30 i 0.501 PERFOB 23:30 - 00:00 0.50 ~ PERFO P 9/17/2007 00:00 - 01:00 1.00 i PERFOB P 01:00 - 03:30 2.501 PERFO P 03:30 - 04:30 ! 1.00 PERFOB P 04:30 - 06:00 1 1.50 PERFO ~ P 06:00 - 0730 1.50 PERFO~ P -Tag liner top @ 7,659' md. -P/U to 7,640' md. Up wt= 53K, SOW= 41 K. OTHCMP Set RTTS. -Chart & test 9 5/8" Cs to 4000 si / 30 minutes -PASS. OTHCMP Unseat RTTS. 15K overpull to unseat. -Short trip RTTS +/- 20 ft. Flowcheck well. No losses. -R/U to displace to clean NaCI brine. OTHCMP Displace wellbore over to clean /filtered 8.9 ppg NaCI. -Circulate 600 bbls @ 6 bpm / 1250 psi, load pits w/ 290 bbls. OTHCMP Crew change. PJSM. Flowcheck well, fluid falling in annulus. -POOH laying down 2 7/8" Tbg. w/ double displacement. - Losses @ -3 bbls/Hr. OTHCMP BOLD RTTS. OTHCMP Drain Stack. Pull wear ring. OTHCMP Adjust brakes. Remove pitcher nipple. OTHCMP N/D flow nipples. N/U shooting flange. OTHCMP PJSM w/ SLB. R/U SLB: -10' Lubricator extentsion, Wire Line BOPE. - Lubricator &HWLP packoffs for pressure control equipment. OTHCMP PJSM w/ :WSL, TP, SLB & Rig crew. OTHCMP Test HWLP packoffs & Lubricatorto 1000 psi -PASS. OTHCMP P/U Gun # 1. Arm Gun. -RIH Tag bottom, complete Tie-in Log. -Fire Gun & perf interval 9,050' md- 9,090' md. -(9,090- and = 7,146' tvd). -Monitor well 5 minutes. Pull up above Liner top. OTHCMP Shut in well. -Monitor wellbore for 30 minutes. -Losses @ 5 bpm while shut in. OTHCMP PJSM w/: WSL, TP, RLG, & Rig crew. -Discuss incident (derrickman receiving stitches). OTHCMP Redress tools. R/U & Arm Gun # 2. OTHCMP Continue to redress tools and arm Gun # 2. OTHCMP RIH w! Gun # 2. Fill hole w/ 4.5 bbls. -Run 2 7/8" 6 SPF Omega-powerjet gun. -Tag bottom @ 9,135' md. Tie-in to Log. -Pick up and perfiorate f/ 9 010' and to 9.050' and / 7.131' tvd. -Monitor well for 5 minutes, slight vacuum. POH above liner top. OTHCMP Shut in well. Monitor 15 minutes. -Losses @ 2 bph. -Losses during Perf run & perforating = 16 bbls. -POH w/ Gun # 2. OTHCMP UD Gun # 2. Redress tools. I -M/U Gun # 3.- 30' of 2 7/8" 6 spf, Omega-powerjet guns. OTHCMP i RIH w/Gun # 3 and tag bottom. -E-line corrected bottom of 9,112' md. -Make correlation passes. -Correct to proper depth using GR/CCL perf record dated May 3, 2007. Printed: 10/3/2007 2:20:14 PM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig. Name: NABOBS 4ES Date From - To Hours ~ Task Code' NPT II 9/17/200706:00 - 07:30 ~ 1.50, PERFO P Start: 9/13/2007 Rig Release: 9/20/2007 Rig Number: Page 4 of 5 Spud Date: 12/13/2006 End: Phase Description of Operations OTHCMP -Position guns, load hole w/ 5 bbls. -Perforate 8,980' - 9,010' and / 7,116' tvd. -Well on slight vacuum. POOH into 9 5/8" Csg and monitor well. 07:30 - 08:00 0.50' PERFO P OTHCMP POH w/ SLB e-line Gun # 3. 08:00 - 09:00 , 1.00 PERFO P OTHCMP Rig down SLB. Clean and clear rig floor. 09:00 - 10:30 i 1.50' RUNCOM P RUNCMP Safety Stand down meeting with Rig Crew. I ~ -Discuss incident which occurred with hatch cover in shaker 'j room. !I -Discuss Safety programs in place. -Discuss personal committment to Safety. -Discuss completion procedure. 10:30 - 12:00 1.501 BUNCO P RUNCMP N/D shooting flange. NU pitcher nipple. Rig up floor to run completion. '~, -Contact Bob Noble w/ AOGCC and notify of upcoming MIT-IA. 12:00 - 15:00 I 3.00 15:00 - 16:00 I 1.00 16:00 - 23:30 7.50 23:30 - 00:00 0.50 -Will give AOGCC 2 hours notice. RUNCMP Open blinds and load hole w/ 6 bbls of 8.9 #/gal brine. -Losses @ -1 bbl/Hr. Continue to R/U floor for completion. -Drift HXO nipple and sleeve w/ HES 1 7/8" ball-rod (on roller stem). -ID of Sleeve = 2.62", OD of rollers on stem = 2.22" -Load pipe shed. PJSM with Rig crew, Baker, Nabors Csg. RUNCMP P/U & M/U WLEG and XN / X nipples. -Baker-Lok all connections below Baker S-3 9 5/8" x 4 1/2" packer. -RIH w/ 4 1/2" 12.6#/ft, TCII tubing. -Torqued to 3850 ft-Ibs. -Torque turn Svc & Jet Lube Seal pipe dope utilized. -Losses @ -1 bbl/Hr. RUNCMP P/U &RIH w/ 4 1/2" TC II Tbg injection string. RUNCMP PJSM @ jt # 105 of 4 1/2" Tbg run. -Discuss R/U & running of Heat trace. 9/18/2007 100:00 - 02:30 I 2.50 02:30 - 06:00 I 3.50 I R 06:00 - 09:00 3.00 RUNCOMP I III 09:00 - 10:00 1.00 ~ BUNCO i P i 10:00 - 18:00 8.00'' RUNCOI~iP i I ; RUNCMP R/U Rig floor to run Heat Tracer and Cannon clamps. -Load Flat guards w/ Bands onto floor for Heat Trace. -Pull Heat Tracer over Sheave. -Test Heat Tracer.-Start Heat tracer on Pin end of jt # 106. Heat Trace is used. There is an armor repair @ 500' from bottom (+/- 2690') from end, and a splice @ 1290' from bottom (+/- 1900' md) RUNCMP P/U and RIH w/ 4 1/2" Tbg, Heat Tracer and Cannon clamps. -Losses since Midnight = 7 bbls. -1 Bbl/Hr. RUNCMP Crew change. PJSM discussing completion operations and hazards. Notify AOGCC of upcoming MIT-IA. Bob Noble waived the State's right to witness on MPF-99. 24 hour notice to AOGCC for upcoming BOPE test on MPF-57. RUNCMP 132 joints in hole. RU floor w! SLB spooling unit etc. PUMU HXO nipple. MU dual SS, 1/4" control lines to nipple, test to 5000 psi for 10 minutes. RUNCMP Continue RIH w/ completion: Heat Trace, dual 1/4"SS control and balance line from HXO nipple, flat guards, and Cannon cross coupling clamps. Losses @ -1 Bbl/Hr. Printed: 10/3/2007 2:20:74 PM ~ ! BP AMERICA Page 5 of 5 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: WORKOVER Start: 9/13/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/20/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To ,Hours 'i Task Code NPT I Phase '~i Description of Operations - _ __ ~ ---jI- _ _ - - - -- -- 9/18/2007 18:00 - 23:00 5.00 RUNCOf~V1P RUNCMP Held crew change and PJSM. Continue RIH w/ completion: I, Heat Trace, dual 1/4"SS control and balance line from HXO nipple, flat guards, and Cannon cross coupling clamps. Losses ~ I @ -1 Bbl/Hr. Ran 183 jts 4-1/2" TC-II L-80 tubing, installed 466 x 6' flat guards, 1 x 4' flat guard, 1 x 3' flat guard, 1404 flat bands, 4 stainless steel bands, and 79 Cannon clamps. 23:00 - 00:00 1.00 RUNCOf~1P (RUNCMP PUMU tubing hanger. Installed penetrator for heat trace. 9/19/2007 00:00 - 01:00 1.00 RUNCOIYIII P ~ RUNCMP Attached control lines to tubing hanger. Tested control lines to i ( 5000 psi for 10 minutes. 01:00 - 01:30 0.50 BUNCO ' P i RUNCMP RD control line spools and tubing handling equipment. 01:30 - 06:00 4.50! BUNCO P RUNCMP Spliced heat trace cable to penetrator. MU heat trace cable to ~ wellhead penetrator. Land tubing hanger. RILDS. PUW = 96K, SOW = 76K 06:00 - 07:00 1.00 RUNCO P RUNCMP Dry rod set TWC. P/T TWC from below to 1000-psi. ~ 07:00 - 11:30 4.50 BUNCO ~ P RUNCMP PUMU Lubricator. Pull TWC. L/D lubricator. 11:30 - 14:30 3.00 RUNC011~1P RUNCMP Hook up circulating lines. Reverse circulate 120-Bbls. 120E SW @ 3.0-BPM @ 190-PSI down IA taking returns to Tiger Tank. Reverse circulate 290-Bbls. 120E corrosion inhibited SW down IA @ 3.0-BPM @ 190-PSI taking returns to Tiger Tank. MIRU LRS. 14:30 - 14:45 0.25 RUNCOMP RUNCMP PJSM -All crew and LRS crew. Pump diesel freeze protect. 14:45 - 16:00 1.25 RUNCOMP ~ RUNCMP LRS reverse circulate 140-Bbls of 120E diesel down IA to freeze protect well @ 2.0-BPM @ 300-PSI. 16:00 - 18:00 2.00 BUNCO P RUNCMP Drop ball & rod w/roller stem. Allow ball & rod to fall - 20 ~ minutes. Bring tubing pressure up to 4000-PSI for 30 charted minutes while observing IA pressure. IAP = 300-PSI, OAP = 250-PSI. Bled tubing off to 1500-PSI and LRS increased IA 18:00 - 18:30 0.50 RUNCOM P RUNCMP Held crew change and PJSM. Bled MIT pressures and sucked out fluid from stack. 18:30 - 19:30 1.00 BUNCO ' P RUNCMP Set TWC and tested from above to 1000 psi for 10 minutes. RD lines. 19:30 - 21:00 1.50 BUNCO P RUNCMP ND BOPE. 21:00 - 00:00 3.00 BUNCO P RUNCMP NU adapter flange and tested void to 5000 psi. NU and tested tree to 5000 psi. MPU Pad Operator approved tree orientation. 9/20/2007 00:00 - 02:00 2.00 BUNCO P RUNCMP RU and tested lubricator. Attempted to pull TWC. Could not screw into TWC. 02:00 - 04:00 2.00 BUNCO N SEAL RUNCMP PU lubricator. Cleaned grease from tree. Lubricator rod not centralized over TWC threads. Screwed rod into TWC and reset lubricator. Pulled TWC, PU lubricator. 04:00 - 05:00 1.00 BUNCO P RUNCMP Reset and tested lubricator. Set BPV. 05:00 - 06:00 1.00 BUNCO P RUNCMP Secured tree and cellar. Released rig @ 06:00 hrs, 6/20/2007. Printed: 10/3/2007 2:20:14 PM by ~ M icaela Weeks Geologist Milne Point Unit May 29, 2007 State of Alaska Oil and Gas Conservation Comm. 333 7th Ave Anchorage, AK Direct: (907) 564-5635 Main: (907) 564-5411 Micaela.weeks@bp.com Chip Samples BP Alaska MPF-99 Milne Point Fieid North Slope, AK Depths: 8804-9014' MD Core Sections 1-7 Signed: Micaela Weeks BP BP Alaska Exploration 900 E. Benson Blvd Anchorage, AK 99508 ~~= =~ i~i~111~~~ I~1~1~\ State of Alaska: MPF-99, 206-156 • ~ Page 1 of 2 Mahnken, Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, October 17, 2007 10:59 AM To: Mahnken, Christine R (DOA) Subject: FW: MPF-99, 206-156 Attachments: MPF-99i Core Chip Descriptions.xls; MPF-99 State Chip Samples to state.doc; MPF-99 core cut and recovered.doc Christine: Please print the letter below and all attachments and place them in the MPF-99 well history file (PTD 206-156). Thanks, Steve D. __ _ _ __ From: Stewman, Sondra D [mailto:Sondra.Stewman@bp.com] Sent: Wednesday, October 17, 2007 10:53 AM To: Davies, Stephen F (DOA) Subject: MPF-99, 206-156 Hello Steve, Please reference the following well: Well Name: MPF-99 Permit: 206-156 API#: 50-0292332-00-00 Top PerF MD: 8844' Bottom Perf MD: 9090' This well never began Production, it was converted to WAG Injector and Perforated interval '8980' -9090' - (Sundry #307-288) in September 2007. I will be submitting the 10-404 for this work to the AOGCC today. Method of Operations is presently: Water Injector Date of first injection: October 17, 2007 There is no well test data Please find attached the coring data for this well. «MPF-99i Core Chip Descriptions.xls» «MPF-99 State Chip Samples to state.doc» «MPF-99 core cut and recovered.doc» Please advise of further data request. 10/17/2007 MPF-99, 206-156 . Thank you Sondra Stewman ADW Drilling TA Diversity & Inclusion Resource D&I Info: http//alaska.bpweb.bp.com/di Page 2 of 2 10/17/2007 • • BP MPF-99i CORE PROGRAM Aril 2007 CORE MD INTERVAL CUT RECOVERED # FROM / TOP TO / BASE (ft) (ft) % Comments 1 8804 8834 30 30 100 2 8834 8864 30 30 100 3 8864 8894 30 31 104 4 8894 8924 30 28.5 95 5 8924 8954 30 30.7 102 6 8954 8984 30 30.2 101 7 8984 9014 30 30.5 102 TOTAL CORE CUT 210' TOTAL CORE RECOVERED 210.9 TOTAL % RECOVERED 100.4% MPF-99i Core Chip Descriptions.xls Core Chi Descri tions 8804' MD to 9014' MD Well: MPF-99i API # 50-029-23332-00 Geologistls: Reusing I Zarndt Location: Milne Point date: April 24- 29, 2007 Cemanf a °L Pnro Scorn Mrunied • Depth Lithology Color Grainsize Roundness Porosity Cement Description MD Lith u w > E ° > ` °' ~ N N E ~ % Type Constituents Shows Core 1 8804 Med-drk gry argillaceous sltst; tr and grn gtrllthc Slst med-drk gry grns;sli micaceous, massive; well indurated Not done due to MOBM 8805 Sh dk gry-brn x Slty, sub-fissle, carbonaceous, tr mica 8806 Slts med-drk brn-gry x x Qtrose, argillaceous, w! v-f interlaminated shale 8807 Predom. Sltst. Qtrose, argill, mirco-mica (tr) w! v-fn Sltslsh med-drk brn-gry x x (1-2 mm) interlam dk gry shale (mud rip-ups?) 8808 Sh v dk gry/blk X x sub-fissle, carbonaceous, tr micro-mica specks Predom. Sltst: (65%) Qtrose, argill, mirco-mica (tr); 8809 Interlam. w/ v-fn (1-2 mm} interlam dk gry shale (mud rip-ups?) Sltslsh med gryldrk brn-gry x x 35% Predom. Sltst: (70%) Qtrose, argill, irate pyrite; w! v 8810 Interlam. u-fn (0.3 -1.5 mm) interlam dk gry carbonaceous 51tslsh med gry/drk brn-gry x x shale, 30% 8811 Interlam. 50% 150% interlamaminated Siltstone/Shale as Sltslsh med gry/drk brn-gry x x above; Laminations 1.0 to 10 mm 8812 Interlam. 40%! 60% interlamaminated Siltstone/Shale as Sltslsh med gryldrk brn-gry x x above; Shale fissile, carbonaceous, black 8813 Shale dk gry I blk x Blocky habit, carbonaceous, nc silt, tr pyrite 8814 Shale med to dk gry x Massive, blocky habit 8815 Shale med to dk gry x As above 8816 Interlam. It-cod gry sltl 65% 135% interlamaminated SiltstonelShale as Sltslsh dk gry-blk sh x x above; Tr VFG ss in slt; wispy/undul. Lams 8817 Interlam. It-cod gry sltl 5ltslsh dk gry-blk sh x x Interlamaminated SiltstonelShale as above... 8818 Interlam. It-cod gry slt/ Interlamaminated Siltstone (95%): gtrose, tr micro- Sltslsh dk gry-blk sh x x pryhe I Shale (5%) wispy clay chips/lams. Depth Lithology Color Grainsize Roundne~ Porosity Cement Description Page 1 of 12 MPF-99i Core Chip Descriptions.xls • MD Lith v ti `> E ° > rn ~°' ~ N N C w % Type Constituents 011 ShoWS 881 g Interlam. It-md gry sltl 98% Siltstone as above, minor very fine lamination of Sltslsh dk gry-blk sh x x clay (shale) < 0.5 mm, tr pyrite, carbon. 8820 Interlam. and gry slt/ dk 50/50% siRstonelshale; very drk gray to blk shale, Slts/sh gry-blk sh x x micro-micaceous, very carbonaceous Predom. Sandstone; clr/glssy Qtr, VFG, v-w srtd, wl 8821 Interlam. and gry slt/ dk tr silt, heavy ail-stain???; occ.whispy shale SS/sh gry-blk sh X x laminations (0.5 tp 2.Omm) 8822 SS (100%) drk brwn X X x x X x Qtr: clrltrnsl, v-w srtd, good p & p, heavy stn SS as above, w/minor wispy (discont.) shale lamin. 8823 SS (95%) drk brwn X X x x X x (0.5 -10 mm) SS (60%): cldglssy Qtz; FNF gr, v-w srtd, w/ tr silt, Interlam. and gry slt! dk heavy oil-stain???; occ. shale laml rip-up clasts (1.0 - 8824 SSlsh gry-blk sh x X X X X X x 5.0 mm) 8825 SS (100%) drk brwn X X x x X x Qtr: clr mod consol, v-w srtd, good p & p, heavy stn 8826 SS as above, uniform srtg and texture as above, SS (100%) drk brwn X X x x X x massive appearance 8827 SS, similar to above, w! occ wispy disc shale SS drk brwn X X x x X x laminations SS as above, uniform srtg and texture as above, 8828 SS (100%) drk bnvn X X x x X x massive appearance 8829 SS (100°!°) drk brwn X X x x X x SS: predominantly quartz, good p &p, excl srtg 8830 SS (99+%) drk brwn X X x x X x SS as above 8831 Quartz SS: massive appearance„ w uniform texture, SS (100%) drk brwn X X x x X x srtg and grain size as noted; v~ por 8832 Quartz SS: massive appearance„ w uniform texture, SS drk brwn X X x x X x srtg and grain size as noted; vt~ por 8833 SS drk brwn X X x x X x Quartz SS: as above, homogeneous... Core 2 8834 SS med-dk brn 25 silica W. consol, qtr ss, w srtd, sli slty, massive 8835 SS med-dk brn 20 silica Massive, wl consol, w srtd, of-f grnd qtr ss 8836 SS med-dk brn 25 silica Massive, wl conscl, w srtd, of-f grnd qtr ss 8837 SS med-dk brn 20 silica Massive, wl consol, w srtd, of-f gmd qtr ss 8838 SS med-dk brn 25 silica Massive, wl consol, w srtd, of-f grnd qtr ss 8839 SS med-dk brn 20 silica Massive, wl consol, w srtd, of-f gmd qtr ss 8840 SS med-dk bm 25 silica Massive, wl consol, w srtd, of-f grnd qtz ss Depth Lithology Color Grainsize Roundness Porosity Cement Description Page 2 of 12 MPF-99i Core Chip Descriptions.xls • MD Lith v N ~ ~ " > ~, °' ~ y ti ;: "' % Type Constituerrts Oil $hOWS 8841 SS and-dk brn 20 silica Massive, wl consol, w srtd, of-f grnd qtr ss 8842 SS and-dk brn 25 silica Massive, wl consol, w srtd, of-f gmd qtr ss 8843 Dom massive, wl consol, w srtd of-f gmd qtr ss, w/ tr SS and-dk brn 25 silica qtr og; w/thin lam and grnd ss wl incr silica cmnt Massive, w consol, w srtd, of-f gmd qtz ss, wl 8844 increasing micaceous content, tr pyr cmnt, tr pyr SS and-dk brn 20 silica nodules 8845 ShISIsNSS It-0k bm I gry ~ 30 silicalpyr Laminated shales, siltstones, ss 8846 Massive, no bedding visible, decrease visible SIst/SS and-dk brn 25 silica, cly porosity, decrease mica content Laminated shales, silstones, ss. Rip-ups visible is 8$47 some shale beds; One laminae off-crs qtr ! ang ShISIsHSS It-dk brn! gy 25 silica, tr pyr mical tr drk gry chrt? 8848 Massive (no visible lam) ss wl tr med qtr/chrt gms w! Dom SS and-dk brn !gry 20 silic 1 cly/pyr micro-pyr lam and dr gry shl lamlbedding 8849 Massive ss to micro-lam of shlsltst, some rip-ups Dom SS and-dk brnlgry 20 silica/cly visible. 8850 Slty Sh and gry WI indurated, micaceous, tr carb, tr ss nods. 8851 W indurated w/ incr slt and micaceous material, tr and Slty Sh and gry brn, of-f grn ss laminations $$52 Slty Sh and brn Incr slt content 8$53 Sh and gry W indurated shale w! incr freq thin med brn ss lam. 8854 W indurated, micaceous, Garb w/ It-md brn, f-md grnd Sh and gry ss lam 8855 Sh and-drk gry Sh as above ! tr pyr w! thin clr-md brn qtr ss lam 8856 Sh and-drk gry Sh as above / tr pyr w! thin clr-md brn qtr ss lam 8857 Sh/SS and brn /gry Thinly lam shlss 8858 ShISS and brn /gry Thinly lam sh (incr micaceous content)Iss $$59 ShISS It-md brnlgry Thinly lam sh (incr micaceous content)/ss sa6o Dom massive, sh, sli slity, reduced micaceous Dom 5h and-dk gry content. Tr sml ss lam 8861 ShISS and-dk brn/gry Interbedded thin ss 1 more massive and-dk gry sh Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 3 of 12 MPF-99i Core Chip Descriptions.xls • • MD Lith % ~ N ~ E ° > m ~ m N ~' c % Type Constituents Oil $hOWS 8862 Sh/SS and-dk brn/gry Interbedded thin ss /more massive and-dk gry sh 8863 ShISS and-dk brnlgry Interbedded thin ss 1 more massive md-dk gry sh Core 3 8864 Sh med gry Very dense, massive, micaceous shale w/try pyr nodules. 8865 Sh mt?d gry Sh as above w/ thin f grnd med brwn ss lam 8866 Sh med gry Micaceous sh; waxy bedding planes in part, mica pyr lam, f-md ss bunow fill 8867 Sh med-drk gry Sli silty! sli micaceous, massive 8868 SS and-drk brn Vf, qtr ss w/ tr v thin shalelmica laminations 8869 Sh med gry Massive, sli silty, tr pyr, w/ tr v thin of ss lamination 8870 Slst and-drk brn Arenacecus, argillaceous, tr pyr 8871 ShISIst1SS and bm/gry Interbedded shlsslslst 8872 SSIShISIst and bMgry ss w s a e an si tstone aminations. ynte am an burrow fill in shale. 8873 5h and gry Dam shale wl pyr and mica lam; thin med brwn ss laminations. 8874 SS/Slst med brwn V micaceous sltst grading to ss wl of-f ss, micaceous, tr qtr og 8875 SS and-drk brn W srtd, w indurated ss w1 no visible bedding, mod qtr og 8876 SS and-drk brn Massive ss, no visible bedding, mod qtr og 8817 SS and-drk brn See above 8878 SS and-drk brn See above 8879 SS and-drk brn See above 8880 SS and-drk brn See above 8881 Sh/SS and-dk brnlgry Thin lam of and-drk brn shlss 8882 Slst and -drk brn Slightly arenaceous slst; no apparent bedding 8883 SS and brn Well indurated, well sorted, qtr ss, w/ incr qtr og and tr pyr/ pyr•filled burrow 8884 SS and brn Well indurated, well sorted, qtr ss, w/qtr og. 8885 ShISS and-drk brnlgry V micaceous, w indurated sh wl med brn of-f grnd ss lam 8886 ShISS It-drk gry/med brn Very thinly interbedded shlss w/ occas pyr Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 4 of 12 MPF-99i Core Chip Descriptions.xls • MD Lith % ~ ~ ' ~ ° > m ° ~ N " E "" % Type Constituents 011 SNOWS Very thinly interbedded shale (freq micalpyrite lam in shale), slut (arenaceous, sli micaceous) and ss(med 8887 Sh/SSlSlst med-drk brn-gry brwn, dom vf) 8888 WI consol, w srtd, qtr ss, w! freq qtr og, no visible SS and-drk brn bedding planes 8889 Interbedded slststlss, both v thin and more massive SIst/SS and-drk bnvn bedding observed. 8890 SS and-drk bnvn Massive, w consol, w srtd, of-f grnd qtr ss, w! qtr og 8891 SS med-drk bnvn Massive, w consol, w srtd, of-f grnd qtr ss, wl qtr og 8892 Massive, w consol, w srtd, of-f grnd qtr ss, wl qtr og SSISh med-drk brnlgry w/thin shale lam visible 8893 SIstISS and-drk bm Micaceous siltstone interbedded w/ of-f gmd ss 8894 SS and brn f, silty ss, freq sid nodules, appears fairly tight Core 4 8894 QTZ: w consol, v-w srtd, massive/no bedding, good SS and-drk brwn par, heavy oil stn QTZ: w consol, excl srtg, massive/no bedding, good 8895 SS and-drk brwn por, 8895 SS and-drk brwn QTZ SS as above, mod -heavy oil stain 8896 SS and-drk brwn QTZ SS as above; mod -heavy oil stain 8897 SS and-drk brwn QTZ SS as above, mod -heavy oil stain 8898 SS and-drk brwn QTZ SS as above, mod -heavy oil stain 8899 SS and-drk brwn QTZ SS as above, mod -heavy oil stain 8900 QTZ: w consol, v-w srtd, massive/no bedding, good SS and-drk brvvn por, heavy oil stn 8901 QTZ: w consol, u-w srtd, massive/no bedding, good SS and-drk brwn por, heavy oil stn 8902 QTZ: w consol, v-w srtd, massive/no bedding, good SS md-drk brwn por, heavy oil stn 8903 QTZ: w consol, v-w srtd, massivelno bedding, good SS md-drk brwn por, heavy oil stn SS, Qtrose, w srtd, of-f grnd, some qtr og, no visible 8904 bedding excpt for occ wispy, discont shale SS and-drk brwn laminations Depth Lithology Color cnsl Grainsize Roundnex Foroairy Cement Description MD Lith % ~ ~ ' ~ ° > m °' o a " ~ '~ % Type Constituents OII SNOWS Page 5 of 12 MPF-99i Core Chip Descriptions.xls • L SS, Qtrose, w srtd, of-f gmd, some qtr og, no visible 8905 bedding excpt for occ wispy, discont shale SS md-drk brwn laminations 8906 SS md~rk brwn Quartz SS, massive , goad p & p heavy oil stain 8907 SS md-drk brwn Quartz SS, massive , goad p & p heavy oil stain 8908 SS: w srtd, of-f grnd ss, some qtr og, v-f wispy SS and-drk brwn clay/shale laminations 8909 SS and-drk biwn Quarttr SS, massive , good p & p heary oil stain 8910 SS md-drk biwn Quartz SS, massive , good p & p heary oil stain 8911 Predominantly SS wl minor clay/shale lamin. Mad oil SS and-drk brwn stn 8912 Predominantly SS w/minor clay/shale lamin. Mod oil SS and-drk biwn stn 8913 Predominantly SS w! minor clay/shale lamin. Mod oil SS and-drk bnun stn Predominantly SS w/ minor claylshale lamin. Motl oil 8914 SS mtl-drk bnvn stn 8915 SS and-drk brwn Quartz SS, massive , good p & p heavy oil stain 8916 SS and-drk bnvn Quartz SS, massive , good p & p heavy oil stain SS1Sh (~50I50) clrlglssy Qtr; FNF gr, v-w srtd, w/ tr 8917 silt, mod to heavy oil-stain; shale lamin and sider Interlam SSISh and-drk bnvn tr sidr cmnt lenses SSlSh (-50!50) clrlglssy Qtr; FNF gr, v-w srtd, wl tr 8918 silt, mad to heavy oil-stain; shale lamin and sider Interlam SSISh and-drk brwn tr sidr cmnt lenses SSISh (-5D150) clrlglssy Qtr; FNF gr, v-w srtd, w/ tr 8919 silt, mod to heavy oil-stain; shale lamin and sider Interlam SSISh and-drk bnvn tr sidr cmnt lenses SS1Sh (-50/50) clrlglssy Qtr; FNF gr, u-w srtd, w/ tr $920 silt, mod to heavy oil-stain; shale lamin and sider Interlam SSISh and-drk brwn tr sidr cmnt lenses 8921 SS and-drk brwn Quartz SS, massive , good p & p heavy oil stain 8922 Interlam SS1Sh md-drk brwn SS W/ 10% Sh laminations, as above 8923 8924 Core 5 Interlam Ss1SIstslSh (30:30:40); ss: v f -f grnd, w 8924 SSISIst/Sh med-drk brwnlgry srtd, qtz og. Slst sli arenaceous. Depth Lithology Color cnsl Grainsize Roundness Parosiry Cement Description Page 6 of 12 MPF-99i Core Chip Descriptions.xls r~ ~~ MD Lith % v N ' E ° > m m `m ~ " E '~ % Type Constituents Oil SNOWS 8925 SSIShISIst and-drk brnlgry Interlam SSlShlSlst (6020:20) Thin wispy h gry sh lam {5%) in fairly massive ss w/ 8926 visible lam due to change ingrain sae. SS v SS med-drk brn micaceous along some lam, freq qtr og. Massive ss (no visible bedding) w/ 5% thin It gry sh 8927 SS med-drk brn lam 8928 Slty Sh drk brn-gry Thin (<5%) ss lam (vfgrn) in slty sh 8929 SSIShISIst It gry /med-drk brn ' Lt gry sh laminations/ med brn ssl med bm slst 8830 SS and-drk bm No visible beddingllaminations, tr qtr og 8831 SS a!a w/ thin v micaceous, fissile and-drk gry, sli SS and-drk brn silty, shale lam SS ala wl decrease mica content in shale 8832 SS and-drk brn laminations. 8833 Increasing frequency and thicker silty shale to siRst Dom SS and-drk brn lam. 8834 Dom ss w! incr qtr og and It-metl gry very micaceous Dom SS and-drk brn (incr from above) shale laminations 8835 Dom ss w! incr qtr og and It-metl gry very micaceous Dom SS and-drk brn (incr from above) shale laminations 8836 SS and-drk brn SS w/ thin med gry sh lam, slight decr mica content SS w/ increasing frequency, thickness of gry sh 8837 SSISh and-drk brnlgry laminations 8838 SS/Sh and-drk brnlgry SS dom w/ incr amount shale laminations 8839 Drk gry, sli silty, micaceous shale w/ med-drk gry Sh drk gry sltst. Shale, drk gry, slightly silty, thicker lam than above, 8840 w/ vf, It brn ss, incr cementation, laminations in shale. ShISS and-drk brnlgry Med brn ss 50% Shale, drk gry, slightly silty, thicker lam than above, 8841 w/ vf, It brn ss, incr cementation, laminations in shale. ShISS and-drk brnlgry Med brn ss 50% Decrease thickness and frequency of shale 8842 SS med-drk brn laminations, partings wl waxy luster 8843 Medium gry shl waxy luster on bedding planes; v Sh and gry thin, of grnd ss lam As above w/visible micro fracture cutting 3 ss lam; 8844 Dom Sh and gry ss lam v thin. Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 7 of 12 MPF-99i Core Chip Descriptions.xls • MD Lith % v ~ > ~ ° > m °' `m ~ " ` % Type Constituents Oil SNOWS 8845 med gray shale to sltst w/thin and freq distorted ss ShlSltst and gry laminations; 8846 Sltst and gry $$47 Sltst and gry Dom silstone w/ v thin ss laminations 8848 Dom shale, sli silty; very thin ss laminations both Sh drk gry stained and mare lightly cemented and unstained saa9 Silty shale as above wl increasing number and Sh med-drk gry thickness of ss laminations and lenses 8850 Silly shale as above wl number and thickness of ss Sh med-drk gry laminations and lenses as above 8851 Silly shale as above w! decreasing amount of ss Sh med~rk gry laminations and lenses As above silly shale to siltstone, continued 8852 Silty ShlSlst and-drk gry decreasing amount of ss s a ove s a e si ty s a e w increasing ss 8853 Silty ShlSlst and-drk gry lamination thickness 8854 Silty ShlSlst and-drk gry As above shale/silty shale Core 6 8954 Vf-f grnd, silty qtr ss wl thin med gry shale Dom SS and-drk brn laminations Silly, micaceous shale w/thin med brn of ss 8955 lenses/laminations and tight, unstained ss Dom Sh and gry laminations and burrow fill 8956 Dark gry, silty, micaceous sh w/ of-f gmd bm ss and ShISS and brnldrk gry unstained tight ss 8957 Dark gry, silty, micaceous sh w/ of-f gmd bm ss; NO ShiSS and brn/drk gry visible unstained, tighter ss in chip 8958 ShISS gry and brnldrk Dark gry, silty, micaceous sh w/ of-f gmd brn ss 8959 Good visible porosity in ss; occas med grn qtr; SS and-drk bm interlam w/drk gry silty, micaceous shale 8960 SS and-drk bm SS as above w/decrease in % sh laminations 8961 Increasing % of shale !siltstone laminations in med SS/Sh/Slst med -drk brn/gry brn, good visible porosity ss Increasing % of shale 1 siltstone laminations in med 8962 brn, good visible porosity ss. Shale: drk gry w! waxy SSIShISIst med -drk brn/gry luster along some bedding planes Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 8 of 12 MPF-99i Core Chip Descriptions.xls • ~~ MD Lith % ~ y > E v ~ ~ m ~ m y c w % Type Constituer>ts OII SNOWS 8963 Sh md-drk gry Shale wt very few ss laminationsllenses 8964 Dom med brn of-f gmd ss wl good visible porosity wl SS and -drk brn med -drk gry, micaceous shale Interlaminated shale and of-f grnd ss w! good visible 8965 Sh/SS and-drk brnlgry porosity 8966 Med -drk bran, of-f gmd, tr med grn, w srtd, w SS and-drk brn consolidated, occas qtr og, excellent visible porosity 8967 SS and-drk brn SS as above 8968 SS and-drk brn SS as above 8969 SS and-drk brn SS as above 8970 SSISh and-drk brnlgry Interbedded micaceous ss and sh 8971 SSlSh and-drk brn/gry Interbedded micaceous ss and sh 8972 me a micaceous ss an s ;increasing ShISS and-drk brn/gry amounts shale; some visible good porosity ss 8973 nter a micaceous ss an s ;increasing ShISS and-drk brnlgry amounts shale; some visible good porosity ss Interbedded micaceous ss and sh; increasing 8974 amounts shale; some visible excellent porosity ssl SS/Sh and-drk brnlgry some very tight 8975 Sltst and-drk brn Slgithly arenaceous slststone 8976 Interlaminated siltstone and ss; some sands good SIstISS med-dk bm visible porositylsome poor visible porosity 8977 Interlaminated ss /sh (70/30); ss ranges from oil- SSISh and-drk brnlgry stained and good visible porosity to unstained, tight 8978 Dom ss wl good visible porosity; -10% shale SS md-drk brn laminations 8979 Interlam micaceous sltst/ss/sh; ss sli to very silty and SIst/SSISh med-drk brnlgry micaceous; ss overall good visible porosity Micaceous ss /shale laminations. SS overall w/ 8980 SS metl-drk brn good visible porosity ecrease amount o s a e am; ss goo wsi e 8981 SS and-drk bm porosity Interlaminated ss to sltst and shale; all very 8982 SSISIty Sh med-drk brn/gry micaceous Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 9 of 12 MPF-99i Core Chip Descriptions.xls MD Lith % v ~+ ~ ~ ° > rn m `m ~ N c "" % Type Constituents OII SNOWS 8983 Micaceous and carbonaceous shalelsltst w! ss ShlSltst and brnlgry bedding with good visible porosity 8984 Dom ss wl good visible porosity; very thin dark gry sh SS and-drk brn laminations Core 7 Dom of-f grnd, tr med grn, w srtd ss w/ qtr og and 8984 good visible porosity. Very rare and thin med gray SS med-drk brn shale laminations Dom gry silty, micaceous shale w/ of-f ss laminations 8985 /lenses. Some laminations wispy. SS visible Sh1SSISlst and-dk brnlgry porosity good to poor. Dom and brn, micaceous ss w! qtz og and good to 8986 poor visible porosity. Unstained ss laminations and Dom SS and brn burrow fill 8987 Dom Sh drk gry Drk gry, dense, non-fissil, sil micaceous, sli silly. Med -drk gry sh wl It-md brn ss laminations and 8958 lenses w! good to poor visible porosity. Micro Sh/SS med-drk brn/gry fracture visible cutting some ss laminations Dom SS wl med-drk gry siltsone and silty shale bedsllaminations. SS! Sh interface freq wispy, bedding slip faces visible. SS visible porosity ranges 8989 Dom SS md-drk brn from good to poor 8990 Dom SS, well sortd, micaceous, qtr og, no visible Dom SS and-drk brn bedding w/ tr drk gry silty shale laminations 8991 Dom ss w! good visible porosity w/thin shale (It-md Dom SS and-drk brwn gry) laminations Increase in unstained I tight ss laminations w! poor 8992 visible porosity. Thin and infrequent shale Dom SS md-drk brwn laminations SS w! good to moderated poroshy, thinlinfrequent 8993 iight ss laminations; think /infrequent shale Dom SS md-drk brwn laminations Interlaminated ss (massive, good visible porosity) w/ 8994 ss (It brown to clear, poor visible porosity) laminations and lenses and thin It-drk gry shale SSISh and-drk brnlgry laminations 8995 ShISS and-drk brnlgry Increase shale and unstained ss Depth Lithology Color cnsl Grainsize Roundness Porosity Cement Description Page 10 of 12 MPF-99i Core Chip Descriptions.xls • '~ I• MD Lith % ~ y ~ ` ~ ° > m °1 `m N " ` ~` % Type Constituents OII SNOWS 8996 ShISSlSIst md-drk brn/gry Sh/SSl w/ Slst 8997 Sh w/ thinner ss laminations/lenses w/some thicker Sh and-drk gry ss (good visible porosity) laminations 8998 Dom ss w! good visible porsotiy and few unstained SS med-drk bm lenses/laminations. Few shale laminations 8998 No visible bedding llaminations, excellent visible Dom SS and-drk brn porosity. 9000 No visible bedding llaminations, excellent visible Dom SS and-drk brn porosity. 9001 Interlaminated ss (dom good visible porosity), shale, SSIShlSlst and-drk brnlgry siltstone. Slump and fill features visible. 9002 Slst and-drk brn Slightly arenaceous slst; no apparent bedding Shale wl ss laminations w! good to poor visible 9003 ShlSS and-drk brnlgry porosity a e w ss aminations w goo to poor visa e 9004 ShISS and-drk brn/gry porosity 9005 Slst and-drk brn Skst w! ss and shale laminations 9006 Med-drk brn ss wl unstained ss laminationsllenses SS and brn and med gry shale laminations Med-drk brn ss w! unstained ss laminationsllenses 9007 and decrease in number of med gry shale SS and-drk brn laminations 9008 Slst med-drk brn Slightly arenaceous slst 9009 Thin shale laminations in interbedded stained and SS and-drk bm unstained ss /lenses 9010 Micaceous shale interbedded w! stained and ShISS and-drk bm/gry unstained ss 9011 ShISIstlSS md-drkbrnlgry Interbedded shalelsilstone/ss 9012 ShISIstlSS md-drkbrnlgry Interbedded shalelsilstonelss 9013 ShISIstlSS md-drkbrnlgry Interbedded shalelsilstonelss Thick ss lamination wl thin shalelslstn/unstained ss 9014 SS med-drk brn laminations Ead of Coring Page 11 of 12 MPF-99i Core Chip Descriptions.xls • • Page 12 of 12 • Regg, James B (DOA From: Regg, James B (DOA) ~}, ~~~, Sent: Thursday, September 20, 2007 4:25 PM To: 'Hefley, G Mike'; Fleckenstein, Robert J (DOA); Maunder, Thomas E (DOA} Subject: RE: Emailing: MPF-99 MIT Form.xls Z~~ _~~~ was this intentionally done as a CMIT TxIA? Based solely on the report, I would not consider this a passing MIT-IA. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: Hefley, G Mike [mailto:HefleyMGC~BP.com] Sent: Thursday, September 20, 2007 12:06 PM To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: Emailing: MPF-99 MIT Form.xls «MPF-99 MIT Form.xls» The message is ready to be sent with the following file or link attachments: MPF-99 MIT Form.xls Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 1 ~ ~ Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: P. Bay / MPU /MPF-99 DATE: 09/19/07 OPERATOR REP: Hefley/Aubert AOGCC REP: Waived by Bob Noble (06:30 / 9/18/07) Packer Depth Pretest Initial 15 Min. 30 Min. Well MPF-99 Type Inj. WAG TVD 7511 Tubing 0 4000 3950 3930 Interval T P.T.D. 206-156 .Type test Tbg /MIT-IA Test psi 4000 Casing 0 4100 4000 3970 P/F P Notes: Conversion from producer to WAG injection. OA 250 250 250 250 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~,~~ R I2,~~~ -- ~S~ i v~c:c-mil c l.cc.~j tf-e Cc s ~t~I'-'~ TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D = Drfferential Temperature Test INTERVAL Codes I = initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MPF-99 MIT Form.xls a ~ a~ SARAH PAUN, GOVERNOR ~SSt~T Q~ ~ ~7 333 W. 7th AVENUE, SUITE 100 C~~S+~IRQA/1~01` LtO~,IIS+~+IO~ ANCHORAGE, ALASKA 99501-3539 A7 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Ream Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPF-99 Sundry Number: 307-288 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this ~? day of September, 2007 Encl. ~ -~ 5~ KClr~l V ~L~ (,~'`1~IZ~o~ . STATE OF ALASKA • ~~ SEP 1 0 20Q7 ALASKA OIL AND GAS CONSERVATION COMMISSION l`~ APPLICATION FOR SUNDRY APPROVAL Alaslfa ~Ji1 ~ Gas Cons. CQmmissian 20 AAC 25.280 Anchorage 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ®Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ~ ~' Convert to WAG In'ector 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-156 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23332-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 7400' MPF-99 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 025509 °` 45.81' ~ Milne Point Unit / Kuparuk River Sands ' 12 PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9270 - 7215 ~- 9225 ~~ 7198 ~ 8570 None asin L n h Size MD TVD Burst Colla se Structural Conductor 112' 2 112' 112' 1490 470 Surface 4858' 13-3/8" 4893' 4608' 4930 2270 Intermediate Production 7 22' 9-5/8" 7954' 6717' 870 4760 Liner 895' 7-5/8" 7775' - 8670' 6653' - 6989' 6890 4790 Liner 1618' 4-1/2" 7652' - 9270' 6608' - 7215' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8844' - 8934' 7056' - 7089' ~ 2-7/8", 6.5# L-80 7647' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ~ ~, ~~, o~ ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory development Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 16, 2007 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5477 Printed Na avid Reem Title Engineering Team Leader i Prepared By Name/Number: Signature Phone 564-5743 Date J - ~ _ ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~BpP Zest , . ~M.,.echanical Integrity Test ^ Location Clearance Other: ~~~~ ~S t ~~.! ~ ~~`~ Subsequent Form fired: APPROVED BY ~`/ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revisec~0 / ~ ~ ! V ~„~ RBDNOS BFI SEP I 3 2007 Submit In Duplicate yr/o? .~~=loT • ~, ~G P ik ~ ' ~; pia, ~,4` S~~ Milne Point F-99 Rig Workover; CONVERSION TO INJECTOR Scope of Work: Pull existing ESP & 2 7/8" tubing completion, run GR/CCL & perforate Kuparuk A-1 sand on wireline, run new 4-~/2" L-80 premium threaded completion w/ heat trace and a SCSSV. MASP: 1750 psi Well Type: Producer being converted to injection ~ Estimated Start Date: Sept. 16, 2007 ire-ri re work: O 1 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 4ES. 2. Circulate out freeze protection fluid and circulate well with warm seawater. Measure SITP. 3. Kill well with clean kill weight fluid. 4. ND tree. NU and test BOPE to 4000 psi, test annular to 3500 psi. 5. POOH with existing ESP completion and 2-7/8" tubing. 6. Run GR/CCL & Gauge ring to correlate to previous log and ensure wireline can get down to 9100' MD 7. Run 2-7/8" OMEGA guns (6 SPF) and wireline perforate from 8980' to 9090' 8. Run new 4 1/2", 12.6 #, L-80, TC-II tubing w/ heat trace and SCSSV for injection. 9. Freeze protect to 2200' MD w/diesel. 10. Set and test 4 Y2" x 9 5/8" packer to 4000 psi. 11. Install new tubing adapter rated to 5M, test to 5000 psi. 12. ND BOPE. Set & test BPV. 13. Install new 4'/z" tree rated to 5M, test to 5000 psi. 14. RDMO. ell wGt Or ~. .~~~y ~Pr~i1"-~ qt q ~!~'~rOc~v~ ~ti,l QcT?71r: L~~~-~~ ,^,,'~l COM~ ~ q~z/o 7 Tree: Cameron 2 9/16 " - 5M~ M P F -99 Orig. ~lev. = 45.8' Doyon 14 Wellhead: FMC 11" x 2 7/8" Tbg. Orig. KB to BF = 29.73' Doyon 14 Hanger, 2 7/8" EU 8rd T & B I 2.5" CIW - Type H BPV profile 20", 92 ppf, H-40 Welded & 120` Insulated 3 3/8", 68 ppf, L-80, BTC 4893` KOP @ 250' Max. hole angle = 67 to 70 deg. f/ 7450' to 8750' Hole angle thru' perfs = 69 deg. 2 7/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347"ID, Cap = .0058 bpf) 9 5/8" 47#, L-80, BTC casing (Drift ID = 8.525, Cap w/ tbg = .0652 bpf) ID 0 i Camco 2 7/8" x 1" KBMM GLM 153` HES XD Sliding Sleeve 7408` 2.313 ID 2.313" XN nipple w/ 2205" No-Go ID 7557` Pressure Head - GPDIS 7567' Tandem Pump: 7568` 145P1,1 Model SSD 1:1 47 Stage P62 Model SXD ' Gas Separator GRSFTX BAR H6 7600 Intake Depth 6590' TV D Tandem Seal Section CSF33f7E3iJT SE'~1SE3 F'FSA 7605` t fSB3L)Ei~i SE3ISB FSA CI_5 Motor, 228 HP, 2305vo1[, 60 7619` amp, Model KMH PumpMate XTO Sensor w/ 6 fin ` centralizer and Anode 7638 Sensor Deoth 6603' TVD ~~~ I~~ r / ; 1 + 9 5/8" x 4 1/2" Liner Top 7652` 9 5/8" x 7 5/8" Liner Top 7775' Perforation Summary Ref log: Size SPF Interval (TVD) 2 7/8" 2 7/8" 6 6 8844` - 8864' 8894` - 8934' 7056` - 7064' 7075` - 7089' 9 5/8", 47 ppf, L-80, BTC 7954` 7 5/8", 29.7 ppf, L-80, Hyd 513 8670` I 4 1/2", 12.6 ppf, L-80, IBT-M 9225' /HES Float Collar (PBTD) 9270' ~ HES Shoe DATE REV. BY COMMENTS MILNE POINT UNIT 05-21-07 L. Hulme Drilled and completed -Doyon 14 WELL MPF-99 API NO: 50-029-23332-00 Shroud 7600' - 7647` BP EXPLORATION Tree:Cameron41/16"-5M MPF-99 PROPOS Wellhead: FMC 11" x 4 1/2" Tbg. Hanger Orig. KB Elev. = 45.8' Doyon 14 Orig. KB to BF = 29.73' Doyon 14 20", 92 ppf, H-40 Welded & 120` Insulated 4 1/2" HXO SSSV, L-80 -2100` w/ dual control line I13 3/8", 68 ppf, L-80, BTC 4893` KOP @ 250' Max. hole angle = 67 to 70 deg. f/ 7450' to 8750' Hole angle thru' perfs = 69 deg. 4 1/2" 12.6# L-80TC-II 9 5/8" 47#, L-80, BTC casing (Drift ID = 8.525, Cap w/ tbg = .0652 bpf) HES XD Sliding Sleeve 7408` 2.313 ID 9 518" x 4 1 /2" Baker S-3 Permanent Packer 41/2"" X nipple w/ 3.813" I.D. 4 1/2"" XN nipple w/ f ~ I 3.725" I.D. L~ 14 1/2", 12.6# L-80 TC-11 Tubing 9 5/8" x 4 1 /2" Liner Top 7652` 9 5/8" x 7 5/8" Liner Top 7775` Shroud 7600` - 7647` 9 5/8", 47 ppf, L-80, BTC 7954` I 7 5/8", 29.7 ppf, L-80, Hyd 513 8670` I Perforation Summary Ref log: Size SPF Interval (TVD) 2 7/8" 2 7/8" 6 6 8844` - 8864' 8894` - 8934' 7056' - 7064' 7075` - 7089' DATE REV. BY COMMENTS 09-07-07 H. West Proposed Completion 4 1/2", 12.6 ppf, L-80, IBT-M 9225` HES Float Collar (PBTD) 9270' HES Shoe MILNE POINT UNIT WELL MPF-99 API NO: 50-029-23332-00 BP EXPLORATION I WC=iANICAL INTEGRITY R~"PORT - ~ - ~~ ~ _ i s °UD v::I_ : ~a~~3"~ ~ OPER ~ FZELD ~~ Mt ~~~~ ~°-k- ...G r EW~.,y , `r' j~_ ~~ ie~Ll. NUMBER ~"\~ ~` '~~ n~ LL DAT~_ TD : ~la~~ _?~.. `l~i~ TVD ; ?BTD : ~~~~ 3~D ~i~i~ TVD Corsi^g '~~j~. Shoe: ~~ MD ~i~~ TVD ~: ~l`1'1 S ?~ ~~~~I`4'I? _., e .. ~'1 ` ~ Shoe . `3'1~ ~ '~~~ i T`JT ; . Gr . '~~~ >.~ (~ ~Q ~ '_"~ D -moo=~~ ~~_PaCKe~ - :~ T`+n1 ; Set a~ 1~?~~ ole Si ~ ~ L_ ~e ~ ~~~-l and ~S ~~s`~~; Perfs ~ ~-~~ to ~' ~ C'r'.~?~ =C~ ~.. _NTEGRITY - ?A1ZT # ~ rnnu.lus ?ress Test:? i 5 min ?,0 min Comments: r :~' CHA N { C?i, iNTEGRT'I'Y -PART # 2 ~ ~o~ ~ ~ ; ~~` ~ . ~ ~ 1~- Cement Volumes:. ~~t. ~1.ner~~~s~ ; Csg a~~-}S~,C l~ t~ll~ Cwt. -rol to cover oers ~;'3~ C~~~ `3CZk~~~~ s~~c`_+~r.~-~ C..C'V~`~ ~~c~ no-.- flrv~ SO~~ eoretical TCC i ~~ C'' Cement Band Log (Yes (~-t-~~ ~' ar No) ~~~ ; In AOGCC ~ i~~-.~_~r.,~ File-~~,~- CSL Evaluation, gone above perfs S~ C~~i , 'y~~ . ~~C °~~ Production I..og: ''_'ype ; Evaluation CON~LJSIONS: 4 ?art rl: - ?ar ~ 12: T WELL LOG TRANSMITTAL To: State of Alaska September 5, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-99 AK-MW-5043543 1 LIS formatted CD with verification listing. API#: 50-029-23 3 32-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 g 5S1 ~M ~'~Q i ,~, ~_ Date: ,.. A~ris~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: ~~~- ~5~ ~ tS~Cl~ • • WELL LOG TRANSMITTAL To: State of Alaska September 5, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPF-99 AK-MW-5043543 MPF-99: Digital Log Images: 50-029-23332-00 1 CD Rom PLEASE ACK1~tOWLEDGE RECEIPT BY SIGNING AND RETURNING-THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~- ~, s ; _----~ Date-~ ~ .~ ~~r~~ -;=-y- q"~tCfi BP Exploration (Alaska} Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I Signed: ~Q(o-(S ~ ~ l S4~b`~ To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-99 PB 1 a September 5, 2007 AK-MW-4794046 1 LIS formatted CD with verification listing. API#: 50-029-23332-70 PLEASE ACKNOWLEDGE RECEIP'T' BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 -~: r ~ ~, ~.~~' '~ Dam ~ ' ,~, ~'Jv~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: ~b~' ~~~ ~ +5~~l0~ WELL LOG TRA.~ISNIITTAL To: State of Alaska September 5, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPF-99 PB 1 AK-MW-4794046 MPF-99 PB1: Digital Log Images: 50-029-23332-70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUR.~iING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ ~r ~g~: ~~ ~,~ .. . Date: ~~ ~ ~ ~~~ ~~,~~a ,~~~ ~;-~~ ~n~~r;s~~~s: ~,_ .,q~ BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: _ ~ ~'~o ~ 1 S~o~ ~6~ Page 1 of 1 Maunder, Thomas E (DDA) From: Regg, James B (DOA) Sent: Thursday, September 06, 2007 12:31 PM a' ~,~ ~ ~ ~~ To: Maunder, Thomas E (DOA) ~+ Subject: MPU F-99 Convert to Injection ti~~5 Call from Nathan Leonard (BP; 564-g7~87` said they want to convert MPU F-99 to injection. Wel! is a Kuparuk completion; PTD 206-156 approved 11!21!2006; driAed/suspended Dec '06 -Jan '07; completed May 2007. He asked about what was needed to do the AOR for the conversion - if we had a data packet to guide the submittal. He was apparently not aware the well was permitted as 1 WINJ; Well Permit Checklist indicates no wells within '/. mile AOR of F-99 (closest well is producer L-02 which is >1500 ft ;PTD says ops governed by AIO 10B. Well was completed as 1-OIL and they did a single well tracer test; well was never hooked up to sales line. I told Nathan the well was permitted as 1 VNINJ so AOR was likely completed, and that you would contact him about what is outstanding/needed to convert to injection. Appears to me they just need to submit the bond log for MiT Part 11 (if not already done), performisubmit results of apre-injection MIT (none in our files), file a 10-404 to change status of the well from producer to injector, and inject per AIO 10B. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ,~rL~"( 9/6/2007 i ~ a ~.~ ~ ~. ~t~r ~ ~ zoo~~ SC~Illl~b~l'~~P ,~~~ Vii! ~ Cis ~`,k,~5. (.r~rnmisaic~P• 4378 Alaska Data & Consulting Services ~tIICpZUf~(~^ Com an State of Alaska P Y~ 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott o8i22io7 rt-en Job # Lo Descri lion Date BL Color CD OWDW-SE 11492253 RST UZ 11/16/06 1 1 MPF-99 11638629 CH EDIT PDC GR (USIT)s - ~! 05/03/07 1 02-18B 11661155 MCNL - ~ ~- (0 06/08/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth i Received by: ~~' E~EIVE^- ~~ ~ STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION ~.iUN 0 5 2047 WELL COMPLETION OR RECOMPLETION REPORT AND LOS .~~ ,.Jil ~ bias Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: 20aaC 25.105 ZoAAC zs.»o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date om Susp., or A~aod< 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/7/2007 GG~~'' 206-156- 307-100 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/13/2006 ' 50-029-23332-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2199' FSL 2450' FEL SEC R 0 ~ 4/30/2007 MPF-99 , , . 06, T13N, 1 E, UM Top of Productive Horizon: 8. KB (ft above MSL): 45.81 15. Field /Pool(s): 3668' FSL, 3123' FEL, SEC. 07, T13N, R10E, UM Ground (ft MSL): 11.5 Milne Point Unit / Kuparuk River Total Depth: 9. Plug Back Depth (MD+TVD) Sands 3298' FSL, 3039' FEL, SEC. 07, T13N, R10E, UM 9225 7198 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 542111 y- 6035652 Zone- ASP4 9270 7215 ADL 025509 TPI: x- 541474 y- 6031838 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 541562 y- 6031469 Zone- ASP4 N/A N/A 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ubmi el ronic and rinted information er 20 AA 25.0 0 N/A ft MSL 1775' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, GYRO, IFR/CASANDRA, NEU, DEN, GEO, TAP/NMR, CCL, SCMT, USIT 22. CASING, LINER AND CEMENTING RECORD CASWG ° SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP ' BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 112' Surface 112' 42" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 35' 4893' 35' 4608' 16" 723 sx AS Lite 550 sx Class 'G' -5/8" 47# L-80 2' 79 4' 32' 6717' 12-1/4" 792 sx I 'G' 7-5/8" 29# L-80 7775' 8970' 6653' 7102' 12-1/4" 254 sx Class 'G' 4-1/2" 12.6# L-80 7652' 9270' 6608' 7215' 327 sx Class'G' - `fj v~ 23. Open to production or inject ion? ®Yes ^ No 24. Tu61NG RECORD If Yes, IISt each i (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 SPF 2-7/8", 6.5#, L-80 7647' MD TVD MD TVD 8844' - 8864' 7056' - 7064' 25: ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8894' - 8934' 7075' - 7089' Freeze Protected with 125 Bbls Crude and 15 Bbls 60140 Methonal 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 24-HOUR RATE• 27. CORE DATA Conventional Core(s) Acquired? ®Yes ^ No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resul 0.071. Iti,C t.~. Will submit Conventional Core Data Summary once available qg ~~S ~L JUL 1 ~ 2Dpq S~a~ lE 133 ~~ ,: 41 23 Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE V 28. GEOLOGyC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS • NAME MD TVD Well Tested'! ^ Yes ®No Permafrost Top 46' 0' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1874' 1775' detailed test information per 20 AAC 25.071. KUB 8670' 6989' None TKUA 8794' 7037' TKA3 8809' 7043' TKA2 8860' 7062' TKA1 8948' 7094' TMLV 9064' 7136' Formation at Total Depth (Name): Top of Miluveach 9270' 7215' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post Rig Well Event Summary, and aLeak- Off Test Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman Title Technical Assistant - Date "'[~y'( MPF-99 206-156 307-100 Prepared Sy Name/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: paul Hanson, 564-4195 Permit No. / A royal No. INSTRUCTIONS GENERA: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00}. IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEne 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-!n, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Tree: Cameron 2 9/16 " - 5fv~ Wellhead: FMC 11" x 2 7/8" Tbg. Hanger, 2 7/8" EU 8rd T & B 2.5" CIW - Type H BPV profile 20", 92 ppf, H-40 Welded & 120` Insulated 3 3/8", 68 ppf, L-80, BTC 4893' KOP @ 250' Max, hole angle = 67 to 70 deg. f/ 7450' to 8750' Hole angle thru' perfs = 69 deg. 2 7/8" 6.5# L-80 EUE 8rd (Drift ID= 2.347" ID, Cap = .0058 bpf) 9 5/8" 47#, L-80, BTC casing (Drift ID = 8.525, Cap w/ tbg = .0652 bpf) 9 5/8" x 4 1/2" Liner Top 7652' 9 5/8" x 7 5/8" Liner Top 7775` Perforation Summary Ref log: Size SPF Interval (TVD) 2 7/8" 2 7/8" 6 6 8844' - 8864' 8894' - 8934' 7056` - 7064' 7075' - 7089' M p F _g g Orig. Elev. = 45.8' Doyon 14 Orig. KB to BF = 29.73' Doyon 14 Camco 2 7/8" x 1" KBMM GLM 153` HES XD Sliding Sleeve 7408` 2.313 ID 2.313" XN nipple wl G 2 205" N ID 7557' o . o- Pressure Head - GPDIS 7567` Tandem Pump: 7568` 145P1,1 Model SSD 1:1 47 Stage P62 Model SXD Gas Separator GRSFTX BAR H6 7600` I t th 6590' TV k D D n a e en Tandem Seal Section GSB3DBUT SB/SB PFSA 7605` GSB3DBLT SB/SB FSACLS MOtOr, 228 HP, 2305 volt, 60 7619` amp, Model KMH PumpMate XTO Sensor w! 6 fin centralizer and Anode 7638' Sensor Deoth 6603` TV D Shroud 7600` - 7647' 9 5/8", 47 ppf, L-80, BTC 7954' 7 5/8", 29.7 ppf, L-80, Hyd 513 8670` 4 1/2", 12.6 ppf, L-80, IBT-M 9225' HES Float Collar (PBTD) 9270` HES Shoe DATE REV. BY COMMENTS MILNE POINT UNIT 05-21-07 L. Hulme Drilled and completed -Doyon 14 WELL MPF-99 API NO: 50-029-23332-00 BP EXPLORATION ~ ~ BP AMERICA Operations Summary Report Page 1 of 24 ~ Legal Well Common W Event Nam Contractor Rig Name: Date ; i Name: ell Name: e: Name: From - To MPF-99 MPF-99 DRILL+C DOYON DOYON Hours OMPLE DRILLIN 14 Task TE G INC Code . NPT Start Rig Rig Phase ~ Spud Date: 12/13/2006 : 12/6/2006 End: 1/10/2007 Release: 1/17/2007 Number: Description of Operations 12/9/2006 13:00 - 14:00 1.00 - MOB P __ PRE - -- Skid rig floor 14:00 - 15:30 1.50 MOB P PRE Move off well #GNI-02A -Phase 1 conditions 15:30 - 16:30 1.00 MOB P PRE Remove cellar doors, heaters, mousehole, and rams 16:30 - 20:00 3.50 MOB P PRE Install front and rear boosters -Remove rockwasher landing 20:00 - 00:00 4.00 MOB P PRE Move rig off GNI pad on Spine road by PBOC -Phase 1 conditions 12/10/2006 00:00 - 12:00 12.00 MOB P PRE Move rig from Spine road by PBOC to Spine road and Oxbow 12:00 - 00:00 12.00 MOB P PRE Move rig from Spine and Oxbow to across East Channel Bridge 12/11/2006 00:00 - 12:00 12.00 MOB P PRE Move rig from East Kuparuk Bridge to Texaco Pad 12:00 - 22:30 10.50 MOB P PRE Move rig from Texaco Pad to F-pad 22:30 - 23:00 0.50 MOB P PRE Attempt to turn rig on pad -Call pad maintenance to remove snow berms on edge of pad 23:00 - 00:00 1.00 MOB P PRE Remove front boosters and support frame 12/12/2006 00:00 - 02:00 2.00 MOB P PRE Remove rear boosters and frame 02:00 - 05:00 3.00 MOB P PRE Turn rig around -Move down pad -Spot & shim rig over MPF-99 05:00 - 06:30 1.50 RIGU. P PRE PJSM -Skid rig floor (Rig accepted C~ 0600 hrs due to 2 hr delay waiting on security) 06:30 - 08:00 1.50 RIGU P PRE Spot & berm rockwasher - R/U mud lines, beaver slide, and rig floor 08:00 - 15:30 7.50 RIGU P PRE Clear floor - N/U 20" annular, riser, and flowline -Load 153 joints drill pipe and MWD tools in pipeshed -Check and calibrate gas alarms 15:30 - 22:00 6.50 RIGU P PRE P/U 153 joints of drill pipe from pipeshed and stand in derrick 22:00 - 23:30 1.50 RIGU P PRE P/U HWDP and jars from pipeshed and stand in derrick 23:30 - 00:00 0.50 DRILL P SURF Mobilize BHA to floor 12/13/2006 00:00 - 02:30 2.50 DRILL P SURF M/U BHA #1 02:30 - 03:30 1.00 DRILL P SURF Upload MWD 03:30 - 04:00 0.50 DRILL P SURF Fire drill -Evacuation drill -Pre-spud meeting with rig personel and service hands on rig floor 04:00 - 04:30 0.50 DRILL P SURF Fill hole checking for leaks -Test MWD 04:30 - 06:00 1.50 DRILL P SURF Drill from 112' to 267' with HWDP (PU 68, SO 68, RW 68, RPM 60, TO 1, 462 gpm, 1100 psi) 06:00 - 07:00 1.00 DRILL P SURF Stand back 2 stands HWDP - P/U non-mag DC -RIH 1 stand HWDP 07:00 - 11:00 4.00 DRILL P SURF Drill from 267' to 540' (PU 86, SO 86, RW 86, RPM 60, TO 1, gpm 462, 1100 psi, WOB 25) 11:00 - 12:30 1.50 DRILL N DPRB SURF Close approach issues -Wait on orders from town 12:30 - 17:00 4.50 DRILL P SURF Drill from 540' to 809' with Gyro surveys (PU 92, SO 94, RW 92, 488 gpm, 1730 psi, RPM 80, TO 2) 17:00 - 21:30 4.50 DRILL N DPRB SURF Ream out dogleg from 701' to 809' 21:30 - 00:00 2.50 DRILL P SURF Drill from 809' to 999' with Gyro surveys -AST 4.13, ART 2.01, ADT 6.14 (PU 97, SO 95, RW 97, 552 gpm, 1530 psi, RPM 80, TO 2-5, WOB 19-25) 12/14/2006 00:00 - 16:30 16.50 DRILL P SURF Directional Drill from 999' to 2416' 550-650 gpm 1350-1850 psi - WOB 25k -AST 4.79 ART 5.24 ADT 10.03 - PU 130k - SO 110k RW 123k -RPM 80 - TO 4-6k 16:30 - 18:30 2.00 DRILL P SURF CBU 3X - w/ 650 gpm 2080 psi -Rotate w/ 80 rpm & reciprocate pipe 90' 18:30 - 20:30 2.00 DRILL P SURF PJSM -Pump out of hole w/ full drilling rate to 720' (No problems) 20:30 - 21:00 0.50 DRILL P SURF RIH from 702' to 2322' -Wash last stand down to 2385' 21:00 - 22:00 1.00 DRILL P SURF Circulate thick mud out -Stage up to 1120 psi ~ 455 GPM Printed: 6/5/2007 10:10:35 AM ~ ~ BP AMERICA Page 2 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date II -- _ 1 Name: ell Name: e: Name: From - To ---. MPF-99 MPF-99 DRILL+C DOYON DOYON Hours __ ___ OMPLE DRILLIN 14 Task TE G INC Code' . NPT 12/14/2006 22:00 - 00:00 2.00 DRILL N - RREP 12/15/2006 00:00 - 02:00 2.00 DRILL N RREP 02:00 - 02:30 0.50 DRILL P 02:30 - 00:00 21.50 DRILL P 12/16/2006 00:00 - 10:30 10.50 DRILL P 10:30 - 13:00 2.50 DRILL P 13:00 - 18:00 5.00 DRILL P 18:00 - 20:00 2.00 DRILL P 20:00 - 00:00 4.00 DRILL P 12/17/2006 00:00 - 04:00 4.00 DRILL P 04:00 - 10:30 6.50 DRILL P 10:30 - 14:00 3.50 DRILL P 14:00 - 16:30 2.50 DRILL P 16:30 - 00:00 7.50 CASE P 12/18/2006 00:00 - 03:30 3.50 CASE P 03:30 - 05:00 1.50 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 10:00 4.00 CASE P 10:00 - 13:00 3.00 CEMT P 13:00 - 15:00 2.00 CASE P Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1 /17/2007 Rig Number: Phase Description of Operations SURF #1 conveyor chain jumped sprocket -Trouble shooting conveyor SURF Re-install chain on sprocket - Re-align sprocket on #1 conveyor SURF Wash to 2416' staging pumps up to 650 gpm / 2140 psi SURF Directional drill from 2416' to 4210' (AST = 4.35, ART = 11.14, ADT = 15.49, TST = 13.27, TRT = 18.39, TDT = 31.66, PU 175, SO 128, RW 150, RPM 80, TO on 10, TQ off 7, WOB 30, 640 gpm ~ 2480 psi on/ 2160 psi off) SURF Directional drill from 4210' to 4777' (ART = 4.48, AST = 4.48, ADT = 8.69, PU 187, SO 140, RW 160, RPM 160, TO 9, WOB 25) SURF Circulate and condition mud (PU 187, SO 140, RW 160, RPM 80, TO 9, 440 gpm, 740 psi) -Work on #2 mud pump SURF Pump out of hole from 4779' to 720' (424 gpm ~ 1110 psi) - Flow check -Blow down top drive -Working on # 2 mud pump SURF RIH from 720' to 4779' -Wash last stand to bottom SURF Drill from 4779' to 4902' (AST=1.34, ART=1.96, ADT=3.3, TST=19.09, TRT=24.56, TDT=43.65, PU 185, SO 140, RW 160, RPM 80, TO 12 on, TO 9 off, WOB 35, GPM 645, 2500 psi on, 2340 psi off) SURF Circulate and condition ~ 4902' (PU 190, SO 140, RW 160, RPM 100, TO 8, 656 GPM, 2260 psi) SURF Observe well -Pump out of hole stringing "G"seal pill - Continue to pump out w/ 650 gpm 1800 psi to 177' SURF Stand back DC's - LD UBHO -Down load MWD - LD MWD, stab, motor & bit SURF PJSM -Clean/Clear rig floor of BHA - MU Franks fill up tool - Change to long bales - RU casing equipment SURF PJSM -Run 93 joints of 13 3/8" 68# L-80 BTC casing to 3700' - Fill every joint -Break circ. every 10 jts. -Run 25 centralizers on jts #1 to #25 - (PU 340, SO 205, GPM 212, 360 psi) SURF Continue run 13 3/8" L-80 68# casing from 3700' to 4892' (122 joints total) -Break circulation every 10 jts - (210 gpm ~ 360 psi) -Circulate last 2 jts down -Land casing SURF Stage up from 2 bpm to 5 bpm with Frank's running tool - Circulate bottom's up (5 bpm C~ 340 psi) SURF Rig down Frank's tool -Make up cement head - SURF Circulate & condition mud for cement job SURF PJSM w/ all involved with upcoming operation -Give to Schlumberger -Pump 10 bbls H2O -Test lines to 4000 psi - Pump 20 bbls CW 100 - 100 bbls Mud Push II at 10.6 ppg - Drop bottom plug -Pump lead cement, 585 bbls ASL at 10.7 ppg w/ 5 bpm 300 psi -Stage up to 6.75 bpm 460 psi followed by tail cement, 124 bbls 15.8 ppg class "G" w/ .2% D046 - .3% D065 - .33% D167 - .1% D013 & .02 gal/sk D110 w/ 4 bpm 375 psi -Stage up to 5 bpm 675 psi -Drop top plug, kick out w/ 10 bbls H2O SURF Displace cement w/ rig pumps - 10 bpm 330 psi -Caught up w/ cement at 400 stks -Slow to 8 bpm 400 psi -Cement to surface at 3600 strokes away -Slow pumps to 5 bpm - Continue displacing -Final circ. pressure 1300 psi -Bump plug w/ 2500 psi -Hold 10 min -Check floats - OK - CIP ~ 15:00 hrs -Total cement to surface 320 bbls Printed: 6/5/2007 10:10:35 AM • BP AMERICA Page 3 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations _-__ _ __ I - - - __ _- _ __- 12/18/2006 15:00 - 17:30 2.50 ~ CASE ~ P SURF R/D cement head -Flush stack - UD landing joint -Clear and 17:30 - 20:30 I 3.001 CASE I P I I SURF 20:30 - 22:30 I 2.001 BOPSUR P I I SURF 22:30 - 00:00 1.50 BOPSU P SURF 12/19/2006 00:00 - 02:00 2.00 BOPSU P SURF 02:00 - 03:30 1.50 BOPSU~ P SURF 03:30 - 07:00 3.50 BOPSU P SURF 07:00 - 08:00 1.00 CASE P SURF 08:00 - 11:30 3.50 BOPSU P SURF 11:30 - 12:30 I 1.001 BOPSUR P I I SURF 12:30 - 13:30 1.00 CASE P SURF 13:30 - 18:00 4.50 CASE P SURF 18:00 - 21:30 3.50 CASE P SURF 21:30 - 23:00 1.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 12/20/2006 00:00 - 01:00 1.00 CASE P SURF 01:00 - 02:00 1.00 CASE P SURF 02:00 - 04:00 I 2.001 DRILL I P I I SURF 04:00 - 05:00 1.00 CASE P SURF 05:00 - 09:00 4.00 CASE P SURF 09:00 - 10:00 1.00 EVAL P SURF 10:00 - 11:30 1.50 DRILL N WAIT INT1 11:30 - 00:00 12.50 DRILL P INT1 12/21/2006 100:00 - 09:00 I 9.001 DRILL I P I I INTi 09:00 - 12:30 3.50 DRILL P INT1 12:30 - 13:30 1.00 DRILL P INT1 13:30 - 15:00 1.50 DRILL P INT1 clean floor Safety stand down w/ Doyon and service personnel assigned to Rig 14 PJSM - R/D riser, knife valve, annular preventor, and remove from cellar area Install and orient FMC wellhead NU BOP stack, riser, flowline, and install secondary annulus valve on OA -Test metal to metal seal to 1000 psi for 10 minutes with FMC PJSM - MU test joint - R/U test equipment Safety stand down Doyon and service personnel assigned to rig 14 Service rig Test BOPE -Annular to 250 psi low, 2500 high f/ 5 min each - Top VBR's -Choke manifold -Choke /Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's -Perform accumulator test -Test Blind rams to 250 psi low, 4500 high f/ 5 min. each -Jeff Jones with AOGCC witnessed test -All tests witnessed by WSL RD testing equipment -Install wear ring -Blow down Choke / Kill lines -Choke manifold Install Bails -Elevators - Moblize BHA to rig floor PJSM - MU Geo-Pilot -Bit - MW D - Up load MW D -Float sub - Flex collars -HWDP -Test Geo-Pilot -HWDP -Jars PU5"DP1X1 Cut drlg line -Service Blocks /Crown /Top Drive Con't RIH from 3923' to 4772' -CBU -GPM 500 - PP 1430 - PU 200 - SO 140 -ROT 165 - Con't CBU RU testing equip -Test casing to 2100 psi for 30 chart recorded minutes -Test good - RD testing equip -Blow down choke /kill lines -choke manifold Tag cement 4798' -Drill cement to 4808' drill plugs and float ~ 4811' -Drill cement shoe to 4892' -Clean out 16" hole to 4902' - Drill 20' new hole to 4922' -GPM 512' - PP 1480 -RPM 100 - TO 10 to 20k -POW 210 - SO 140 -ROT 160 Circulate hole clean -GPM 600 - PP 2005 -RPM 50 - TO 10 Displace to LSND 8.9 ppg -Pump 40 bbls fresh water - 70 bbls Hi-vis spacer -Followed by 690 bbls 8.9 ppg LSND mud RU test equipment -Perform F.I.T. to 12.0 EMW - w/ 8.9 ppg - 750 psi -Shoe TVD = 4606' = 12.0 EMW - 2.8 bbls pumped - .5 bbls back - RD test equip. Working disposal issues - GNI and 1 R disposal wells down Directional Drill f/ 4922' to 5540' - WOB 25 to 35 -RPM 100 to 150-TO on 10 to15K-Off14K-GPM650-PPon1890off 1840 -POW 225 -SOW 140 - ROTW 175 -ECD 9.35 Directional Drill from 5540' to 6110'- WOB 30k -RPM 100 to 150-TO on 10 to15K-Off13K-GPM550-PPon1640off 1590 -POW 240 -SOW 152 - ROTW 183 -ECD 9.41 CBU 3x w/ 596 gpm 1850 psi - 120 rpm - 8k tq Pump out of hole f/ 6110' to 4863' w/ 500 gpm 1290 psi CBU at shoe w/ 500 gpm 1290 psi - R&R DP w/ 100 rpm -Flow Printed: 6/5/2007 10:10:35 AM BP AMERICA Page 4 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPF-99 MPF-99 DRILL+C DOYON DOYON Hours. OMPLE DRILLIN 14 Task TE G INC Code ~ . NPT Start Rig Rig Phase Spud Date: 12/13/2006 : 12/6/2006 End: 1/10/2007 Release: 1/17/2007 Number: Description of Operations 12/21/2006 13:30 - 15:00 1.50 DRILL P INT1 check -Dry job 15:00 - 16:30 1.50 DRILL N DFAL INT1 POH f/ 4863' to 801' 16:30 - 20:00 3.50 DRILL N DFAL INT1 Stand back HWDP -Collars -Down load MWD -Clean Geo-pilot -Bit 20:00 - 20:30 0.50 DRILL N DFAL INT1 PJSM -Clear /clean rig floor -Mobilize BHA to rig floor 20:30 - 00:00 3.50 DRILL N DFAL INT1 MU BHA -Bit -Motor -Stabilizer - Mwd -Orient - Up Load MWD -Surface test MWD -HWDP -Jars 12/22/2006 00:00 - 01:00 1.00 DRILL N DFAL INT1 RIH f/ 818' to 13 3/8" casing shoe at 4892' -Fill pipe every 25 stands 01:00 - 03:00 2.00 DRILL P INT1 Cont. RIH f/ 4892' to 6110' -Fill pipe every 25 stands -Break circ -Wash last stand to bottom, hole in good shape 03:00 - 05:00 2.00 DRILL P INT1 Directional drill f/ 6110' to 6203' - WOB 30 -RPM 80 - TO on 8/11 k /off 7k -GPM 610 - PP on 2000 /off 1780 -POW 200k - SOW 175k - ROTW 180k -ECD 9.64 ppg 05:00 - 07:00 2.00 DRILL P INT1 Ream hole to reduce DLS -RPM 80 - TO off 6k -GPM 610 - PP 1750 07:00.- 00:00 17.00 DRILL P INT1 Directional Drill from 6203' to 6933' - WOB 30/38k -RPM 80 - TOon8k/off6k-GPM610-PPon 1930/off 1700-POW 210k -SOW 174k - ROTW 192k -ECD 9.59 ppg 12/23/2006 00:00 - 06:00 6.00 DRILL P INT1 Directional Drill 12 1/4" hole f/ 6933' to 7805' - WOB 30/43k - RPM80-TOon 10k/off 7k-GPM650-PPon 2600 psi/off 2400 psi -PUW 212k -SOW 170k - ROTW 190k -ECD 10.38 PP9 12/24/2006 00:00 - 05:00 5.00 DRILL P INT1 Directional Drill 12 1/4" hole f/ 7805' to 7958' (TD 12 1/4" hole) -W0B40to43-RPM80-TOonlO-off?-GPM 655-PPon 2640 -oft 2450 -PUW 212 -SOW 170 - ROTW 190 -ECD 10.33 05:00 - 08:30 3.50 CASE P INT1 Circulate hole clean -GPM 650 - PP 2400 - PP 2350 -RPM 80 - TO 8K -Mud wt. 10.1 ppg -ECD 10.28 ppg -Flow check - Well static 08:30 - 11:30 3.00 CASE P INT1 Pump out to 13 3/8' shoe w/ full drlg rate -Observed 40k over pull at 5390' -Ream &Backream to clean up - OK 11:30 - 12:30 1.00 CASE P INT7 CBU at 13 3/8" shoe (4892') -Rotate & reciprocate - 614 gpm, 1970 psi - 60 rpm- TO 3K 12:30 - 14:00 1.50 CASE P INT1 Observe well -Well static -Cut drilling line -Service rig 14:00 - 15:30 1.50 CASE P INT1 RIH f/ 4880' to 6870' -Hit tight spot @ 6870' - (No issues at 5390') 15:30 - 20:00 4.50 CASE N DPRB INT1 Ream &Backream from 6870' to 7958' -GPM 525 - PP 1600 - RPM 80 - TO 8K - Clean up hole 20:00 - 21:30 1.50 CASE P INT1 CBU 1.5 X -GPM 650 - PP 2430 -RPM 80 - TO 7K -ECD 10.35 21:30 - 23:00 1.50 CASE P INT1 Flow check -Well static -Pump out from 7958' to 6455' -GPM 487 -Slight pack-off depths - 7743, 7640, 7441, 7345, 6946, 6930, 6911, 6820, 6611 23:00 - 00:00 1.00 CASE P INT1 RIH from 6455' to 6926' -Hit tight spot -Set down 15K -Work down to 40K would not pass 6926' -Ream through tight spot from 6910' to 6964' - PU to 6910 -Run through section without pump - No tight area observed - Con't RIH from 6964' to 7958' - No problem areas noted 12/25/2006 00:00 - 03:00 3.00 CASE P INT7 CBU 2 X -GPM 600 - PP 2130 -RPM 80 - TO 12 to 8 -ECD 10.23 03:00 - 05:30 2.50 CASE P INT1 Pump out from 7958' to shoe @ 4880' - 35K overpull ~ 5390' - Ream down no issues -Pull through with out pump 30 over - Printed: 6/5/2007 10:10:35 AM BP AMERICA Page 5 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ~ Hours Task Code ~ NPT 12/25/2006 03:00 - 05:30 ~ 2.50 ~ CASE P 05:30 - 07:00 I 1.501 CASE I P 07:00 - 09:00 2.00 CASE P 09:00 - 10:30 1.50 CASE P 10:30 - 13:00 2.50 CASE P 13:00 - 14:00 1.00 CASE P 14:00 - 15:30 1.50 CASE P 15:30 - 19:30 4.00 CASE P 19:30 - 20:00 0.50 CASE P 20:00 - 21:30 1.50 CASE P 21:30 - 22:00 0.50 CASE P 22:00 - 00:00 2.00 CASE P 12/26/2006 00:00 - 03:00 3.00 CASE P 03:00 - 04:00 1.00 CASE P 04:00 - 10:00 6.00 CASE P 10:00 - 14:30 I 4.501 CASE I P 14:30 - 16:30 I 2.001 CEMT I P 16:30 - 18:00 I 1.501 CEMT I P 18:00 - 20:00 I 2.001 CASE I P 20:00 - 21:00 I 1.001 CASE I P 21:00 - 00:00 3.00 (CASE P 12/27/2006 00:00 - 01:30 1.50 CASE P 01:30 - 03:00 1.50 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 05:00 1.50 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 07:00 i 0.501 CASE I P Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1/17/2007 Rig Number: Phase i Description of Operations INT1 RIH with out pump -good - (no packing off) -Hole in good shape INT1 Flow check at shoe - CBU w/ 600 gpm 1850 psi - R&R DP 60 rpm, 5k torque INT1 POH to BHA INT1 Stand back HWT. - LD 8" DC's INTi Down load MWD - LD MWD, motor & bit INT1 Clear /Clean rig floor -Pull wear ring -Install test plug INT1 Change upper rams to 9 5/8" casing rams -Test door seals to 1500 psi INT1 PJSM - RU 9 5/8" casing equipment -PJSM Running casing INT1 PJSM - PU float equipment -Check floats INT1 PU /Run 9 5/8" BTC-M 47# L-80 casing to 1455' INT1 Rig up Torque turn equipment - (Circ casing volume) INT1 Con't PU /Run 9 5/8" TC11 47# L-80 casing to 2917' INT1 PU /Run 9 5/8" TC11 47# L-80 Casing from 2917' to 4850' INT1 Circ casing volume -BPM 8 - PP 560 INT1 Con't Run 9 5/8" casing from 4850 to 7905' -Tight C~ 6338 - Work string 4 X -Tight @ 7061' -work pipe 3 X INT1 Break Circulation -Stage up pump from 2 1/2 bpm to 6 1/2 bpm -Wash from 7905' to 7954' - PP from 450 to 300 - PU 430 - SO 250 -Circulate 1.5 casing volume - LD Franks tool - MU Shclumberger cement head /lines -Circulate one bottoms up -Give to Schlumberger INT1 Pump 10 bbls water - 3.5 bpm @ 275 psi Test lines to 4000 Pump 20 bbls CW-100 - 3.5 bpm C 275 Pump 70 bbls Mud Push mixed at 12 ppg - 4 bpm ~ 250 Drop bottom plug Mix and pump 165 bbls 792 sxs -Yield 1.17 -Class "G" mixed at 15.8 ppg - 4 ~ 200 Drop top plug Pump 10 bbls water - 2.5 ~ 150 Give to rig INT1 Displace with 567 bbls of 10.1 ppg mud - 6.5 bpm @ 220 - Final pump rate 3 bpm ~ 600 psi -Bump plug with 1600 psi - Hold for 10 mins record on chart -Bleed off pressure -Floats holding - CIP 17:50 hrs -Reciprocate string PU 400 to 480 - SO 265 to 235 INT1 RD Cement head -Clear rig floor -Void casing -Flush stack / tubing head /well head INT1 ND choke -Flow line -Stack -Raise stack for setting slips and cut off INT1 Set emergency slips with PUW 375K -Cut casing - LD cut jt - Length cut 23.40' INT1 Install 9 5/8" Pack-off - RILDS INT1 Change out tubing spools INT1 Test pack-off to 3800 psi for 15 mins -Test good INT1 NU BOP's -Install secondary valve on tubing spool INT1 Change 9 5/8" csing rams to 4 1/2" x 7" VBR's INT1 Bullhead 30 bbls mud down OA - 2 BPM -PSI 900 ICP - 750 FC P INT1 RU to test BOP's Printed: 6/5/2007 10:10:35 AM ~ r BP AMERICA Page 6 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code ~. 12/27/2006 (07:00 - 10:30 ~ 3.501 CASE ( P Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1/17/2007 Rig Number: NPT Phase Description of Operations INTi 10:30 - 11:00 I 0.501 CASE I P I I INTi 11:00 - 11:30 I 0.501 CASE I P I 1 INTi 11:30 - 12:00 0.50 CASE P INT1 12:00 - 13:00 1.00 CASE P INTi 13:00 - 16:30 3.50 CASE P INT1 16:30 - 19:30 I 3.001 CASE I P INT1 19:30 - 21:00 1.50 CASE P INT1 21:00 - 22:00 1.00 CASE P INTi 22:00 - 22:30 0.50 CASE P INT1 22:30 - 00:00 1.50 EVAL P INT1 12/28/2006 00:00 - 01:00 I 1.001 EVAL I P INTi 01:00 - 03:30 I 2.501 DRILL I P I I INT1 03:30 - 05:00 1.50 CASE P INT1 05:00 - 06:30 1.50 DRILL P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 08:30 1.00 DRILL P INT1 08:30 - 09:30 1.00 DRILL P PROD1 09:30 - 14:00 4.50 DRILL P PROD1 14:00 - 19:00 5.00 DRILL N DPRB PROD1 Test BOP's -Annular 250 low 2500 high -Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Jeff Jones waived witness of BOP test -All test were witnessed by WSL - RD testing equipment -Shut annulus valve -Pull test plug - Install wear ring Bullhead 30 bbls mud down OA - 2 BPM -PSI 1060 ICP 750 psi FCP Install bails and elevators. RU floor, mobilize BHA, hold PJSM PJSM - MU Geo-Pilot -Bit -MWD - Up load MWD -Float sub - Flex collars -HWDP -Surface test MWD -Jars -HWDP RIH from 804' to 7414' Fill pipe every 25 stands -Function test Geo-pilot Cut Drlg line -Rig service -Blocks -Crown -Top Drive RIH from 7414' to 7696' -Function Geo-pilot seals -Wash down from 7696 to 7853 tag cement RU testing equipment - RU line from test pump Test casing to 4000 psi with rig pump - Con't test with test pump to 4500 psi - Test 9 5/8" casing - RD testing equipment -Blow down choke and kill Drill cement on top of float collar -Shoe track to 7953' - WOB 5 to 10-RPM 50-T018to 22-GPM420-PP1400 CBU -GPM 432 - PP 1358 -RPM 50 - TO 15K Displace with new 10 ppg LSND mud Drill shoe @ 7953 -New hole to 7980' - WOB 5 to 10 - CBU Preform FIT - MD 7954 - TVD 6719 - 10 ppg - 1400 PSI = EMW 14 Directional Dril- from 7980 to 8257' - WOB 10 -RPM 140 - TO 15 to 20 on-15 off-GPM450-PP1950 on-1940off-PUW 242 -SOW 140 - ROTW 175 - ECD 10.97 Flow increase -Shut in well - DP 20 - Casg 50 - 10 bbl gain - Montior well /filling gas buster with mud -Notified AOGCC (Chuck Scheve) -Milne PT Well operations supervisor (John Cubbon) -Dan Kara Senior Engineer (Anchorage) -Attempt to circulate influx out using drillers method holding 420 psi on DP - 0 pressure on casg - (SPR 30 Stks 280 psi) - DP pressure varied between 420 to 1200 due to packing off -Shut well in with hydraulic choke -work string through annular 285K up 100K down - String appeared to be free -Bring pump on pressure oaring 600 to 920 psi - By-pass Geo-pilot manifold - Pumped total of 1400 stks pit gain 10 bbls -Shut in well with hydraulic choke - DP 20 pressure 150 casing -Gained additional 10 bbls for 31 total -Shut manual valve in front of Hydralic choke - DP pressure 450 psi -Casing 470 -Bring on pump holding casing constant to equivalent mud weight of 12.5 ppg = 1230 DP - 960 casing perssure -Circulate influx out holding 1230 psi on DP -Casing pressure decreased 960 to 740 -Shut down pump bleed off casing pressure to 20 psi - Printed: 6/5/2007 10:10:35 AM . • ~ BP AMERICA Page 7 of 24 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ; MPF-99 MPF-99 DRILL+C DOYON DOYON Hours OMPLE DRILLIN 14 Task TE G INC Code'; . NPT 12/28/2006 14:00 - 19:00 5.00 DRILL N DPRB 19:00 - 00:00 5.00 DRILL N DPRB 12/29/2006 00:00 - 15:00 15.00 DRILL N DPRB 15:00 - 16:00 1.00 DRILL N DPRB 16:00 - 18:00 2.00 DRILL N DPRB 18:00 - 19:30 1.50 DRILL N DPRB 19:30 - 23:30 4.00 DRILL N DPRB 23:30 - 00:00 0.50 DRILL N DPRB Spud Date: 12/13/2006 Start: 12/6/2006 End: 1/10/2007 Rig Release: 1/17/2007 Rig Number: Phase Description of Operations ___ _ __ - - PROD1 Shut well in with manual valve -Let stablize for 25 mins DP pressure 670 -Casing 520 psi PROD1 Circulate hole using drillers method holding 1100 psi on DP - Casing 660 psi -Order 12.5 ppg kill mud PROD1 Circulate holding 1080 psi on DP 670 on casing at 30 spm- Waiting on kill mud PROD1 Started displacing hole with 12.5 ppg mud using the Driller's Method. Held casing pressure constant at 670 psi and pumped 12.5 ppg kill mud down the drillpipe at 30 spm. Initial circulating drillpipe pressure 1080 psi decreased to 340 psi as kill mud exited the bit with 1470 strokes pumped. Switch to drillpipe and held drillpipe pressure gauge constant at 340 psi while circulating kill mud up the annulus. At 1900 strokes (50 bbls of kill mud in annulus) well started packing off. Well was completely packed off at 2000 strokes pumped (DP 1120 psi - casing 470 psi). Attempted to work pipe through annular preventor to break pack off with no success. PU 320K SO 100K. PROD1 Bled pressure off of well. Open annular preventer. Worked pipe free with rotation at 50 RPM at 18K torque. Slowly brought up pump to 30 spm at 310 psi. Pumped 14 bbls of mud total with 1 bbl gain. Shut down pump and closed well back in with annular peeventer. Attempted to resume circulating schedule. Drill pipe immediately packed off and DP pressure increase to 600 psi with slow bleed off. Bled off pressure and and opened annular began working pipe. RPM 80 TO 15-20K- Broke circulation at 1.5 bpm and increased to 3.0 bpm. Pumped a total of 34 bbls and gained 2 bbls of mud in pits. Shut down rotary and pump and closed in well with annular preventer. Attempted to resume pumping schedule and drill pipe instantly packed off with 900 psi on drill pipe. Bled off drill pipe pressure. Monitored well and DP pressure increase to 40 psi -casing 170 psi. PROD1 Bled off pressure and opened up annular preventer. Broke pipe free with 260K to 310K and starting rotating pipe slowly bring up pumps. Rotating pipe weight 190 K slowly increased pumps to a max rate 6.5 bpm at 600 to 800 psi. Circulated 12.5 ppg KW mud to surface. Had small amount of gas to surface with bottoms up. PROD1 Attempt to clean up well -Ream to bottom from 8220 to 8210' packing off with 5 bpm - pp 650 to 750 - Con't work to bottom - Back ream from 8257' to 8169' -From 8255 to 8200- packing off ratty -from 8200 to 8169 -hole in fairly good shape -Ream back to bottom -From 8210 to 8255 -packing off very ratty - Back ream from 8255 to 8200' hole packing off -hole conditions deteriorating - 4.5 to 5 bpm max flow rate through that section -Back ream from 8200 to 8169' -Flow check well - Well static - (Tested Hydraulic choke with test pump -would not hold any pressure) - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone / Siltstone) over shakers -Loss 25 bbls mud PROD1 Attempt to pump out with 5 bpm - 720 psi -Packing off at 8160' - Back ream from 8160' to 8130 -Packing off - 5 bpm - 730 psi Printed: 6/5/2007 10:10:35 AM ~ ~ BP AMERICA Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPF-99 MPF-99 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 12/6/2006 Rig Release: 1/17/2007 Rig Number: Date I From - To Hours Task Code I NPT ~ Phase 12/29/2006 23:30 - 00:00 0.50 DRILL N DPRB PROD1 12/30/2006 00:00 - 02:30 2.50 DRILL N DPRB PROD1 02:30 - 03:00 I 0.501 DRILL I N I DPRB I PROD1 03:00 - 11:30 I 8.501 DRILL I N I I PROD1 11:30 - 12:30 I 1.001 DRILL I N I DPRB I PROD1 12:30 - 00:00 ~ 11.501 DRILL ~ P PROD1 12/31!2006 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ P ~ ~ PROD1 01:00 - 02:00 I 1.001 DRILL I P I I PROD1 02:00 - 03:30 1.501 DRILL P PROD1 03:30 - 06:00 2.50 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 07:00 - 08:00 i.00 DRILL P PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 13:00 4.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PRODi 14:00 - 15:00 1.00 DRILL P PRODi 15:00 - 16:00 1.00 DRILL P PRODi 16:00 - 16:30 0.50 DRILL P PROD1 16:30 - 17:30 1.00 DRILL N RREP PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 23:30 I 4.501 DRILL t P 23:30 - 00:00 I 0.501 DRILL I P PROD1 PROD1 Page 8 of 24 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) over shakers Back ream from 8130 to 7887' -Packing off bad / tight ~ 8015' to 7969 - BPM 5 - PP 750 -RPM 110 - T014K - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) - Loss 21 bbls pump out Circulate -Setting deflexion to zero on Geo-pilot -GPM 411 - PP 1700 -RPM 50 - TO 10K -ECD 13.42 CBU -Reciprocate -Casing load with cuttings -RPM 70 - TO 10K-GPM 411 to 480-PP 1700 to2130-65%CIay35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) shale over shakers (Change out Hydraulic choke) While cleaning up 9 5/8" casing -Add black products for shale stability ~ 9 5/8" casing shoe - (Continue change out hydraulic choke) -GPM 411 to 480 - PP 1700 to 2170 -RPM 70 - TO 10k Wash and ream from casing shoe to bottom ~ 8257' - PUWT 215k -SOW 145k - ROWT 175k -GPM 450 PP 1920 -ROT 120 - TO 15 -ECD 13.09 (hole in good shape) Directional drill 8 1/2" hole f/ 8257' - 8260'. (minor pack-off - reduced pump rate, back ream stand, hole cleaned up) WOB 8 -RPM120-TOon15/off13K-GPM400-PP1950on/ 1950 off -PUW 215 -SOW 145 - ROTW 175 -ECD 13.26 - Con't Directional Drill 8 1/2" hole f/ 8260' to 8575' - WOB 15 / 18-RPM 140-T015Kon-off 13K-GPM 450-PP2210on- 2000 off -PUW 220 -SOW 145 -ROT 175 -ECD 13.36 Directional Drill 8 1/2' hole from 8575' to 8637'-15 WOB - RPM 140 - TO 15K on / 13kK off -GPM 440 - PP on 2200 / 2100 off -PUW 220 -SOW 145 - ROTW 175 -ECD 13.4 Circulate and condtion hole to reduce ECD from 13.4 ppg EMW to 13.2 ppg EMW. - 445 GPM C~ 1900 psi Directional Drill 8 1/2" hole from 8637' to 8670 ' - TD - 15 WOB -RPM140-TOon16/off 14-GPM440-PP2190 on/2040 off -PUW 220 -SOW 145 - ROTW 179 -ECD 13.2 CBU - 3X. 450 GPM @ 2000 psi - 150 RPM - 15K TO - 13.05 Pump out to shoe @ drlg rate CBU ~ shoe -GPM 470 - PP 2200 -RPM 100 - TO 10K Flow check -Well Static Pump dry job - POH from 7880' to 810' Stand back HWDP -Jars - LD Flex DC's -Float sub Down load MWD -Service Geo-pilot LD - TM, MWD, DM, Geo-pilot, Bit Clear rig floor of vendors tools Repair Iron roughneck -Change out top jaw PU Reaming BHA - 9 1/2" Rhino reamer - Bakerlok / bullnose - Circ sub - 1 HWDP - Stabailzer - 6 HWDP -Jars - 14 HWDP RIH from 687' to 7954 -Filling pipe every 25 stands -RIH to 7974' -Bring up pump to 254 gpm 1200 psi -Open blades - Pick up to locate casing shoe - PU 215 -SOW 145 - ROTW 175 Attempt to rotate -Stalling out at 25K -Shut down pump - Work string -Bring pump back on line - Re-start procedure locating bottom of shoe -Start reaming from 7955' to 8000 ' - Printed: 6/5!2007 10:10:35 AM ~ M BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 ,Rig Name: DOYON 14 Rig Number: Date From - To ~li 12/31 /2006 -- 23:30 - 00:00 1 / 1 /2007 00:00 - 00:30 00:30 - 01:00 Hours I Task I Code I NPT I Phase 0.50 DRILL P 0.50 DRILL P PROD1 PROD1 0.501 DRILL I P 01:00 - 20:30 I 19.501 DRILL I P 20:30 - 22:30 I 2.001 DRILL I P PROD1 PROD1 PROD1 22:30 - 23:30 I 1.001 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/2/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:00 0.50 DRILL P PROD1 01:00 - 02:30 1.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 06:30 3.50 DRILL P PROD1 06:30 - 07:30 1.00 DRILL P PROD1 07:30 - 08:30 1.00 BOPSU P PROD1 08:30 - 09:30 1.00 CASE P PROD1 09:30 - 12:00 2.50 CASE P PROD1 12:00 - 13:00 1.00 CASE P PROD1 13:00 - 20:30 7.50 CASE P PROD1 20:30 - 23:00 2.50 CASE P PROD1 23:00 - 23:30 0.50 CASE P PROD1 23:30 - 00:00 0.50 CASE P PROD1 1/3/2007 00:00 - 03:30 3.50 CASE P PROD1 03:30 - 05:00 I 1.501 CEMT I P I I PROD1 05:00 - 06:00 I 1.001 CASE I P I I PROD1 Page9of24~ Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations GPM 450 -PP 2060 -RPM 100 - TO 13K Ream from 8000 to 8053' - 6% flow increase -Pit gain of 3 bbls on bottoms up -Work string back up to shoe -Tight overpull of 100K -packing off -Shut down pump -Work string up to shoe with out pump Flow check /well flow 2 bbl gain -Shut in well - (More then likely DP air from fill ups) Monitor we1125 mins - No DPP - NO SICP -Open Annular -Well static -Circulate 2200 stks air out of mud Ream hole from 7979' to 8670' - WOB 2 K -RPM 100 to 130 - TO 13K -GPM 450 - PP 2000 to 2135 (Reaming 45' to 55' fUhr) -Torque or stall depths 8114, 8218, 8264, 8378, 8431, 8455, 8467, 8518, 8532, 8567, 8596 -Increase weight on reamer to 5 to 8K - 8383, 8410, 8419 to 8421', 8467, 8518, 8532, 8596, 8655 -Back ream each stand from 8426' to TD 8670' CBU3X-RPM 130-T010K-GPM450-PP2060-PUW 200 -SOW 150 - ROTW 175 -Reciprocate string 75' strokes Pump out from 8670' to 8329' at 450 GPM - PP 1970 -PUW 200 to 215 -Pump out from 8329' to 7990' at 210 GPM - PP 600 -PUW 210 to 220 -Pull from 7990' to 7943' without pump - PUW 210 to 220 - 7960' PUW 220 - No Pack-off -Hole in good shape CBU - 7943 -GPM 500 - PP 2330 Con't CBU -GPM 500 - PP 2350 @ 7944' Pull 3 stands watch for swab - No Swab observed -RIH Drop ball to open circ sub -CBU 2 X -GPM 500 - PP 1430 - RPM 120 - TO 6K with rotary -Metal shavings coming back to surface -Shut down rotary -CBU 1 X - Reciprocating string - Shakers clean Flow check -Well static Dry job - POH from 7944' to 687' Stand back HWDP - UD BHA Pull wear ring -Install test plug -Test annular to 250 psi low, 2500 psi high for 5 minutes each - R/D -Install wear ring PJSM - R/U to run 7 5/8" liner Run 7 5/8" liner and M/U hanger Install gel seal in packer RIH with 7 5/8" liner on 5" DP from 905' to 7925' (fill pipe every 10 stds, break circulation every 20 stands) Circulate hole clean C 7925' (560 psi @ 5 BPM, PU 210, SO 150) RIH with 7 5/8" liner to 8645' M/U cement head on single drill pipe - M/U to top drive Circulate hole clean -Stage pump up from 84 GPM to 212 GPM ~ 370 psi to 670 psi -Reciprocate 20' (PU 210, SO 145) Cement per plan (5 bbls water, Test lines to 4000 psi, 32 bbls 13.5 mud push, 53 bbls 15.8 cement, Drop dart, Displace with rig pump 50 SPM C~ 380 ICP, 680 FCP, slow pump to 1.5 BPM to latch up liner and bump plug @ 1676 total strokes, Pressure to 2500 psi) -Reciprocate 20' -Cement in place ~ 0500 hours Set hanger and packer per Baker rep -Check floats -Circulate cement above liner lap out of hole (Appr. 5bbls cement back) Printed: 6/5/2007 10:10:35 AM A BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 /3/2007 MPF-99 MPF-99 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 12/6/2006 Rig Release: 1/17/2007 Rig Number: From - To Hours i Task i Code ~ NPT Phase 06:00 - 06:30 0.50 CASE P PROD1 06:30 - 08:00 1.50 CASE P PROD1 08:00 - 09:00 1.00 CASE P PROD1 09:00 - 10:30 1.50 CASE P PROD1 10:30 - 13:30 3.00 CASE P PROD1 13:30 - 14:30 1.00 CASE P PROD1 14:30 - 16:00 1.50 CASE P PROD1 16:00 - 16:30 0.50 BOPSU P PROD1 16:30 - 17:30 1.00 BOPSU P PROD1 17:30 - 22:30 5.00 BOPSU P PROD1 22:30 - 23:00 0.50 BOPSU P PROD1 23:00 - 23:30 0.50 CASE P PROD1 23:30 - 00:00 0.50 CASE P PROD1 ,1/4/2007 00:00 - 01:00 1.00 CASE P PROD1 01:00 - 01:30 0.50 CASE P PROD1 01:30 - 02:30 1.00 CASE P PROD1 02:30 - 04:00 1.50 CASE P PROD1 04:00 - 05:30 1.50 CASE P PROD1 05:30 - 09:30 4.00 CASE P PROD1 09:30 - 10:00 0.50 CASE P PROD1 10:00 - 11:00 1.00 EVAL P PROD1 11:00 - 13:00 2.00 DRILL P PROD1 13:00 - 14:30 1.50 DRILL P PRODi 14:30 - 17:00 2.50 DRILL P PRODi 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 19:30 1.50 DRILL P PROD1 19:30 - 20:30 1.00 DRILL P PRODi 20:30 - 22:30 2.00 DRILL P PROD1 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/5/2007 00:00 - 15:00 15.00 DRILL P PROD1 15:00 - 20:30 5.50 DRILL P PROD1 20:30 - 00:00 I 3.501 DRILL P I PROD1 11/6/2007 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 Page 10 of 24 Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations UD cement head and hoses Pump nut plug sweep and CBU 2X - (560 gpm ~ 1440 psi) - Reciprocate pipe full stand POOH 10 stands to 6825' -Pump dry job Cut and slip drill line -Service top drive POOH from 6825' to 228' POOH UD 6 joints 5" drill pipe and 7.625 packer running tool RIH with 7 stands HWDP and jars from derrick and UD same Pull wear ring and install test plug R/U to test BOPE Test BOP's -Annular 250 low 2500 high -Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Lou Grimaldi with AOGCC waived witness of BOP test -All test were witnessed by WSL Pull test plug -Install wear ring Mobilize drilling BHA to rig floor -Change elevators P/U drilling BHA - M/U MWD, near bit stab, & bit Cont M/U drilling BHA Upload MWD Cont M!U drilling BHA -Surface test MWD (200 gpm ~ 1060 psi) P/U 4" HWDP & 4" drill pipe from pipe shed Fill pipe and test MWD 250 GPM @ 1500 psi -Not getting good detection -Trouble shooting -Aired up mud RIH to 8456' Circulate drill pipe volume (270 GPM @ 2200 psi) Test casing to 1000 psi for 30 minutes (Good) Drill latch collar, cement, float collar, cement to 8665' (PU 225, SO 140, RW 170, WOB 5-8, 255 GPM, 2020 psi, 80 RPM, 13 TO) Circulate hole clean (255 GPM ~ 2020 psi) Pump 70 bbls treated H2O, 40 bbls high vis sweep -Displace to 10.0 ppg mud (Initial 2300 psi, final 270 gpm @ 1650 PSI) Drill out shoe and 20' new hole to 8690' (1900 psi ~ 270 GPM, WOB 12, PU 220, SO 160, RW 175, 80 Rpm, 13 TO) Circulate hole clean (1750 psi ~ 290 GPM) R/U -Perform FIT (MD 8670', TVD 6989', MW 10.1 ppg, 872 psi) - EMW = 12.5 ppg (Good test) - R/D Drill from 8690' to 8738' TVD 7014' (PU 215, SO 160, RW 185, WOB 12, 1700 psi, 290 GPM, 80 RPM, 13 TO) ADT= 1.04 hrs Circulate hole clean - R & R (290 GPM, 1700 psi) Check flow (static) -Pull 1 stand into casing Clean pits and prepare for coring fluid Offload oil base mud to pits -Heat oil base mud to 90 degrees using Hot Oil services PJSM -Displace well to 10 ppg oil base mud (pump 100 bbls H2O /soap, 100 bbls high vis 10 ppg spacer, 40 bbls high vis sweep, 520 bbls OBM) (252 GPM @ 2100 psi) Cont displace w/OBM (PU 225, SO 155, RW 180, 252 GPM, 2100 psi) (Monitoring hole while cleaning pits observed 1 bbl Printed: 6/5/2007 10:10:35 AM • BP AMERICA Operations. Summary Report ',Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: I Date From - To j Hours Task Code j NPT Phase i _ _ - - -- 1/6/2007 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:00 0.50 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 05:30 2.50 DRILL P PROD1 05:30 - 06:30 1.00 DRILL P PROD1 06:30 - 08:00 1.50 DRILL P PRODi 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 11:00 2.50 DRILL P PROD1 11:00 - 12:30 1.50 DRILL P PROD1 12:30 - 16:30 4.00 DRILL P PROD1 16:30 - 20:30 4.00 DRILL P PROD1 20:30 - 21:00 0.50 DRILL P PROD1 21:00 - 22:00 1.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 1/7/2007 00:00 - 00:30 0.50 EVAL P PRODi 00:30 - 03:30 3.00 EVAL P PROD1 03:30 - 06:00 2.50 EVAL P I PROD1 06:00 - 10:00 4.00 EVAL P PROD1 10:00 - 14:00 4.00 EVAL P PROD1 14:00 - 16:00 I 2.001 EVAL I P I I PROD1 16:00 - 00:00 8.00 EVAL P PROD1 1/8/2007 00:00 - 02:30 2.50 EVAL P PROD1 02:30 - 03:00 I 0.501 EVAL I P I I PRODi 03:00 - 10:00 7.00 EVAL P PROD1 10:00 - 10:30 0.50 EVAL P PROD1 14:00 - 18:00 I 4.00 EVAL P I PROD1 PROD1 18:00 - 19:00 1.00 EVAL N DFAL PROD1 19:00 - 21:00 2.00 EVAL N DFAL PROD1 21:00 - 00:00 3.00 EVAL N DFAL PROD1 1/9/2007 00:00 - 00:30 0.50 EVAL N DFAL PROD1 00:30 - 01:30 1.00 EVAL N DFAL PROD1 01:30 - 02:30 1.00 EVAL N DFAL PROD1 02:30 - 03:30 1.00 EVAL N DFAL PROD1 03:30 - 05:30 2.00 EVAL N DFAL PROD1 Page 11 of 24 I Spud Date: 12/13/2006 End: 1/10/2007 Description of Operations gain over 20 hour period. Had traces of oil with bottoms up.) Clean out trough, hole fill line -Stand back 1 stand -Observe well PJSM -Handling core barrel and shuttle practice run Drill from 8738' to 8786' (PU 225, SO 155, RW 180, RPM 100, TO 11, 290 GPM, 2750 psi) CBU - R & R (100 RPM, 290 GPM, 2750 psi) Pump out of hole from 8786' to 8079' Clean floor -Observe well -Mobilize coring tools to rig floor Pump 12 ppg pill -POOH from 8079' to 5240' Review core handling procedures with both crews while changing out Hi-Line breaker POOH from 5240' to 1628' C/O elevators & roughneck to handle 4" work string & BHA - POH w/4" DP &HWDP - UD NMDC & stabs Download MWD UD MWD, stab, & bit Clean rig floor (oil base mud) Continue clean floor -Mobilize coring tools to floor PJSM - M/U outer core barrels, 6.75" core bit - P/U & space out inner barrels P/U DC's &HWDP - M/U core BHA -Surface test BHA (100 GPM C~3 80 psi) RIH from 1978' to 8588' (fill pipe every 25 stands) Circulate hole and pit volume mixing tracer into system (180 GPM ~ 1060 psi) M/U space out pups -Wash down to 8786' (PU 205, SO 155, 168 GPM, 910 psi) -Pull up to 8693' -Drop ball -Circulate ball down (psi increase to 1540 psi ~ 150 GPM) Coring from 8786' to 8831' (PU 210, SO 155, RW 180, 1260 psi, 150 GPM, WOB 12/20, TO 6/11) Coring to 8831' -Total 45' of core cut -Last 2 1/2 hours no progress, POOH to evaluate (PU 210, SO 155, RW 180, 1260 psi, 150 GPM, WOB 12/20, RPM 60, TO 6/9) Pump out of hole 5 stands (25 to 35K overpull up to 7760' or top of liner) Observe well (static) -Pump dry job -POOH to 1978' Clean floor - C/O rubbers in mud bucket, and elevators to work 4" work string POOH with 4" DP, HWDP, DC's Pull core barrels - Break off bit -Pull inner barrels -Gamma log cores - UD inner cores to pipe shed (Recovered 45' core, bit was not damaged apparently core jammed in inner barrels) Clean OBM from rig floor M/U inner core barrels & install in outer barrels - M/U bit & coring BHA RIH to 7172' (fill pipe every 25 stands) Cont RIH from 7172' to 7770' Slip and cut drill line Service top drive and blocks Space out -RIH from 7770' to 8735' Wash down to 8828' (tight ~ 8795') -Drop ball and circulate ball down (PU 210, SO 155, RW 180, 100 GPM, 650 psi) Printed: 6/5/2007 10:10:35 AM • • BP AMERICA Page 12 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task i Code NPT Phase Description of Operations I_ - - _- - ----_ _. 1/9/2007 05:30 - 15:00 9.501 EVAL N DFAL PROD1 Core from 8831' to 8867' (no progress past 8867') (PU 220, 15:00 - 17:00 2.00 EVAL N DFAL PROD1 17:00 - 17:30 0.50 EVAL N DFAL PROD1 17:30 - 22:00 4.50 EVAL N DFAL PROD1 22:00 - 23:00 1.00 EVAL N DFAL PROD1 23:00 - 00:00 1.00 EVAL N DFAL PROD1 1/10/2007 00:00 - 02:00 2.00 EVAL N DFAL PROD1 02:00 - 07:00 5.00 EVAL N DFAL PROD1 07:00 - 08:30 I 1.501 EVAL I N I DFAL I PROD1 08:30 - 12:30 4.00 EVAL N DFAL PROD1 12:30 - 13:00 0.50 EVAL N DFAL PROD1 13:00 - 14:00 1.00 EVAL N DFAL PROD1 14:00 - 17:30 3.50 EVAL N DFAL PROD1 17:30 - 18:00 0.50 EVAL N DFAL PROD1 18:00 - 20:00 I 2.00 i EVAL I N I DFAL I PROD1 20:00 - 20:30 0.50 EVAL N DFAL PROD1 20:30 - 23:00 2.50 DRILL N DFAL PROD1 23:00 - 00:00 1.00 EVAL N DFAL PROD1 1/11/2007 00:00 - 02:30 2.50 EVAL N DFAL PROD1 02:30 - 04:00 1.50 EVAL N DFAL PROD1 04:00 - 06:00 2.00 EVAL N DFAL PROD1 06:00 - 09:00 3.00 EVAL N DFAL PROD1 09:00 - 10:30 1.50 EVAL N DFAL PROD1 10:30 - 11:00 0.50 EVAL N DFAL PROD1 11:00 - 12:00 1.00 EVAL N DFAL PROD1 12:00 - 13:00 1.00 EVAL N DFAL PROD1 13:00 - 17:00 4.00 EVAL N DFAL PROD1 17:00 - 19:00 2.00 EVAL N DFAL PROD1 19:00 - 22:30 3.50 EVAL N DFAL PROD1 22:30 - 00:00 1.50 EVAL N DFAL PROD1 1/12/2007 00:00 - 00:30 0.50 EVAL N DFAL PROD1 00:30 - 01:30 1.00 EVAL N DFAL PROD1 01:30 - 02:30 1.00 EVAL N DFAL PROD1 02:30 - 09:00 6.50 EVAL N DFAL PROD1 SO 155, RW 180, WOB 15-25, RPM 40/70, TO 5-18, 1240 psi, 150 GPM) Pump out of hole 10 stds Flow check (static) -Pump dry job -Blowdown top drive POOH from 7929' to 1978' C/O elevators & mud bucket rubbers to handle 4" work string - Clean OBM from floor Stand back 11 stands 4" DP & 1 stand 4" HWDP Stand back BHA to core barrels Pull inner core barrels (only 5' of core recovered) -Inspect inner barrels -Pull outer barrels - UD and inspect same - L/D bit Clean OBM from rig floor -Service top drive -Discuss options with town M/U cleanout BHA to 250' -Test MWD (good test) Lubricate rig Continue RIH w/ BHA to 2025' - C/O to 5" elevators RIH from 2025' to 8670' (fill every 25 stands) Wash to bottom @ 8865' (PU 212, SO 155, 1920 psi, 280 GPM) Surrey ~ 8865' MD -Pull up to 8809' MD -Survey -Wash to bottom -Mad pass from 8865' to 8721' (PU 212, SO 155, RW 180, RPM 50, TO 12, 1860 psi, 280 GPM) Evaluate logs Drill from 8865' to 8872' MD, 7057' TVD (PU 212, SO 155, RW 180, 100 RPM, TO 9, WOB 13, 1970 psi, 284 GPM) Circulate hole clean - R & R - (100 RPM, TO 10, 2100 psi, 300 GPM) Continue circulate hole clean - R & R (PU 212, SO 155, RW 180, RPM 100, TO 10, GPM 300, 2050 psi) Pump out of hole from 8870' to 7770' Circulate hole clean @ top of liner w/ 300 gpm 1950 psi - R& R w/ 40 rpm Observe well (static) -Pump dry job -Blowdown top drive - POOH to 2029' Stand back cleanout BHA Download MWD UD MWD, junk basket, bit Clear floor of vendor tools -Clean OBM off floor P/U M/U outer core barrels and stabilizers - M/U inner barrels and space out - M/U bit RIH with core run #3 BHA C/O to 5" elevators -RIH from 1950' to 8653' (fill pipe every 25 stands) Cut and slip drill line -Service top drive -Circulating @ 740 psi, 150 GPM Continue circulate bottoms up (150 GPM @ 740 psi) Wash from 8653' to 8872' (PU 215, SO 155, RW 180, 740 psi, 150 GPM) Pull up to 8844' - Drop ball -Circulate ball down Coring #3 run from 8872' to 8876' (no progress) (126 gpm 800 psi - WOB 2-17k) Printed: 6/5/2007 10:10:35 AM ~ • BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: 1/1 Date ~ From - To Hours Task Code ! NPT Phase _1 _- - ----~ 2/2007 09:00 - 11:00 2.00 EVAL N DFAL PROD1 11:00 - 15:00 4.00 EVAL N DFAL PRODi 15:00 - 17:00 2.00 EVAL N DFAL PROD1 17:00 - 20:00 3.00 EVAL N DFAL PRODi 20:00 - 20:30 0.50 EVAL N DFAL PROD1 20:30 - 00:00 3.50 EVAL N DFAL PROD1 1/13/2007 00:00 - 03:00 3.00 EVAL N DFAL PROD1 03:00 - 04:30 1.50 EVAL N DFAL PROD1 04:30 - 05:00 0.50 EVAL N DFAL PROD1 05:00 - 17:00 12.00 DRILL N DFAL PROD1 17:00 - 20:00 3.00 DRILL N DFAL PROD1 20:00 - 20:30 0.50 DRILL N DFAL PROD1 20:30 - 21:00 0.50 DRILL N DFAL PROD1 21:00 - 23:00 2.00 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL N DFAL PROD1 1/14/2007 100:00 - 01:30 I 1.501 DRILL I N I DFAL I PROD1 01:30 - 03:00 1.50 DRILL N DFAL PROD1 03:00 - 06:00 3.00 DRILL N DFAL PROD1 06:00 - 07:30 1.50 DRILL N DFAL PROD1 07:30 - 10:00 2.50 DRILL N DFAL PROD1 10:00 - 11:00 1.00 DRILL N DFAL PROD1 11:00 - 13:00 2.00 EVAL N DFAL PROD1 13:00 - 19:00 6.00 EVAL N DFAL PROD1 19:00 - 20:00 1.00 CEMT N DFAL PROD1 20:00 - 22:00 2.00 CEMT N DFAL PROD1 22:00 - 00:00 2.00 CEMT N DFAL PROD1 1/15/2007 00:00 - 00:30 0.50 CEMT N DFAL PROD1 00:30 - 01:00 0.50 CEMT N DFAL PROD1 01:00 - 01:30 0.50 CEMT N DFAL PROD1 01:30 - 03:30 2.00 CEMT N DFAL PROD1 03:30 - 04:30 1.00 CEMT N DFAL PROD1 04:30 - 05:30 1.00 CEMT N DFAL PROD1 05:30 - 07:30 2.00 CEMT N DFAL PROD1 07:30 - 14:30 I 7.001 CEMT I N I DFAL I PROD1 14:30 - 15:00 0.50 EVAL N DFAL PROD1 15:00 - 15:30 0.50 EVAL N DFAL PROD1 15:30 - 16:30 1.00 EVAL N DFAL PROD1 Page 13 of 24 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations Pump out of hole f/ 8876'-7710' w/ 145 gpm, 1000 psi Observe well - POH w/ 5" DP to 1950' Stand back 4" DP, HWT, jars, DC's. PJSM - UD coring assembly #3 (Core catcher was pushed up into core barrel 1 1/2 feet jamming barrel, recovered 5" of cores) Clear and clean rig floor M/U drilling BHA RIH from 2027' to 8637' (fill pipe every 25 stands) CBU (PU 210, SO 155, RW 180, 295 GPM, 2230 psi) Wash to 8876' Drill from 8876' to 9106' (PU 215, SO 155, RW 180, 292 GPM, 2140 psi, 100 RPM, TO 9, WOB 20} CBU 3X - R & R (100 RPM, 300 GPM, 2140 psi) Flow check (static) -Pump out of hole from 9106' to 8670' (300 GPM C~ 2140 psi) Flow check (static) - RIH to 9106' CBU 2X - R & R (300 GPM, 2100 psi, 100 RPM) Pump out of hole from 9106' to 8525' (300 GPM, 2100 psi, PU 210, SO 155) Continue pump out of hole from 8525' to 7692' (300 GPM, 2050 psi) CBU 2X - R & R (300 GPM, 2050 psi, 40 RPM, TO 7) Check flow (static)- Pump dry job -POOH from 7692' to 2027' Stand back 4" DP, HWDP, DC's UD 4 3/4" flex DC's -Download MW D -Flush MW D w/LVT fluid - UD MW D & bit Clear and clean OBM from rig floor Mobilize and R/U SWS wireline Run USIT/CBL logs to 8665' -USIT log failed during operation - Continued w/ CBL f/ 8665' to 7745' - R/D SWS Mobilize and R/U to run 3 1/2" tubing PJSM -RIH with 17 joints 3 1/2" IBT tubing and 4" HT-38 drill pipe RIH w/5" drill pipe from 1570' to 7235' (PU 172, SO 140) Cont RIH from 7235' to 8652' Circulate pipe volume ~ 8652' (210 GPM, 700 psi) RIH from 8652' to 9024' -Wash to 9106' (PU 197, SO 155, 256 GPM, 850 psi) Circulate and condition mud -PJSM -Batch up cement PJSM -Pump 10 bbls 12 ppg OBM spacer, Test lines to 2500 psi, Pump 27 bbls 15.8 ppg gas bloc cement, Pump 2.25 bbls 12 ppg OBM spacer, Drop wiper ball, Displace with OBM 1400 strokes with rig (Cement in place (~ 04:30) POOH 10 stands to 8163' Pump nut plug sweeps and circulate hole clean (420 GPM, 1100 psi, 30 bbls contaminated OBM overboard) Circulate @ 8163' -Wait on cement (155 GPM, 460 psi) - Clean mud pits 3,4 & 5, flush lines, and surface equipment RIH -Tag cement at 8620' MD with 10 K down weight Circulate pipe volume (300 GPM, 1160 psi) R/U test equipment -Test casing to 1200 psi for 30 minutes (good test) - RD test equipment Printed: 6/5/2007 10:10:35 AM • • BP AMERICA Page 1 ~ of 24 Operations Summary Report Legal Well Name: MPF-99 ,Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 ~IContractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To I Hours ~ Task i Code i NPT Phase Description of Operations 1/15/2007 16:30 - 21:00 4.50 EVAL ~ N ~ DFAL (PRODi PJSM -Circulate while loading pits w/seawater -Displace OBM 'I i 21:00 - 22:00 1.00 EVAL N DFAL PROD1 22:00 - 23:00 1.00 EVAL N DFAL PROD1 23:00 - 00:00 1.00 EVAL N DFAL PROD1 1/16/2007 00:00 - 02:30 2.50 TA N DFAL ABAN 02:30 - 03:30 1.00 TA N DFAL ABAN 03:30 - 06:00 2.50 TA N DFAL ABAN 06:00 - 07:00 1.00 TA N DFAL ABAN 07:00 - 08:00 1.00 TA N DFAL ABAN 08:00 - 11:30 3.50 TA N DFAL ABAN 11:30 - 12:30 1.00 TA N DFAL ABAN 12:30 - 13:30 1.00 TA N DFAL ABAN 13:30 - 14:00 0.50 TA N DFAL ABAN 14:00 - 17:00 3.00 TA N DFAL ABAN 17:00 - 19:00 2.00 TA N DFAL ABAN 19:00 - 20:00 I 1.001 TA I N DFAL ABAN 20:00 - 21:00 1.00 TA N DFAL ABAN 21:00 - 22:00 1.00 BOPSU N DFAL ABAN 22:00 - 22:30 0.50 BOPSU N DFAL ABAN 22:30 - 00:00 1.50 TA N DFAL ABAN 1/17/2007 00:00 - 01:30 1.50 TA N DFAL ABAN 01:30 - 02:30 1.00 TA N DFAL ABAN 02:30 - 04:00 1.50 TA N DFAL ABAN 04:00 - 04:30 0.50 TA N DFAL ABAN 04:30 - 06:30 2.00 BOPSU N DFAL ABAN 06:30 - 08:00 1.50 BOPSU N DFAL ABAN 08:00 - 09:30 1.50 BOPSU N DFAL ABAN 09:30 - 11:00 1.50 TA N DFAL ABAN 11:00 - 12:00 1.00 TA N DFAL ABAN 12:00 - 14:00 2.00 TA N DFAL ABAN 14:00 - 14:30 0.50 TA N DFAL ABAN 14:30 - 15:00 0.50 TA N DFAL ABAN 15:00 - 17:00 2.00 TA N DFAL ABAN w/8.5 seawater (pump 20bbls LVT, 80 bbls 10 ppg LSND with safe surf O, 560 bbls sea water, 300 GPM, 990 psi) -Returns did not clean up ,ordered more seawater Turn water on throughout rig -Clean rig floor, drip pan, mud pits of OBM UD 21 jts 5" drill pipe -RIH 7 stds from derrick Continue clean rig and pits of OBM while waiting on seawater Continue cleaning pits, rig floor, and pollution pans of OBM while waiting on clean seawater Pump 30 bbl hi-vis sweep and displace with clean seawater (420 GPM, 1200 psi) Pump dry job - Blowdown top drive -POOH UD 5" drill pipe from 8620' to 6526' Slip & cut drilling line Service rig -Blocks, Top Drive ,Crown, Draw-works Continue UD 5" DP to 1570' Change elevators -Clear floor - UD 4" DP to 522' RIH w/ mule shoe - 3 1/2" tubing - 4 3/4" drill collars - 4" HWDP to 1350' Circulate 120 degree seawater surface to surface / 500 GPM / 970 PSI LD 4" HWDP - 4 3/4" drill collars - 3 1/2" tubing -mule shoe - Clear rig floor PJSM -Change out Saver sub to 4" HT -Clean oil base mud from torque tube -Change out Dies and guide on iron roughneck RU stack washer -Flush out stack w/ hot water /function rams - RD stack washer Pull wear ring -Install test plug PJSM -Change out rams to 2 7/8" x 5" VBR's RU test equipment -Test bonnet door seals to 1500 psi f/ 5 mins. -Record on chart - RD test equip. PJSM - RU tubing equipment -Run 2 7/8" kill string Con't RIH with 2 7/8" Kill string to 2194' MU Head pin -Reverse circ 165 bbls 100 degree seawater RD head pin - MU Tubing hanger -Land tubing ~ 2225' - RILDS -Test from below to 1000 psi for 10 mins LD landing joint - RD tubing equipment -Clear floor of tools and equipment Nipple down BOP's -Riser - Flowline Nipple up Adapter Flange, Tree Test Adapter flange to 5000 psi -Test tree (TWC leaking) - Change hobbit in TWC -Test tree to 5000 psi -Good test -Pull TWC RU Hot Oil truck to pump diesel freeze protect Clear /Clean Rig floor/ cellar -Wait on diesel for freeze protect to arrive from WOA PJSM -Freeze protect tubing - IA -with 156 bbls diesel for Hot Oil - 1.78 bpm - ~ 500 psi U-tube Diesel for 30 mins -Clean pits Install BPV -Test to 1000 psi -Suck lines out - RD hot oil RD lines -Clear cellar area -Secure tree -Rig released C~ Printed: 6/5/2007 10:10:35 AM ~ • BP AMERICA Operations Summary Report Legal Well Name: 'Common Well Name 'Event Name: 'Contractor Name: Rig Name: MPF-99 MPF-99 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 12/6/2006 Rig Release: 1/17/2007 Rig Number: Date ! From - To j Hours Task Code NPT ~ Phase 1/17/2007 15:00 - 17:00 2.00 TA N DFAL ARAN 4/19/2007 00:00 - 03:00 3.00 MOB N DFAL PRE 03:00 - 07:00 4.00 MOB N DFAL PRE 07:00 - 08:00 1.00 RIGU N DFAL PRE 08:00 - 11:00 3.00 RIGU N DFAL PRE 11:00 - 14:00 3.00 STKOH N DFAL PROD1 14:00 - 16:00 2.00 STKOH N DFAL PROD1 16:00 - 17:30 1.50 WHSUR N DFAL PROD1 ', 17:30 - 21:00 3.50 BOPSU N DFAL PROD1 ~I 21:00 - 0.00 BOPSU N DFAL PROD1 4/20/2007 00:00 - 01:30 1.50 BOPSU N DFAL PROD1 01:30 - 02:00 0.50 BOPSU N DFAL PROD1 02:00 - 04:00 2.00 WHSUR N DFAL PROD1 04:00 - 07:00 3.00 BOPSU N DFAL PROD1 07:00 - 08:00 1.00 BOPSU N DFAL PROD1 08:00 - 09:30 1.50 W HSUR N DFAL PROD1 09:30 - 10:00 0.50 STKOH N DFAL PROD1 10:00 - 13:00 3.00 STKOH N DFAL PROD1 13:00 - 15:00 2.00 BOPSU N DFAL PROD1 15:00 - 17:00 2.00 STKOH N DFAL PROD1 17:00 - 23:00 6.00 STKOH N DFAL PROD1 I 23:00 - 00:00 1.00 STKOH N DFAL PRODi i 4/21/2007 00:00 - 03:30 3.50 STKOH N DFAL PROD1 03:30 - 05:30 2.00 STKOH N DFAL PROD1 05:30 - 06:00 0.50 STKOH N DFAL PROD1 06:00 - 06:30 0.50 STKOH N DFAL PROD1 06:30 - 07:30 1.00 STKOH N DFAL PROD1 Page 15 of 24 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Description of Opje~ratio~ns 17:00 hrs C-J ~` ~~5 S ,~~, „" S'~ ~ l~''O`1 Move rig from Pesado-01 A to F-Pad Turn rig around on pad -Spot over well MPF-99i Skid rig floor from move to drlg Rig up rig floor -Pull BPV with DSM -Spot rock washer and berm same - IA 150 psi - Tubiing 100 psi - (Rig accepted ~ 10:00 hrs on 4/19/2007) Rig up on tree for displacement -Fill pits with seawater PJSM -Displace diesel -Pump seawater down tubing -Taking returns from annulus to tiger tank - 180 bbls -BPM 4 - PP 570 - Flow check -Well static Install TWC -Test from below to 1000 psi - 10 mins -Record on chart - ND Tree -Adapter flange -Verify hanger threads - 2 7/8" EUE 8 rd -Dry run 8.5 turns NU BOP's -Riser -Flow line -Change out choke hose adapter RU test equipment -Test BOP's -Annular 250 low 2500 high 5 mins each test -Top VBR's - 2 7/8" x 5" -Upper IBOP /Lower IBOP -Floor safety valve -Dart valve -Choke manifold - 250 low 4500 high 5 mins each test Test BOP's - Con't testing - HCR Choke /Kill -Manual Choke / Kill - 250 low 4500 high - 5 mins each test -Perform Accumulator test -Test Blinds - 250 low - 4500 high 5 mins each test -All test witnessed by WSL -Lou Grimaldi with AOGCC waived witness of BOP test - RD testing equipment -Close Annulus valves RU lubricator -Attempt to Pull TWC -Can not get screwed on to TWC -Back out lubricator - POH -Bottom XO left screwed into hanger PJSM -Break stack off tubing spool -Back out XO -Clean / vac off TWC -Clean area around and off top of TWC - NU Stack RU Testing equipment -Close blinds -Test break 250 low 4500 high 5 mins each test - RD testing equipment Dry rod out TWC -Screw landing joint in hanger -BOLDS -Pull hanger to rig floor - PU 12K CBU -GPM 340 - PP 720 - RU tubing equipment LD 2 7/8" tubing -Clear tubing equipment off floor - (71 jts 2 7/8" EUE 8rd tubing - 1 tubing hanger) Install test plug - RU testing equipment -Test Bottom VBR's 3 1/2" x 6" - 250 low 4500 high 5 mins each test - RD testing equipment -close Annulus valves -Pull test plug -Install wear ring Load /strap 4" DP in pipe shed - 300 joints PU 4" DP from pipe shed 1 x 1 to 7775' -Tag top of liner Work through liner top - to 7781 taking weight -Pull to 7776' - Break circulation -Pack off 800 psi no returns -Pull to 7770' pressure dropped off -Regained returns -Wash from 7770' to 7809' -Circulate DP vol 1.5 X -BPM 3 to 6 - PP 200 to 800 psi Flow check 10 mins -Well static - POH from 7770' to surface PU Jars - 2 Jts 4" HW DP - PU 42 jts DP 1 X 1 from pipe shed Circulate DP volume -GPM 250 - PP 200 POH from 1413' to surface Moblize BHA to rig floor Printed: 6/5/2007 10:10:35 AM BP AMERICA Page 16 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To i MPF-99 MPF-99 DRILL+C DOYON DOYON Hours OMPLE DRILLIN 14 Task I TE G INC Code . NPT Start Rig Rig Phase Spud Date: 12/13/2006 : 12/6/2006 End: 1/10/2007 Release: 1/17/2007 Number: Description ofi Operations 4/21/2007 07:30 - 09:00 1.50 STKOH N DFAL PROD1 MU Bit -motor -MWD - Up load MWD 09:00 - 09:30 0.50 STKOH N DFAL PRODi Con't MU BHA -Jars - HWDP -Surface test MWD -GPM 260 - PP - 940 - MW D not functioning 09:30 - 10:00 0.50 STKOH N SFAL PROD1 Trouble shoot MWD problems 10:00 - 13:30 3.50 STKOH N SFAL PROD1 Change out MWD -Orient - Up load - Con't MU BHA to 273' - Surface test MWD -GPM 260 - PP 940 -Test good 13:30 - 17:00 3.50 STKOH N DFAL PROD1 RIH from 273' to 7775' Top liner -Filling string every 25 stands - Con't RIH to 8433' -Wash from 8433' to 8620' tag cement 17:00 - 17:30 0.50 STKOH N DFAL PROD1 Drill cement from 8620' to 8653' - 315 to 320' per hour with 5 to 15K on bit -RPM 50 - TO 8K -GPM 250 - PP 1520 on 1420 off -PUW 200 -SOW 120 - ROTW 150 17:30 - 21:00 3.50 STKOH N DFAL PRODi Circulate -Flow check -Well flowing after 7 mins -Circulate Bottoms up -GPM 237 - PP 1410 psi -Flow increase after 2000 stks pumped from 28% to 31 % -From 2000 to 5000 stks flow 29% - No Increase in Pit volume seen -After 5500 stks pumped -Flow check well 6 mins -Well flowing - Con't circulate -Call town -Displace to MOB 21:00 - 00:00 3.00 STKOH N DFAL PRODi Prepare to displace to MOB mud 10 ppg -Displace to MOB mud -GPM 212 - PP 1410 Pump 30 bbls Hi-vis spacer Pump 70 bbls MOB spacer Pump 566 bbls MOB mud 10 ppg 4/22/2007 00:00 - 01:00 1.00 STKOH N DFAL PROD1 Con't displace SW to MOB mud - 4.5 bpm - PP 1360 -RPM 30 -T09k 01:00 - 02:30 1.50 EVAL N DFAL PROD1 Flow check - 10 mins -Well static - RU testing equipment - Test casing /plug to 1000 psi - 15 mins bleed off from 1000 psi to 870 psi loss 130 psi -Bump up to 1000 psi in 15 mins bleed off from 1000 psi to 830 psi loss of 170 psi - RD testing lines 02:30 - 03:30 1.00 STKOH N DFAL PROD1 Call town -Circulate with 4.5 bpm - PP 1340 -RPM 30 - TO 9K 03:30 - 04:30 1.00 STKOH N DFAL PROD1 Flow check well 35 mins Fluid dropped 13 1/2" inches in drlg nipple -Town call 04:30 - 05:00 0.50 STKOH N DFAL PROD1 Drill cement from 8653' to 8673' - WOB 5 to 10 -Running speed 250 ft per hour -GPM 250 - PP 2560 on -off 2460 - RPM 50 - TO 7k -Circulate 15 mins 05:00 - 05:30 0.50 STKOH N DFAL PROD1 Flow check 30 mins lost .25 bbl 05:30 - 10:00 4.50 STKOH N DFAL PROD1 Drill from 8673' to 8680' 10:00 - 13:00 3.00 STKOH N DFAL PROD1 Build trough in attempt to kick out of old hole from 8680' to 8701' 13:00 - 13:30 0.50 STKOH N DFAL PROD1 Time drill from 8702' to 8703' 13:30 - 14:00 0.50 STKOH N DFAL PROD1 Attempt to go on High line power - No Success 14:00 - 15:00 1.00 STKOH N DFAL PROD1 Trouble shoot electrical problem in SCR house 15:00 - 21:30 6.50 STKOH N DFAL PROD1 Time drill from 8703' to 8714' -Exit well bore 8690' ', 21:30 - 22:30 1.00 STKOH N DFAL PROD1 Dirctional Drill -Rotate from 8714' to 8730' - WOB 10 -RPM 60 - TO 7K -GPM 240 - PP on 2390 -off 2260 -POW 180 -SOW 125 - ROTW 147 22:30 - 23:00 0.50 STKOH N DFAL PROD1 Pump out to 8620' -Circulate 15 mins 23:00 - 00:00 1.00 EVAL N DFAL PROD1 RU testing equipment -FIT - MD 8690 - TVD 6996 -Surface Pressure 730 -Mud Weight 10 ppg = EMW 12.01 ppg - RD testing equipment -Blow down choke manifold 4/23/2007 00:00 - 04:30 4.50 DRILL N DFAL PROD1 Directional Drill from 8730' to 8803.7' - WOB 20 -RPM 80 - TQ on7-off6-GPM250-PPon2500-off 2400-PUW 190- SOW 125 - ROTW 145 'i 04:30 - 05:00 0.50 DRILL N DFAL PROD1 Circulate 6 3/4" hole volume - Pump to shoe -Pump 1 liner Printed: 6/5/2007 10:70:35 AM BP AMERICA Page 17 of 24 ~ Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: i Date From - To !Hours ~ Task Code NPT Phase 4/23/2007 -_ _ - 04:30 - 05:00 0.50 DRILL N DFAL PROD1 05:00 - 07:30 2.50 DRILL N DFAL PROD1 07:30 - 09:00 1.501 DRILL N DFAL PROD1 09:00 - 14:00 5.00 DRILL N DFAL PROD1 14:00 - 14:30 0.50 DRILL N DFAL PROD1 14:30 - 15:30 1.00 DRILL N DFAL PROD1 15:30 - 16:30 1.00 DRILL N DFAL PROD1 16:30 - 17:30 1.00 DRILL N DFAL PROD1 17:30 - 19:30 2.00 DRILL N DFAL PROD1 19:30 - 20:30 1.00 DRILL N DFAL PROD1 20:30 - 23:30 3.00 DRILL N DFAL PROD1 23:30- 00:00 0.50 DRILL N DFAL PROD1 4/24/2007 00:00 - 01:30 1.50 DRILL N DFAL PRODi 01:30 - 03:00 1.50 DRILL N DFAL PRODt 03:00 - 04:00 I 1.001 DRILL I P I I PROD1 04:00 - 05:30 I 1.501 DRILL I P I I PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 10:00 4.00 DRILL P PROD1 10:00 - 13:00 3.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 16:30 2.50 DRILL P PROD1 16:30 - 18:30 2.00 DRILL P PROD1 22:00 - 23:00 1.00 DRILL P PROD1 23:00 - 00:00 I 1.001 DRILL I P i I PROD1 4/25/2007 100:00 - 00:30 0.501 DRILL P PROD1 00:30 - 01:30 I 1.001 DRILL I P I I PROD1 01:30 - 05:00 3.50 DRILL P PROD1 05:00 - 08:30 3.50 DRILL P PROD1 08:30 - 10:30 2.00 DRILL P PROD1 10:30 - 14:30 I 4.001 DRILL I P I I PROD1 Description of Operations volume - Pump to liner top Pump out to liner top - Madd Pass from 8709 to 8200 ~ 320 fph Drop dart to open P.O.S. - CBU 2 X -GPM 450 - PP 2750 - RPM 80 - TO 6k -Flow check -Well static POH from 7770' to 273' Change out P.O.S. sub -Stand back HWDP -Jars - DC's Down load MWD Flush and LD MW D tools -Break bit - LD Motor Clear floor of vendor tools -Clean MOB mud off rig floor PJSM with Baker Core Rep - MU bit -Core barrel -Add spacer - MU XO and P.O.S. sub - PU 12 DC's - 9 joints 4" HWDP - MU jars 5 joints HWDP RIH from 870' to 7705' -Filling pipe every 25 stands - Cut drlg line -Top drive service Con't cut drlg line -Rig service ~ 8670 8670' -Break circulation -Wash down to 8803 to confirm bottom - TD 8804' -Record PU 180 - SO 130 -ROT 150 -Drop ball pump on seat -Record SPR's - # 1 20 730 - 30 1180 - GPM 100 - PP 500 -Ball on seat PP increased to 750 psi Cut Core # 1 from 8804' to 8834' - WOB 5 -RPM 50 - TO 9 to 10k-GPM177-PP1550-PUW 180-SOW-130-ROTW 150 Pick up break core -Pump out to 7884 -Drop ball -Pump on seat open P.O.S. sub - BPM 3 - PP 900 -Shear out @ 3000 psi Flow check (static) POH f/ 7884' to 3000' POH f/ 3000' to 37' @ controlled rate schedule PJSM -Break off bit - LD Core # 1 /core barrel -Rebuild P.O.S. -Install new core barrel - MU bit -Clean up floor - Core recovered = 30') RIH w/ core barrel assy. #2 from 37' to 8654' Circulate and condition mud ~ 8654' -GPM 200 - PP 1020 RIH wash and ream f/ 8700' to 8834' (took 5 to 10k wt through kickoff point) GPM 150 - PP 780 - TO 6k -RPM 20 Drop 1" ball -Pump down ~ GPM 100 - PP 540 -Observed 220 psi increase when ball seated -Cut core #2 f/ 8834' to 8850'-W065k-RPM 50-T08k-GPM 180-PP1670- PUWT 185k - SOWT 135k - ROTW 150k Cont. coring f/ 8850 - 8864' - PUWT 185k - SOWT 130k - ROWT 150k - WOB 5k -RPM 50 -GPM 180 - PP 1670 on / 1650 psi off - TO on bttm 8k /off bttm 6k Pick up break core - 30k over pull @ 8819' -Back ream f/ 8819' to 8764' -Cont. pump out of hole f/ 8764' to 7896' -GPM 100 - PP 700 PJSM -Check well f/ flow (static) - POH f/ 7896' to 3000' POH f/ 3000' to 37' ~ controlled rate schedule PJSM -Break off bit - LD Core # 2 /core barrel -Install new core barrel - MU bit -BHA -Clean up rig floor - (#2 Core recovered = 30') RIH w/ # 3 core barrel assy. f/ 37' to 8654' (fill pipe every 25 stds) Printed: 6/5/2007 10:70:35 AM ~ ~ BP AMERICA Page 18 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date I From - To Hours ' Task Code ~ NPT Phase ~ Description of Operations 4/25/2007 14:30 - 15:30 1.00 DRILL P PROD1 Wash and rotate f! 8654' to 8864' -PUWT 180k - SOWT 130k - RTWT 150k -RPM 20 - TO 5k -GPM 200 - PP 1000 psi 15:30 - 16:00 0.50 DRILL P PROD1 Pump out short trip to 7 5/8" shoe -RIH wash back to bttm - GPM 200 - PP 1000 psi (No tight hole encountered) 16:00 - 17:30 1.50 DRILL P PROD1 Drop 1" ball -Pump down ~ GPM 100 - PP 520 -Observed 210 psi increase when ball seated -Cut core #3 f/ 8864' to 8894'-W065k-RPM50-TOon8k/off 6k-GPM 180-PP 1820 psi on bttm / 1810 psi off -PUWT 180k - SOWT 130k - ROTW 150k 17:30 - 19:00 1.50 DRILL P PROD1 Pick up break core -Pump out of hole f/ 8894' to 8884' 30k overpull -Attempt to back ream /excessive Torque -Pump out of hole t/ 8884 - 7896' -GPM 150 - PP 1150 psi (No additional hole problems encountered) 19:00 - 22:00 3.00 DRILL P PROD1 Flow check well (static) -PJSM - POH f/ 7896' to 3000' 22:00 - 00:00 2.00 DRILL P PROD1 Cont. POH f/ 3000' to 1160' slowly C~ controlled rate schedule 4/26/2007 00:00 - 02:30 2.50 DRILL P PROD1 Cont. POH f/ 1160' to 37' slowly @ controlled rate schedule 02:30 - 03:00 0.50 DRILL P PROD1 PJSM -Break off bit - LD Core # 3 /core barrel -Install new core barrel - MU bit -BHA -Clean up rig floor - (Core #3 recovered = 31') 03:00 - 08:00 5.00 DRILL P PROD1 RIH w/ # 4 core barrel assy. f! 37' to 8654' (fill pipe every 25 stds) 08:00 - 09:30 1.50 DRILL P PROD1 Slip and cut drilling line -Service top drive -Circulate and condition OBM -GPM 125 - PP 690 psi 09:30 - 10:00 0.50 DRILL P PROD1 Wash and rotate f/ 8654' to 8894' -PUWT 180k - SOWT 130k - RTWT 150k -RPM 20 - TO 5k -GPM 200 - PP 1000 psi 10:00 - 10:30 0.50 DRILL P PROD1 Pump out of hole to 7 5/8" shoe -GPM 200 - PP 1000 psi (no tight hole encountered) 10:30 - 11:00 0.50 DRILL P PROD1 Wash back to bottom w/ no rotation f/ 8654' to 8894' -GPM 200 - PP 1000 psi (no tight hole observed) 11:00 - 12:30 1.50 DRILL P PROD1 Drop 1"ball -Pump down C~3 GPM 100 - PP 540 -Observed 260 psi increase when ball seated -Cut core #4 f/ 8894' to 8924'-W065k-RPM50-TOon9k/off 7k-GPM180-PP 1640 psi on bttm / 1620 psi off -PUWT 180k - SOWT 130k - ROTW 150k 12:30 - 13:00 0.50 DRILL P PROD1 Pickup break core -Pull 30' attempting to pump out without rotation (40k overpull observed) -Slacked off -Back ream f/ 8924' to 8858' -GPM 180 - PP 1600 psi -RPM 30 - TO 7-8k (minimal overpull observed / 5k) 13:00 - 14:30 1.50 DRILL P PROD1 Pump out hole without rotary f/ 8858' to 7765' -GPM 150 - PP 1050 psi 14:30 - 17:00 2.50 DRILL P PROD1 PJSM -Flow check well f/ 15 min. (static) - POH f/ 7765' to 3000' 17:00 - 20:30 3.50 DRILL P PROD1 Cont. POH f/ 3000' to 37' slowly @ controlled rate schedule 20:30 - 22:30 2.00 DRILL P PROD1 PJSM -Break off bit - LD Core # 4 /core barrel -Install new core barrel - MU bit -BHA -Clean up rig floor - (Core #4 recovered = 28.5' / 95%) 22:30 - 00:00 1.50 DRILL P PROD1 RIN w/ # 5 core barrel assy. f/ 37' to 1825' 4/27/2007 00:00 - 03:30 3.50 DRILL P PROD1 Cont. RIH f/ 1825' to 8654' (fill pipe every 25 stds) 03:30 - 04:00 0.50 DRILL P PROD1 Wash and rotate f/ 8654' to bttm ~ 8924' -PUWT 185k - SOWT 135k - RTWT 150k -RPM 20 - TO 6k -GPM 200 - PP 1130 psi 04:00 - 04:30 0.50 DRILL P PROD1 Pump out of hole to 7 5/8" shoe -GPM 200 - PP 1100 psi (no tight hole encountered) -Wash back to bottom w/ no rotation f/ Printed: 6/5/2007 10:10:35 AM • • BP AMERICA Page 19 of 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Mours ~ Task Code ~ NPT Phase i Description of Operations 4/27/2007 04:00 - 04:30 0.50 DRILL P PROD1 8654' to 8924' -GPM 200 - PP 1150 psi (No hole problems) 04:30 - 05:30 1.00 DRILL P PROD1 Drop 1" ball -Pump down ~ GPM 100 - PP 540 -Observed 05:30 - 06:30 I 1.001 DRILL I P I I PROD? 06:30 - 07:30 1.00 DRILL P PROD1 07:30 - 08:00 0.50 DRILL P PROD1 08:00 - 11:00 3.00 DRILL P PROD1 11:00 - 15:00 4.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 19:30 3.50 DRILL P PROD1 19:30 - 20:30 1,00 DRILL P PROD1 20:30 - 21:30 1.00 DRILL P PROD1 21:30 - 23:00 I 1.501 DRILL I P I I PROD1 23:00 - 00:00 1.00 DRILL P PROD1 4/28/2007 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 01:30 0.50 DRILL P PROD1 01:30 - 04:30 3.00 DRILL P PROD1 04:30 - 07:00 2.50 DRILL P PROD1 07:00 - 10:00 3.00 DRILL P PROD1 10:00 - 14:00 I 4.001 DRILL I P I I PROD1 14:00 - 16:00 I 2.001 DRILL I P I I PRODi 16:00 - 16:30 J 0.501 DRILL I P I I PROD1 16:30 - 17:30 I 1.001 DRILL I P I I PROD1 17:30 - 18:00 I 0.501 DRILL I P I I PROD1 290 psi increase when ball seated -Cut core #5 f/ 8924' to 8954'-WOB5k-RPM50-TOon 9k/off 7k-GPM 180-PP 1790 psi on bttm / 1760 psi off -PUWT 180k - SOWT 130k - ROTW 150k Pickup break core -Pull 45' attempting to pump out without rotating (20-45k overpull observed) -Slacked off -Begin rotating -Back ream slowly f/ 8954' to 8864' (90') -GPM 175 - PP 1680 psi -RPM 20 - TO 6-10k Pump out of hole f/ 8864' to 7765' -GPM 150 - PP 1350 psi Blow down top drive -PJSM /Flow check well f/ 15 min. (static) POH w/ 4" drill pipe f/ 7765' to 3000' Cont. POH f/ 3000' to 37' slowly ~ controlled rate schedule PJSM -Break off bit - LD Core # 5 /core barrel -Inspect bit - Install new core barrel - MU bit -BHA -Clean up rig floor - (Core #5 recovered = 30.T / 102%) RIH w/ # 6 core barrel assy. f/ 37' to 8654' (fill pipe every 25 stds) Wash and rotate f/ 8654' to bttm ~ 8954' -PUWT 180k - SOWT 130k - RTWT 150k -RPM 20 - TO 5k -GPM 200 - PP 1080 psi Pump out of hole to 7 5/8" shoe -GPM 200 - PP 1060 psi (no tight hole encountered) -Wash back to bottom w/ no rotation f/ 8654' to 8954' -GPM 200 - PP 1100 psi (No hole problems) Drop 1" ball -Pump down ~ GPM 100 - PP 540 -Observed 250 psi increase when ball seated -Cut core #6 f/ 8954' to 8984'-WOB5k-RPM50-TOon 8k/off 6k-GPM 180-PP 1760 psi on bttm / 1710 psi off -PUWT 180k - SOWT 130k - ROTW 150k Pickup break core - POH -back reaming slowly f/ 8984' to 8730' -GPM 180 - PP 1620 to 1510 psi -RPM 20 - TO 6 to 9k (no problems encoutered) Pump out without rotating f/ 8730' to 7704' -GPM 180 - PP 1410 psi PJSM /Flow check well f/ 15 min. (static) -Blow down top drive POH w/ 4" drill pipe f/ 7704' to 3000' Cont. POH f/ 3000' to 37' slowly ~ controlled rate schedule PJSM -Break off bit - LD Core # 6 /core barrel -Inspect bit - Install new core barrel - MU bit -BHA -Clean up rig floor - (Gore #6 recovered = 30.2' / 100%) RIH w/ # 7 core barrel assy. f/ 37' to 8654' (fill pipe every 25 stds) Circulate and condition OBM / PJSM /Cut and slip drilling line / Service top drive Wash and rotate f/ 8654' to bttm ~ 8984' -RPM 20 - TO 5k - GPM 200 - PP 1130 psi Pump out of hole to 7 5/8" shoe -GPM 200 - PP 1130 psi (no tight hole encountered) -Wash back to bottom without rotating f/ 8654' to 8984' -GPM 200 - PP 1150 psi (No hole problems) Drop 1"ball -Pump down @ GPM 100 - PP 540 -Observed 260 psi increase when ball seated Printed: 6/5/2007 10:10:35 AM ~ ~ BP AMERICA Page 20 of 24 Operations Summary Report Legal Well Name: MPF-99 .Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours ask Code ~ NPT Phase ~ Description of Operations '!4/28/2007 18:00 - 19:00 1.00 EVAL P PROD1 Cut core # 7 f/ 8984' to 9014' - WOB 5k -RPM 50 - TO on 8k / ~ off 7k -GPM 180 - PP 1760 psi on bttm / 1750 psi off -PUWT 176k - SOWT 130k - ROTW 150k 19:00 - 21:00 2.00 DRILL P PROD1 Pickup break core - POH -Back ream slowly t/ 8984' to 8825' (2 stds) -GPM 180 - PP 1620 to 1550 psi -RPM 20 - TO 6 to ~, 9k (No problems) 21:00 - 21:30 0.50 DRILL P PROD1 Pump out without rotating f/ 8725' to 7704' -GPM 180 - PP 1500 psi 21:30 - 22:00 0.50 DRILL P PROD1 PJSM /Flow check well f/ 15 min. (static) -Pump dry job -Blow down top drive 22:00 - 00:00 2.00 DRILL P PROD1 POH w/ 4" drill pipe f/ 7704' to 3158' !, 4/29/2007 00:00 - 04:00 4.00 DRILL P PROD1 Cont. POH f/ 3158' to 3T slowly @ controlled rate schedule ! 04:00 - 05:30 1.50 DRILL P PROD1 PJSM -Break off bit - LD Core # 7 /core barrel - LD Baker coring assy. (Core #7 recovered = 30.5' -total footage cored = 210' /recovered = 210.9' or 100.4%) 05:30 - 07:00 1.50 DRILL P PRODi Clear rig floor of vendor tools /clean rig floor -Mobilize drlg assy to rig floor 07:00 - 11:00 4.00 DRILL P PROD1 PJSM on loading nukes - MU 6 3/4" Drlg assy. - MU Bit - ', MWD tools -Nukes -Upload MWD -Upload Nukes - DC's - ' Jars -HWDP -Surface test MWD -GPM 230 - PP 1380 psi 11:00 - 12:00 .1.00 DRILL P PROD1 RIH from 322' to 2610' - Function test MWD and Geo span - GPM 230 - PP 1380 psi 12:00 - 14:30 2.50 DRILL P PRODi RIH w/ 4" drill pipe f/ 2610' to 8654' (till pipe every 25 stds) 14:30 - 16:00 1.50 DRILL P PROD1 Wash and ream f/ 8654' to bttm @ 9014' -PUWT 170k - SOWT 130k - ROWT - 150k -GPM 250 - PP 3200 psi - TO 6k -RPM 100 ', 16:00 - 00:00 8.00 DRILL P PROD1 Directional Drill f/ 9014' to 9215' -PUWT 175k - SOWT 125k - !, ROWT - 147k -GPM 250 - PP 3200 psi - WOB 23k -RPM 110 - TO on bttm 7k /off 5k 4/30/2007 00:00 - 02:30 2.50 DRILL P PROD1 Directional Drill f/ 9200' to 9270' MD / 7215' TVD (TD}- PUWT 175k - SOWT 125k - ROWT 147k -GPM 250 - PP 3200 psi - WOB 23k -RPM 110 - TO on bttm 7k /off 5k 02:30 - 06:00 3.50 DRILL P PROD1 Circulate bttms up x 2 -GPM 254 - PP 3100 psi 06:00 - 11:00 5.00 DRILL P PROD1 POH w/ 4" drill pipe f/ 9270' to 9080' -MWD Mad pass f/ 9080' to 8670'-GPM250-PP3060 psi-RPM80-TO6k 11:00 - 12:00 1.00 DRILL P PROD1 RIH w/ 4" drill pipe f/ 8670' to 9010' 12:00 - 18:00 6.00 EVAL P PRODi Move tool -Take Sperry Geo Tap survey pressures ~ 9010' - 9003' - 8998' - 8991' - 8981' - 9877' - 8942' - 8939' - 8935' - 8929' - 9104' - 9071' - 9034' - 9032' - 8949' - 8813' - 8807' 18:00 - 18:30 0.50 DRILL P PROD1 RIH w/ 4" drill pipe f/ 8865' - 9270' (wash last stand to bttm) 18:30 - 19:00 0.50 DRILL P PROD1 Circulate and condition OBM -PUWT - 175k - SOWT 125k - ROWT 145k -GPM 250 - PP 3150 psi - R&R - 100 RPM - TO 5k - (Base line TO 5.5k ~ 15 RPM) 19:00 - 21:00 2.00 DRILL P PROD1 Pump out of hole w/ 4" drill pipe f/ 9270' to 7775' -GPM 250 - PP 2890 psi 21:00 - 23:00 2.00 DRILL P PROD1 Drop POS dart -Open circulating sub -Circulate hole clean - GPM 435 - PP 3000 psi - R&R - 100 RPM - TO 5k - (Base line TO 5k ~ 15 RPM) 23:00 - 00:00 1.00 DRILL P PROD1 PJSM /Flow check well f/ 15 min. (static) -Pump dry job -Blow down top drive 5/1/2007 00:00 - 03:00 3.00 DRILL P PROD1 POH w/ 4" drill pipe f/ 8028' to 322' 03:00 - 04:00 1.00 DRILL P PROD1 Stand back in derrick -HWDP -Jars - DCs -PJSM on handling nukes Printed: 6/5/2007 10:10:35 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 5/1/2007 04:00 - 07:00 3.00 DRILL P 07:00 - 08:00 I 1.001 CASE I P 08:00 - 09:00 1.00 CASE P 09:00 - 15:00 6.00 CASE P 15:00 - 21:30 I 6.501 CASE I P 21:30 - 22:30 I 1.001 CASE I P 22:30 - 23:30 1.00 CASE P 23:30 - 00:00 0.50 CASE P 5/2/2007 100:00 - 01:30 I 1.501 CASE I P 01:30 - 02:30 I 1.00 I CASE I P 03:00 - 04:00 1.00 CEMT P 04:00 - 05:30 1.50 CASE P 05:30 - 07:30 I 2.001 CASE I P 07:30 - 08:30 1.00 I CASE P 08:30 - 13:00 4.50 I CASE I P Start: 12/6/2006 Rig Release: 1/17/2007 Rig Number: Page 21 of 24 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Phase ~ Description of Operations PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PRODi LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 13:00 - 13:30 0.50 CASE P LNR2 13:30 - 14:30 1.00 CASE P LNR2 14:30 - 16:30 2.00 CASE P LNR2 16:30 - 18:00 1.50 CASE P LNR2 18:00 - 20:00 I 2.00 I CASE I P I I LNR2 Download MWD - Dowdload Nukes - LD MWDtools -Nukes - Geo tap equip -Clear rig floor Mobilize cement head to rig floor - MU XOs and pup jt. - LD same to pipe shed PJSM - RU casing equipment -Change out elevators -Slips Run 4 1/2" 12.6# L-80 IBT-M Liner - 2 pup jts -Boxes installed w/ Tesco torque rings - 2 centralizers per jt - 1 centralizer per each pup jt. - MU casing hanger - XO -Circulate liner volume - GPM210-PP320 psi RIH w/ 4" drill pipe f/ 1627' to 7 5/8" shoe ~ 8653' (fill pipe every 20 stds) Circulate And condition OBM -GPM 168 - PP 740 psi -PUWT 165k - SOWT 128k - ROWT 142k -RPM 15 - TO 5k RIH w 4 1/2" liner f/ 8653' to 9242' - MU cement head and line Wash last jt. to bttm f/ 9242' to 9270' -GPM 165 - PP 1000 psi - PUWT 167k - SOWT 130k - ROWT 142K -RPM 15 - TO 5k Circulate bttms up -GPM 240 PP 1200 psi -PUWT 165k - SOWT 128k - ROWT 142k PJSM w SLB and all rig crew -Cont. Circulate and condition while Schumberger batch up cement Give to Schlumberger Pump 5 bbls 12.1 ppg Mud push II Test lines to 4000 psi Pumped 33 bbls Mud push II Pumped 63 bbls class "G" ~ 15.8 ppg cement /yield 1.17 / 327 sxs Displace with rig pump 35 bbls Perf pill @ 10.2 ppg -followed by 62.6 bbls OBM ~ 10.2 ppg -BPM 5 - PP 1000 psi -Saw dart latch up ~ 785 stks / 2560 psi -Plug bumped C~ 968 stks - CIP @ 04:12 hrs. Rotated and reciprocated throughout cement job -RPM 15 - TO 5k Pressure up 2800 psi /Set hanger -Slack off liner load +30k - Pressure up to 4000 psi to release running tool - PU to 160k - Slackoff to 120k rotate w/ 15 rpm -Repeat process 4x -Bled off pressure -Pickup to verify released from liner -Set liner top packer -Pressured up to 1500 psi -Pull out of liner Circulate out Mud push /Excess cement to surface -BPM 8 - PP 1360 psi -Approx. 10 bbls cement observed ~ shakers - Overboard 140 bbls mud push /cement contaminated MOBM Observe well (Static) -Pump dry job - LD single and cement head -Blow down TD and lines POH f/ 7624' -Service breaks and LD liner running tool (Running tool looked good) Clean /clear rig floor - Moblize drlg assy to rig floor MU 8 1/2" Cleanout assy -Bit - 4 3/4" DC's - 4" HWDP -Jars RIH w/ 4" drill pipe f/ 933' to 7520' (fill pipe every 25 stds) Wash and ream cement stringers f/ 7520' to 7638' - Washed down freely / no cmt stringers f/ 7638' to 7655' (TOL) PUWT 170k - SOWT 128k - ROWT 146k -GPM 250 - PP 1420 psi - RPM 10-TO 7k Circulate hole clean - R&R -RPM 100 - TO 7k -GPM 400 - PP 3040 psi Printed: 6/5/2007 10:10:35 AM BP AMERICA Page 22 ~f 24 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: I ~ Date I From - To .Hours Task i Code NPT Phase Description of Operations 5/2/2007 20:00 - 20:30 20:30 - 22:00 0.501 CASE I P 1.501 CASE I P 22:00 - 23:30 1.50 CASE P 23:30 - 00:00 0.50 CASE P 5/3/2007 00:00 - 02:30 2.50 CASE P 02:30 - 04:00 1.50 CASE P 04:00 - 05:00 1.00 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 08:00 I 0.50 I CASE l P 08:00 - 09:00 1.00 CASE P 09:00 - 12:00 3.00 CASE P 12:00 - 12:30 I 0.501 CASE I P 12:30 - 13:00 0.50 BOPSUFj P 13:00 - 15:30 2.50 EVAL ( P 15:30 - 17:00 I 1.501 EVAL I P 17:00 - 17:30 0.50 EVAL P 17:30 - 19:30 2.00 CASE P 19:30 - 22:30 3.00 BOPSU P 22:30 - 23:00 0.50 CASE P 23:00 - 00:00 1.00 CASE P 5/4/2007 00:00 - 01:30 1.50 CASE P 01:30 - 03:30 2.00 CASE P 03:30 - 04:00 ~ 0.50 ~ CASE ~ P LNR2 PJSM w/ Veco truck drivers and all rig crew / Discussed fluid transfers, Safety issues, Anti-slip foot wear, Positioning of personnel, Spill prevention procedures f/job LNR2 Displaced OBM w/ 8.6 ppg KCL water -GPM 450 - PP 2730 psi - R&R ~ 100 RPM Pumped 30 bbls perf pill 10.2 ppg Pumped 150 bbls hot KCL water treated w/ Safe-SurfO Pumped 465 bbls hot 2% KCL water @ 8.6 ppg Pumped until clean 8.6 ppg brine water returns were observed shakers LNR2 Flushout surface equipment in pits !Lines /Trough /Trip tank LNR2 POH w/ 4" drill pipe laying down 1 x 1 to pipe shed LNR2 POH laying down 4" drill pipe 1x1 to pipe shed f/ 7190 to 6260' LNR2 Cont. POH w/ 4" drill pipe -Stand back in derrick f/ 6260' to 933' LNR2 LD BHA - HWDP -Flex DCs - NM DCs -Bit sub -Bit LNR2 Clean /Clear rig floor -Mobilize SLB wireline equipment to rig floor LNR2 PJSM - RU test equipment LNR2 Pressure test 4 1/2" liner lap @ 7655' and ZXP packer to 4500 psi f/ 30 min. -Record on chart (Good test) - RD test equipment LNR2 PJSM w/ SLB and all rig crew -Discussed job procedures / Mobilizing tools /Lifting procedures /Communication issues / Anti-slip foot wear -PPE LNR2 RU SLB wireline equipment /Hang WL sheave LNR2 RIH w/ SLB wireline 8 1/2" gauge ring /Junk basket -Tag TOL 7655' LNR2 POH w/ wireline GR/JB run #1 (several chunks of cmt in basket) LNR2 Install wear bushing LNR2 RIH w/ SLB wireline 3.8" Gauge ring /Junk basket to 7661' (unable to get past 7661' WLD) - POH w/ wireline tools LNR2 RIH w/ Gamma, CCL f/ wireline dummy run (3.27" OD) to 7661' (unable to get past 7661' WLD) - POH w/ wireline tools LNR2 RD SLB wireline equipment -Clear rig floor LNR2 Pull wear bushing -Install test plug - RU test equipment LNR2 Test BOP's -Annular 250 low 2500 high 5 mins each test -Top VBR's - 2 7/8" x 5" -Lower VBR's - 3 1/2" x 6" -Upper IBOP / Lower IBOP -Floor safety valve -Dart valve -Choke manifold - 250 low 4500 high 5 mins each test - HCR Choke /Kill - Manual Choke /Kill - 250 low 4500 high - 5 mins each test - Perform Accumulator test -Test Blinds - 250 low - 4500 high 5 mins each test -All test witnessed by WSL -Bob Noble with AOGCC waived witness of BOP test LNR2 RD test equipment -Pull test plug LNR2 Slip and cut drilling line -Service top drive LNR2 Cont. -Slip and cut drill line -Service top drive LNR2 Mobilize tubing equipment to rig floor -Double stacked tongs - C/O elevators -Slips -Load /Strap /Drift 55 joints / 2 7/8" FOX work string in shed LNR2 MU 3 3/4" Baker cleanout assy. -Mill - 2 7/8" Baker X-treme motor Printed: 6/5/2007 10:10:35 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 i , Date I From - To Hours Task 'Code NPT -__ - _ - __ 5/4/2007 04:00 - 06:00 2.00 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 09:00 2.50 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 12:00 I 2.50 I CASE I P 12:00 - 15:00 3.001 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 17:30 2.00 CASE P Start: 12/6/2006 Rig Release: 1 /17/2007 Rig Number: Page 23 of 24 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Phase Description of Operations LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 17:30 - 19:30 2.00 CASE P LNR2 19:30 - 20:00 0.50 CASE P LNR2 20:00 - 21:00 1.00 CASE P LNR2 21:00 - 21:30 0.50 CASE P LNR2 21:30 - 22:00 0.50 CASE P LNR2 22:00 - 00:00 2.00 EVAL P LNR2 5/5/2007 100:00 - 04:30 I 4.501 EVAL I P I I LNR2 04:30 - 05:30 I 1.001 EVAL I P I I LNR2 05:30 - 06:00 0.50 EVAL P LNR2 06:00 - 08:00 2.00 EVAL P LNR2 08:00 - 14:00 I 6.00 I EVAL I P I I LNR2 14:00 - 17:00 I 3.001 EVAL I I I LNR2 17:00-21:001 4.00 P I (LNR2 21:00 - 00:00 3.00 P LNR2 5/6/2007 100:00 - 02:00 I 2.001 I P I I LNR2 02:00 - 03:00 1.00 P 03:00 - 03:30 0.50 EVAL P 03:30 - 04:30 1.00 EVAL P 04:30 - 06:30 2.00 BOPSU P LNR2 LNR2 LNR2 LNR2 RIH w/ 2 7/8" FOX work string 1 x 1 f/ pipe shed PU XO's and 1 stand 4" DP -Break circulation -Pump pipe volume RIH w/ 4" DP to 7600' Screw in T.D. -Break circulation w/ 100 gpm 500 psi -Obtain parameters - PUW 160k -SOW 120k -Wash down to 7695' (12' inside 4 1/2" liner) - No issues - PU 25' -Work into liner w/ no pump - OK Run in 4 1/2" liner w/ 3.75" mill, motor and 2 7/8" FOX pipe - Tag landing collar at 9141' Drop ball -Pump down & shear circ. sub -CBU w/ 5 bpm 1100 psi -Spot 30 bbl Perf pill in 4 1/2" liner POH -Spot circ. sub at top of 4 1/2" liner (7684') CBU w/ 265 gpm 1030 psi -Reciprocate circ. sub across 4 1/2" x 9 5/8" liner top -Pump out from 7684' to 7412' w/ 220 gpm 840 psi -Observe well -pump dry job -Blow down T.D. POH w/ 4" drill pipe f/ 7412' to 1620' Change out handling equip. -Elevators -slips - RU stack tongs POH w/ 2 7/8" FOX work string -Rack back in derrick LD BHA - 2 7/8" Baker motor - 3 3/4" Mill -Clear rig floor PJSM - RU SLB wireline equipment RIH w/ SLB wireline tools - SCMT / PBMS - Centralizer w/ rollers / Wt. bars w/ rollers -Log down f/ 7635' to 9156' (W LD) Cont. logging w/ SLB -Log up f/ 9156' to top of 4 1/2" liner 7655' -Continue logging up to 7635' Confirm logging results w/ Geologist /Engineer - POH w/ wireline LD SLB logging tools -Clear rig floor PJSM -Change top rams to 4 1/2' x 7" variables -Test door seals to 2500 psi PJSM - RU SLB 5 1/2" shooting nipple, lubricator, W.L. BOP's, quick test sub & packoff -Test W.L. BOP to 1500 psi. PJSM -Mobilize SLB guns and equip. to rig floor - PU perforating guns RIH w/ SLB wireline run #1 - MH /UPCT /CCL / W PSA / FH / 40' 2 7/8" Omega guns / 6 shots per/ft -Obtain parameters - Correlate guns on depth -Fire guns /Surface indications guns fired -Perforate 4.5" liner f/ 8894' to 8934' (Downhole fluid static) - POH w/ wireline -Inspect guns C~ surface all shots fired PJSM -Change out guns -Pressure up on lubricator Quick test Sub to 3000 psi f/ 5 mins. (test Good) -RIH w/ SLB pert gun #2 run Cont. RIH w/ SLB pert guns Run #2 - MH /UPCT /CCL / W PSA / FH / 20' Omega guns / 6 shots per/ft -Obtain parameters -Correlate guns on depth -Fire guns /Surface indications guns fired -Perforate 4.5" liner f/ 8844' to 8864' (Downhole fluid static) POH w/ wireline -PJSM -Inspect guns ~ surface all shots fired LD SLB perforating guns RD lubricator / Extention / W L BOPS - LD same to pipe shed PJSM -Pull wear bushing -Install test plug -Change top rams Printed: 6/5/2007 10:10:35 AM BP AMERICA Page 24 of 24', Operations Summary Report '', Legal Well Name: MPF-99 Common W ell Name: MPF-99 Spud Date: 12/13/2006 Event Nam e: DRILL+C OMPLE TE Start : 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLIN G INC . Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: ~ I Date From - To~ Hours Task Code NPT Phase I Description of Operations 5/6/2007 04:30 - 06:30 2.00 BOPSU P LNR2 - - to 2 7/8" x 5" VBRs -Test rams to 250 psi low - 4500 high f/ 5 min. each test -Record on chart -Pull test plug -Install wear ring 06:30 - 10:00 3.50 CASE P LNR2 PJSM - RU stack tubing tongs -RIH w/ 2 7/8" workstring -Flow check well f/ 15 min. - POH LD same (correct disp.) 10:00 - 10:30 0.50 CASE P LNR2 RD tongs -Change elevators -Mobilize DP protectors to rig floor /Monitor well 10:30 - 13:30 3.00 CASE P LNR2 MU muleshoe -RIH to 7650' 13:30 - 14:30 1.00 CASE P LNR2 Pump pipe volume x2 -Flow check well f/ 15 min. -Dry job - Blow down T.D. 14:30 - 20:00 5.50 CASE P LNR2 PJSM - POH LD 4" DP 1 x 1 to pipe shed (correct fluid disp. / No fluid losses or gains since perforating) 20:00 - 21:00 1.00 CASE P LNR2 Pull wear bushing -Clear rig floor -Mobilize Completion tools to rig floor 7" Shroud /Clamps /Slips /Stack tongs -Change elevators 21:00 - 00:00 3.00 CASE P LNR2 PJSM w/ Centrilift and rig crew -Prep. ESP completion equipment -Prep. motor 5/7/2007 00:00 - 02:30 2.50 BUNCO RUNCMP PJSM w/ Centrilift and all rig crew -Hang sheave off super tugger - MU ESP motor and pumps 02:30 - 03:00 0.50 BUNCO RUNCMP MU control line f/ spooling unit to pump -Test ESP cable x 1 03:00 - 03:30 0.50 BUNCO RUNCMP PJSM -RIH w/ ESP completion 7" Shroud -Motor - Pump assy - Pup jt. - XN nipple - Pup jt. -Test ESP cable x 2 03:30 - 15:00 11.50 BUNCO P RUNCMP Run 2 7/8" 6.5# L-80 EUE 8rd completion to 7646.58"- Total 238 jts -Make up torque 2,300 Wlbs - PUWT 110k - SOWT ~ 88k (126 cable clamps / tested ESP cable conductivity every 2000') -Monitor fluid displacement throughout tubing run / No downhole losses /gains 15:00 - 17:30 2.50 BUNCO RUNCMP MU pup jts. -Make up FMC 11" x 2 7/8" Gen 4 ESP Tubing hanger -Install ESP Penetrator through tubing hanger -Splice ESP cable w/ BIW lower connector -Connect to penetrator - Test cable (ok) 17:30 - 19:00 1.50 BUNCO RUNCMP Land hanger -Run in lock down screws -Back out landing jt. - Dry rod in TWC -Test TWC to 2500 psi f/ above / 500 psi f/ below 19:00 - 20:30 1.50 BOPSU P RUNCMP Nipple down -Set back 13 5/8" Bop stack 20:30 - 22:30 2.00 BOPSU P RUNCMP Nipple up Fmc 11" x 2 9/16" tubing head adapter -Test FMC adapter to 5000 psi f/ 10 min. (ok) -Nipple up CIW 2 9/16" 5000# Tree -Pressure test to 5000 psi f/ 10 min. (ok) 22:30 - 23:00 0.50 WHSUR P RUNCMP Centrilift final test cable conductivity (ok) 23:00 - 00:00 1.00 WHSUR P RUNCMP RU lubricator -Pull TWC -Install BPV -Shut in well -Prep cellar -Secure well f/ handover -Release rig Printed: 6/5/2007 10:10:35 AM BP AMERICA Page i of i Leak-Off Test Summary Legal Name: MPF-99 Common Name: MPF-99 Test Date Test Type Test Depth (TMD) !. Test Depth (TVD) AMW i Surface Pressure Leak Off Pressure (BHP) EMW 12/20/2006 FIT 4,892.0 (ft) 4,606.0 (ft) 8.90 (ppg) 745 (psi) 2,875 (psi) 12.01 (ppg) 12/28/2006 FIT 7,954.0 (ft) 6,719.0 (ft) 10.00 (ppg) 1,400 (psi) 4,890 (psi) 14.01 (ppg) 1/4/2007 FIT 8,670.0 (ft) 6,989.0 (ft) 10.10 (ppg) 872 (psi) 4,539 (psi) 12.50 (ppg) r 1 ~ J Printed: 5/14/2007 10:49:22 AM Digital Wellfile Page 1 of 1 Well: MPF-99 Well Events for SurfaceWell -MPF-99 Location: BP -> ALASKA -> ALASKA CONSOLIDATED TEAM -> MPU -> MPF -> MPF-99 Date Range: 08/May/2007 to 05/Jun/2007 Data Source(s): AWGRS Events Source Well Date Description AWGRS MPF-99 06/04/2007 SBHPS *** WELL S/I ON ARRIVAL *** RUN DUAL SPARTEK GAUGES.MADE 15 MINUTE STOP 7055' SLM. *** CONTINUEON 06-05-07 *** AWGRS MPF-99 06/03/2007 Well Support Techs rigged up hardline from the wellhead to the header and pressrue tested it to 1150 psi. The pressure test was GOOD. AWGRS MPF-99 05/22/2007 ***WELL S/I ON ARRIV.*** PULLED DPSOV FROM MADREL @124' SLM 153' MD. SET 1" DUMMY ON A BK LATCH IN SAME MANDREL, RDMO ***WELL LEFT S/I*** AWGRS MPF-99 05/20/2007 ***WELL S/I ON ARRV*** PULLED BPV, WELL RETURN LATER TO C/O TOP STATION ***WELL LEFT S/I*** AW .G. R$ MPF-99 05/08/2007 (Freeze Protect Tbg and IA Post RWO) T/I/0=0/0/0. Freeze protect IA w/ 125 bbls crude. IA pressured up to 2750 psi. Pump crude down IA @ .6 bpm. Pump 15bis 60/40 meth down TBG @ .25 bpm to freeze protect. FWHP=1800/1950/0 Refresh List http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 6/5/2007 U Halliburton Company Survey Report Company: BP Amoco Field: Milne Point Date: 6i5r2Q07 Time: 70:30:3 Pa;;c: 1 Co-ordinate(NE) Reference: Well: MPF 99, True North Site: M Pt F Pad Vertical (TVD) Reference: MPF 99:45.8 Wcll: MPF-99 SectiunlVS)Referen cc Well (O.OON,O.OOE,1 87.80Azi) Wellpath: MPF-99 -- Surrey Calculation A _ _ lethixl: Minhnum C~rvatUre Db: Oracle Field: Milne Point - -- - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: MPF-99 S1otName: Well Position: +N/-S 5650.12 ft Northing: 6035652.17 ft Latitude: 70 30 29.935 N +E/-W10322.17 ft Easting : 542111.32 ft Longitude: 149 39 19.607 W Position Uncertainty: 0.00 ft Wellpath: MPF-99 Drilled From: MPF-99P61 500292333200 Tie-on Depth: 8602.50 ft Current Datum: MPF -99: Height 45.80 ft Above System Datum: Mean Sea Level Magnetic Data: 4/19/2007 Declination: 23.53 deg Field Strength: 57627 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.30 0.00 0.00 187.80 Survey Program for DeCnitive Wellpath Date: 6/5/2007 Validated: N o Version: 12 Actual From To Survey Toolcode Tool Name ft ft 100.00 901.00 MPF-99 Gyro (100.00-901.00) (0 CB-GYRO-SS Camera based gyro single shots 980.55 8602.50 MPF-99 IIFR+MS+Sag (980.55-906 MWD+IFR+MS MWD +IFR + Multi Station 8690.00 9224.70 MPF-991 IIFR+MS+Sag (8690.00-9 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD Sys TVll N/S E/W MapN D2ap~; Tool ft deg deg ft ft ft ft ft ft a ___ _ -- 34.30 0.00 - 0.00 34.30 - -11.50 _ _ 0.00 0.00 _ _ 6035652.17 542111.32 __ TIE LINE 100.00 0.18 164.26 100.00 54.20 -0.10 0.03 6035652.07 542111.35 CB-GYRO-SS 170.00 0.48 152.48 170.00 124.20 -0.47 0.19 6035651.71 542111.52 CB-GYRO-SS 259.00 1.05 143.21 258.99 213.19 -1.45 0.85 6035650.73 542112.18 CB-GYRO-SS 351.00 2.11 121.92 350.95 305.15 -3.02 2.80 6035649.17 542114.13 CB-GYRO-SS 441.00 4.70 111.45 440.79 394.99 -5.24 7.64 6035646.97 542118.98 CB-GYRO-SS 531.00 6.91 112.36 530.32 484.52 -8.65 16.08 6035643.61 542127.44 CB-GYRO-SS 621.00 9.12 116.53 619.44 573.64 -13.90 27.47 6035638.43 542138.86 CB-GYRO-SS 713.00 14.24 124.63 709.51 663.71 -23.59 43.31 6035628.83 542154.76 CB-GYRO-SS 806.00 15.62 125.88 799.37 753.57 -37.43 62.87 6035615.10 542174.39 CB-GYRO-SS 901.00 15.69 126.14 890.84 845.04 -52.50 83.60 6035600.15 542195.21 CB-GYRO-SS 980.55 16.63 129.85 967.25 921.45 -66.14 101.03 6035586.61 542212.71 MWD+IFR+MS 1026.21 15.89 129.52 1011.08 965.28 -74.31 110.87 6035578.50 542222.60 MWD+IFR+MS 1120.87 15.54 133.72 1102.21 1056.41 -91.32 130.03 6035561.60 542241.85 MWD+IFR+MS 1211.10 14.88 140.94 1189.29 1143.49 -108.67 146.07 6035544.34 542257.99 MWD+IFR+MS 1304.72 14.88 143.69 1279.77 1233.97 -127.69 160.76 6035525.41 542272.79 MWD+IFR+MS 1398.99 15.75 155.23 1370.71 1324.91 -149.06 173.29 6035504.10 542285.44 MWD+IFR+MS 1491.88 17.05 171.27 1459.87 1414.07 -173.99 180.65 6035479.23 542292.93 MWD+IFR+MS 1589.53 17.67 182.40 1553.09 1507.29 -202.95 182.20 6035450.27 542294.65 MWD+IFR+MS 1686.18 19.19 187.19 1644.79 1598.99 -233.37 179.60 6035419.84 542292.22 MWD+IFR+MS 1781.18 20.77 194.08 1734.08 1688.28 -265.21 173.54 6035387.98 542286.35 MWD+IFR+MS 1872.69 21.39 198.51 1819.47 1773.67 -296.77 164.30 6035356.36 542277.28 MWD+IFR+MS 1968.52 22.34 198.96 1908.41 1862.61 -330.57 152.83 6035322.51 542266.01 MWD+-FR+MS 2063.38 23.56 198.38 1995.76 1949.96 -365.61 140.99 6035287.40 542254.37 MWD+IFR+MS 2156.38 23.81 197.44 2080.92 2035.12 -401.16 129.51 6035251.79 542243.09 MWD+IFR+MS 2251.66 22.22 197.74 2168.62 2122.82 -436.67 118.25 6035216.22 542232.04 MWD+IFR+MS 2347.60 19.90 195.90 2258.14 2212.34 -469.65 108.25 6035183.18 542222.22 MWD+IFR+MS 2441.43 20.28 195.74 2346.26 2300.46 -500.66 99.47 6035152.13 542213.61 MWD+IFR+MS • Halliburton Company Survey Report Company: BP Amoco Date: 6,'52007 Time: 10:30:37 Page: .. Field: Milne Point Co-ordinate(NE) Reference: Well: MPF 99, True North Site: M Pt F Pad Vertical (TVD) Reference: MPF-99: 45.° ~1'etL• MPF-99 Scction(VS)Reference: Weil (O.OON,O.OOE,187.80Azil wellpath: MPF-99 Survey Calculation Me~h~xi: Mirimurn Cuwature Db: OraCle Survev MD Inel Aiim TbU Svs "I~~1) ~/5 E/VV MapN MapE T~rtl ft deg deg ft ft ft ft ft ft 2536.39 19.18 192.52 2435.65 2389.85 -531.73 91.62 6035121.02 542205.94 MWD+IFR+MS 2631.23 20.22 190.15 2524.94 2479.14 -563.08 85.35 6035089.64 542199.86 MWD+IFR+MS 2725.36 21.13 191.15 2613.01 2567.21 -595.73 79.21 6035056.95 542193.89 MWD+IFR+MS 2819.25 22.74 190.57 2700.10 2654.30 -630.18 72.60 6035022.47 542187.49 MWD+IFR+MS 2913.91 21.69 190.81 2787.73 2741.93 -665.35 65.97 6034987.27 542181.05 MWD+IFR+MS 3008.32 19.34 193.34 2876.15 2830.35 -697.70 59.09 6034954.88 542174.36 MWD+IFR+MS 3102.32 19.74 194.06 2964.73 2918.93 -728.24 51.64 6034924.30 542167.08 MWD+IFR+MS 3195.88 20.94 193.91 3052.46 3006.66 -759.80 43.78 6034892.70 542159.40 MWD+IFR+MS 3289.66 20.43 190.85 3140.20 3094.40 -792.14 36.67 6034860.33 542152.48 MWD+IFR+MS 3383.86 21.29 189.19 3228.22 3182.42 -825.17 30.85 6034827.27 542146.84 MWD+IFR+MS 3477.71 20.86 189.59 3315.79 3269.99 -858.47 25.34 6034793.94 542141.52 MWD+IFR+MS 3572.89 20.13 190.96 3404.95 3359.15 -891.26 19.40 6034761.12 542135.77 MWD+IFR+MS 3669.14 19.49 190.97 3495.50 3449.70 -923.28 13.20 6034729.07 542129.75 MWD+IFR+MS 3764.07 20.96 190.19 3584.58 3538.78 -955.54 7.18 6034696.78 542123.92 MWD+IFR+MS 3859.56 20.85 189.40 3673.78 3627.98 -989.12 1.38 6034663.17 542118.31 MWD+IFR+MS 3952.96 20.28 190.40 3761.23 3715.43 -1021.44 -4.25 6034630.83 542112.86 MWD+IFR+MS 4047.51 20.21 195.34 3849.94 3804.14 -1053.30 -11.53 6034598.92 542105.76 MWD+IFR+MS 4141.44 20.32 202.29 3938.07 3892.27 -1084.05 -22.01 6034568.12 542095.46 MWD+IFR+MS 4233.18 20.97 209.12 4023.93 3978.13 -1113.13 -36.04 6034538.96 542081.59 MWD+IFR+MS 4326.75 22.09 216.11 4110.99 4065.19 -1141.98 -54.56 6034510.01 542063.23 MWD+IFR+MS 4420.36 23.61 222.69 4197.26 4151.46 -1169.98 -77.65 6034481.88 542040.31 MWD+IFR+MS 4516.80 25.26 223.46 4285.06 4239.26 -1199.12 -104.90 6034452.60 542013.23 MWD+IFR+MS 4611.10 28.14 224.89 4369.30 4323.50 -1229.48 -134.44 6034422.07 541983.86 MWD+IFR+MS 4708.80 31.33 228.28 4454.13 4408.33 -1262.72 -169.67 6034388.63 541948.82 MWD+IFR+MS 4800.83 33.83 231.40 4531.68 4485.88 -1294.63 -207.56 6034356.51 541911.12 MWD+IFR+MS 4834.36 34.80 232.41 4559.37 4513.57 -1306.29 -222.44 6034344.77 541896.31 MWD+IFR+MS 4927.04 34.68 233.10 4635.53 4589.73 -1338.25 -264.48 6034312.57 541854.46 MWD+IFR+MS 5020.89 33.95 234.39 4713.05 4667.25 -1369.55 -307.14 6034281.04 541811.98 MWD+IFR+MS 5115.51 33.25 237.90 4791.87 4746.07 -1398.72 -350.60 6034251.62 541768.69 MWD+IFR+MS 5210.45 32.06 239.03 4871.80 4826.00 -1425.52 -394.25 6034224.58 541725.19 MWD+IFR+MS 5304.57 31.71 240.33 4951.72 4905.92 -1450.61 -437.17 6034199.24 541682.43 MWD+IFR+MS 5400.07 32.00 241.96 5032.84 4987.04 -1474.93 -481.31 6034174.68 541638.43 MWD+IFR+MS 5496.35 32.91 241.71 5114.08 5068.28 -1499.32 -526.86 6034150.03 541593.02 MWD+IFR+MS 5590.05 33.53 241.78 5192.46 5146.66 -1523.62 -572.07 6034125.48 541547.95 MWD+IFR+MS 5685.82 35.41 240.30 5271.42 5225.62 -1549.88 -619.49 6034098.95 541500.69 MWD+IFR+MS 5780.46 35.82 239.82 5348.35 5302.55 -1577.39 -667.24 6034071.18 541453.09 MWD+IFR+MS 5876.53 35.96 240.12 5426.18 5380.38 -1605.57 -716.00 6034042.72 541404.50 MWD+IFR+MS 5969.86 36.68 238.94 5501.38 5455.58 -1633.61 -763.64 6034014.42 541357.03 MWD+IFR+MS 6066.25 36.14 239.00 5578.96 5533.16 -1663.10 -812.67 6033984.65 541308.17 MWD+IFR+MS 6156.72 36.77 231.23 5651.76 5605.96 -1693.81 -856.67 6033953.69 541264.35 MWD+IFR+MS 6251.17 38.05 226.17 5726.80 5681.00 -1731.68 -899.72 6033915.59 541221.52 MWD+IFR+MS 6345.05 38.74 218.73 5800.42 5754.62 -1774.66 -938.99 6033872.39 541182.50 MWD+IFR+MS 6438.50 39.40 212.32 5873.00 5827.20 -1822.55 -973.16 6033824.31 541148.61 MWD+IFR+MS 6534.54 40.10 205.06 5946.88 5901.08 -1876.36 -1002.57 6033770.34 541119.50 MWD+IFR+MS 6628.95 40.08 198.42 6019.14 5973.34 -1932.76 -1025.06 6033713.82 541097.33 MWD+IFR+MS 6723.42 41.93 193.89 6090.45 6044.65 -1992.28 -1042.26 6033654.21 541080.48 MWD+IFR+MS 6819.95 43.31 188.98 6161.50 6115.70 -2056.31 -1055.17 6033590.12 541067.93 MWD+IFR+MS 6914.47 44.94 183.91 6229.36 6183.56 -2121.66 -1062.51 6033524.73 541060.96 MWD+IFR+MS 7007.99 47.45 178.09 6294.12 6248.32 -2189.08 -1063.61 6033457.31 541060.24 MWD+IFR+MS 7104.17 51.26 176.50 6356.76 6310.96 -2261.96 -1060.14 6033384.46 541064.12 MWD+IFR+MS 7196.60 55.73 174.35 6411.74 6365.94 -2335.99 -1054.18 6033310.47 541070.50 MWD+IFR+MS 7290.81 59.86 171.78 6461.94 6416.14 -2415.09 -1044.52 6033231.44 541080.61 MWD+IFR+MS i ~ Halliburton Company Survey Report Company: BP AmOCO Field: Mllne Point Site: M Pt F Pad Wcll: MPF-99 Wdipath: MPF-99 Surve} MD Ind ft dcg im deg D ft - Sys TVB ft ___-- - - Date• 6/5/2007 lime: 10:30:37 Park: 3 Co-ordinate(NE) Reference: Well: MPF-99, True North Vertical (TVD) Reference: MPF-99: 45.8 Section fVS)Reference: Well (O.OON,O.OOE,187.80Azi) Surse}CaiculationMe~hixl: Minimum Curvature Ph: Oracle - - - --- N/S FJW Ir1apN MapE ('rxil ft ft ft ft 7384.50 63.44 170.65 6506.43 6460.63 -2496.56 -1031.91 6033150.05 541093.68 MWD+IFR+MS 7477.79 67.11 168.11 6545.45 6499.65 -2579.81 -1016.27 6033066.89 541109.79 MWD+IFR+MS 7573.57 70.00 165.33 6580.47 6534.67 -2666.55 -995.78 6032980.28 541130.77 MWD+IFR+MS 7666.92 68.29 164.44 6613.70 6567.90 -2750.77 -973.04 6032896.20 541153.99 MWD+IFR+MS 7757.31 69.43 164.29 6646.30 6600.50 -2831.95 -950.31 6032815.15 541177.17 MWD+IFR+MS 7855.39 68.73 163.65 6681.32 6635.52 -2920.00 -925.02 6032727.26 541202.96 MWD+IFR+MS 7909.58 68.64 163.01 6701.02 6655.22 -2968.36 -910.54 6032678.98 541217.71 MWD+IFR+MS 7992.54 68.11 162.30 6731.59 6685.79 -3041.98 -887.54 6032605.51 541241.12 MWD+IFR+MS 8090.63 68.78 161.98 6767.63 6721.83 -3128.81 -859.56 6032518.84 541269.59 MWD+IFR+MS 8183.10 68.18 162.31 6801.55 6755.75 -3210.69 -833.19 6032437.12 541296.43 MWD+IFR+MS 8273.09 68.13 161.71 6835.03 6789.23 -3290.14 -807.39 6032357.83 541322.67 MWD+IFR+MS 8366.47 67.64 162,89 6870.19 6824.39 -3372.55 -781.09 6032275.58 541349.44 MWD+IFR+MS 8459.83 67.45 164.07 6905.85 6860.05 -3455.26 -756.55 6032193.01 541374.44 MWD+IFR+MS 8557.55 66.91 164,25 6943.75 6897.95 -3541.92 -731.97 6032106.51 541399.51 MWD+IFR+MS 8602.50 66.15 163.96 6961.65 6915.85 -3581.57 -720.68 6032066.92 541411.03 MWD+IFR+MS 8690.00 67.21 164.98 6996.29 6950.49 -3658.99 -699.17 6031989.64 541432.97 MWD+IFR+MS 8744.73 66.01 165.79 7018.Oi 6972.21 -3707.59 -686.49 6031941.11 541445.92 MWD+IFR+MS 8812.83 68.00 164.53 7044.62 6998.82 -3768.18 -670.43 6031880.62 541462.32 MWD+IFR+MS 8907.82 68.56 165.34 7079.77 7033.97 -3853.40 -647.50 6031795.54 541485.74 MWD+IFR+MS 9001.77 69.31 164.65 7113.54 7067.74 -3938.08 -624.80 6031711.00 541508.92 MWD+IFR+MS 9096.12 67.34 166.88 7148.39 7102.59 -4023.05 -603.23 6031626.16 541530.96 MWD+IFR+MS 9186.56 66.95 169.33 7183.52 7137.72 -4104.59 -586.05 6031544.73 541548.60 MWD+IFR+MS 9224.70 67.67 170.23 7198.23 7152.43 -4139.22 -579.81 6031510.14 541555.04 MWD+IFR+MS 9270.00 67.67 170.23 7215.44 7169.64 -4180.52 -572.70 6031468.89 541562.39 PROJECTED to TD Halliburton Company Survey Report Company: BPAmoCO Date: 1;'3012007 Time: 1C:47:55 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPF-99, True North Sitc: M Pt F Pad Vertical (TVD) Refer ence: MPF-99: 45.8 Well: MPF-99 ~ M ~ ~ Section(VS)Reference: Well (O.OON,O.OOE,188.44Azi1 O Wellpath: PF-99 Survey Calculation M eshal: Mi nimum Curvature 1)I,: racle Field: Milne Point _ - - -- - North Slope UNITED STATES Map System:US State Pl ane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum; NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: MPF-99 Slot Name: Well Position: +N/-S 5650.12 ft Northing: 6035652.17 ft Latitude: 70 30 29.935 N +E/-W10322.17 ft Easting : 542111.32 ft Longitude: 149 39 19.607 W Position Uncertainty: 0.00 ft Wellpath: MPF-99 Drilled From: Well Ref. Point 500292333200 Tie-on Depth: 34.31? ft Current Datum: MPF-99: Height 45.80 ft Above System Datum: Mean Sea Level Magnetic Data: 12/12/2006 Declination: 23.68 deg Field Strength: 57621 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.30 0.00 0.00 188.44 Survey Program for Definitive Wellpath Date: 9/26/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.00 901.00 MPF-99 Gyro (100.00-901.00) CB-GYRO-SS Camera based gyro single shots 980.55 9069.44 MPF-99 IIFR+MS+Sag (980.55-906 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Intl Azim TVD Sys TVD N/S E/VV MapN MapE Tool ft deg deg ft ft ft ft ft ft 34.30 0.00 0.00 34.30 -11.50 0.00 0.00 6035652.17 542111.32 TIE LINE 100.00 0.18 164.26 100.00 54.20 -0.10 0.03 6035652.07 542111.35 CB-GYRO-SS 170.00 0.48 152.48 170.00 124.20 -0.47 0.19 6035651.71 542111.52 CB-GYRO-SS 259.00 1.05 143.21 258.99 213.19 -1.45 0.85 6035650.73 542112.18 CB-GYRO-SS 351.00 2.11 121.92 350.95 305.15 -3.02 2.80 6035649.17 542114.13 CB-GYRO-SS 441.00 4.70 111.45 440.79 394.99 -5.24 7.64 6035646.97 542118.98 CB-GYRO-SS 531.00 6.91 112.36 530.32 484.52 -8.65 16.08 6035643.61 542127.44 CB-GYRO-SS 621.00 9.12 116.53 619.44 573.64 -13.90 27.47 6035638.43 542138.86 CB-GYRO-SS 713.00 14.24 124.63 709.51 663.71 -23.59 43.31 6035628.83 542154.76 CB-GYRO-SS 806.00 15.62 125.88 799.37 753.57 -37.43 62.87 6035615.10 542174.39 CB-GYRO-SS 901.00 15.69 126.14 890.84 845.04 -52.50 83.60 6035600.15 542195.21 CB-GYRO-SS 980.55 16.63 129.85 967.25 921.45 -66.14 101.03 6035586.61 542212.71 MWD+IFR+MS 1026.21 15.89 129.52 1011.08 965.28 -74.31 110.87 6035578.50 542222.60 MWD+IFR+MS 1120.87 15.54 133.72 1102.21 1056.41 -91.32 130.03 6035561.60 542241.85 MWD+IFR+MS 1211.10 14.88 140.94 1189.29 1143.49 -108.67 146.07 6035544.34 542257.99 MWD+IFR+MS 1304.72 14.88 143.69 1279.77 1233.97 -127.69 160.76 6035525.41 542272.79 MWD+IFR+MS 1398.99 15.75 155.23 1370.71 1324.91 -149.06 173.29 6035504.10 542285.44 MWD+IFR+MS 1491.88 17.05 171.27 1459.87 1414.07 -173.99 180.65 6035479.23 542292.93 MWD+IFR+MS 1589.53 17.67 182.40 1553.09 1507.29 -202.95 182.20 6035450.27 542294.65 MWD+IFR+MS 1686.18 19.19 187.19 1644.79 1598.99 -233.37 179.60 6035419.84 542292.22 MWD+IFR+MS 1781.18 20.77 194.08 1734.08 1688.28 -265.21 173.54 6035387.98 542286.35 MWD+IFR+MS 1872.69 21.39 198.51 1819.47 1773.67 -296.77 164.30 6035356.36 542277.28 MWD+IFR+MS 1968.52 22.34 198.96 1908.41 1862.61 -330.57 152.83 6035322.51 542266.01 MWD+IFR+MS 2063.38 23.56 198.38 1995.76 1949.96 -365.61 140.99 6035287.40 542254.37 MWD+IFR+MS 2156.38 23.81 197.44 2080.92 2035.12 -401.16 129.51 6035251.79 542243.09 MWD+IFR+MS 2251.66 22.22 197.74 2168.62 2122.82 -436.67 118.25 6035216.22 542232.04 MWD+IFR+MS 2347.60 19.90 195.90 2258.14 2212.34 -469.65 108.25 6035183.18 542222.22 MWD+IFR+MS 2441.43 20.28 195.74 2346.26 2300.46 -500.66 99.47 6035152.13 542213.61 MWD+IFR+MS 2536.39 19.18 192.52 2435.65 2389.85 -531.73 91.62 6035121.02 542205.94 MWD+IFR+MS r Halliburton Company Survey Report __ ___ __ -- Cumpan~: BPAmoCO Date: 1/30/2007 Time: 10:dt:55 Page: 2 Wield: Milne Point Co-ordinate(NE) Reference: Well: MPF-99, True North i Site: M Pt F Pad Vert[cal (TVDI Reference: MPF-99: 45.8 well: MPF-99 ~ ~ \ Section (VS} Reference: Well (O.OON,O.OOE,188.44~Azi) 1t'cllpath: MPF-99 Survey Calculation Methal: Minimum Curvature Db: Oracle - __ ___- - _ _ _ I Suncv -- MD Incl lzim TVA Sys TVD NlS F/W MapN MapE 1'001 ft deg deg ft ft ft ft ft ft 2631.23 20.22 190.15 2524.94 2479.14 -563.08 85.35 6035089.64 542199.86 MWD+iFR+MS 2725.36 21.13 191.15 2613.01 2567.21 -595.73 79.21 6035056.95 542193.89 MWD+IFR+MS 2819.25 22.74 190.57 2700.10 2654.30 -630.18 72.60 6035022.47 542187.49 MWD+IFR+MS 2913.91 21.69 190.81 2787.73 2741.93 -665.35 65.97 6034987.27 542181.05 MWD+IFR+MS 3008.32 19.34 193.34 2876.15 2830.35 -697.70 59.09 6034954.88 542174.36 MWD+IFR+MS 3102.32 19.74 194.06 2964.73 2918.93 -728.24 51.64 6034924.30 542167.08 MWD+IFR+MS 3195.88 20.94 193.91 3052.46 3006.66 -759.80 43.78 6034892.70 542159.40 MWD+IFR+MS 3289.66 20.43 190.85 3140.20 3094.40 -792.14 36.67 6034860.33 542152.48 MWD+IFR+MS 3383.86 21.29 189.19 3228.22 3182.42 -825.17 30.85 6034827.27 542146.84 MWD+IFR+MS 3477.71 20.86 189.59 3315.79 3269.99 -858.47 25.34 6034793.94 542141.52 MWD+IFR+MS 3572.89 20.13 190.96 3404.95 3359.15 -891.26 19.40 6034761.12 542135.77 MWD+IFR+MS 3669.14 19.49 190.97 3495.50 3449.70 -923.28 13.20 6034729.07 542129.75 MWD+IFR+MS 3764.07 20.96 190.19 3584.58 3538.78 -955.54 7.18 6034696.78 542123.92 MWD+IFR+MS 3859.56 20.85 189.40 3673.78 3627.98 -989.12 1.38 6034663.17 542118.31 MWD+IFR+MS 3952.96 20.28 190.40 3761.23 3715.43 -1021.44 -4.25 6034630.83 542112.86 MWD+IFR+MS 4047.51 20.21 195.34 3849.94 3804.14 -1053.30 -11.53 6034598.92 542105.76 MWD+IFR+MS 4141.44 20.32 202.29 3938.07 3892.27 -1084.05 -22.01 6034568.12 542095.46 MWD+IFR+MS 4233.18 20.97 209.12 4023.93 3978.13 -1113.13 -36.04 6034538.96 542081.59 MWD+IFR+MS 4326.75 22.09 216.11 4110.99 4065.19 -1141.98 -54.56 6034510.01 542063.23 MWD+IFR+MS 4420.36 23.61 222.69 4197.26 4151.46 -1169.98 -77.65 6034481.88 542040.31 MWD+IFR+MS 4516.80 25.26 223.46 4285.06 4239.26 -1199.12 -104.90 6034452.60 542013.23 MWD+IFR+MS 4611.10 28.14 224.89 4369.30 4323.50 -1229.48 -134.44 6034422.07 541983.86 MWD+IFR+MS 4708.80 31.33 228.28 4454.13 4408.33 -1262.72 -169.67 6034388.63 541948.82 MWD+IFR+MS 4800.83 33.83 231.40 4531.68 4485.88 -1294.63 -207.56 6034356.51 541911.12 MWD+IFR+MS 4834.36 34.80 232.41 4559.37 4513.57 -1306.29 -222.44 6034344.77 541896.31 MWD+IFR+MS 4927.04 34.68 233.10 4635.53 4589.73 -1338.25 -264.48 6034312.57 541854.46 MWD+IFR+MS 5020.89 33.95 234.39 4713.05 4667.25 -1369.55 -307.14 6034281.04 541811.98 MWD+IFR+MS 5115.51 33.25 237.90 4791.87 4746.07 -1398.72 -350.60 6034251.62 541768.69 MWD+IFR+MS 5210.45 32.06 239.03 4871.80 4826.00 -1425.52 -394.25 6034224.58 541725.19 MWD+IFR+MS 5304.57 31.71 240.33 4951.72 4905.92 -1450.61 -437.17 6034199.24 541682.43 MWD+IFR+MS 5400.07 32.00 241.96 5032.84 4987.04 -1474.93 -481.31 6034174.68 541638.43 MWD+IFR+MS 5496.35 32.91 241.71 5114.08 5068.28 -1499.32 -526.86 6034150.03 541593.02 MWD+IFR+MS 5590.05 33.53 241.78 5192.46 5146.66 -1523.62 -572.07 6034125.48 541547.95 MWD+IFR+MS 5685.82 35.41 240.30 5271.42 5225.62 -1549.88 -619.49 6034098.95 541500.69 MWD+IFR+MS 5780.46 35.82 239.82 5348.35 5302.55 -1577.39 -667.24 6034071.18 541453.09 MWD+IFR+MS 5876.53 35.96 240.12 5426.18 5380.38 -1605.57 -716.00 6034042.72 541404.50 MWD+IFR+MS 5969.86 36.68 238.94 5501.38 5455.58 -1633.61 -763.64 6034014.42 541357.03 MWD+IFR+MS 6066.25 36.14 239.00 5578.96 5533.16 -1663.10 -812.67 6033984.65 541308.17 MWD+IFR+MS 6156.72 36.77 231.23 5651.76 5605.96 -1693.81 -856.67 6033953.69 541264.35 MWD+IFR+MS 6251.17 38.05 226.17 5726.80 5681.00 -1731.68 -899.72 6033915.59 541221.52 MWD+IFR+MS 6345.05 38.74 218.73 5800.42 5754.62 -1774.66 -938.99 6033872.39 541182.50 MWD+IFR+MS 6438.50 39.40 212.32 5873.00 5827.20 -1822.55 -973.16 6033824.31 541148.61 MWD+IFR+MS 6534.54 40.10 205.06 5946.88 5901.08 -1876.36 -1002.57 6033770.34 541119.50 MWD+IFR+MS 6628.95 40.08 198.42 6019.14 5973.34 -1932.76 -1025.06 6033713.82 541097.33 MWD+IFR+MS 6723.42 41.93 193.89 6090.45 6044.65 -1992.28 -1042.26 6033654.21 541080.48 MWD+IFR+MS 6819.95 43.31 188.98 6161.50 6115.70 -2056.31 -1055.17 6033590.12 541067.93 MWD+IFR+MS 6914.47 44.94 183.91 6229.36 6183.56 -2121.66 -1062.51 6033524.73 541060.96 MWD+IFR+MS 7007.99 47.45 178.09 6294.12 6248.32 -2189.08 -1063.61 6033457.31 541060.24 MWD+IFR+MS 7104.17 51.26 176.50 6356.76 6310.96 -2261.96 -1060.14 6033384.46 541064.12 MWD+IFR+MS 7196.60 55.73 174.35 6411.74 6365.94 -2335.99 -1054, i 8 6033310.47 541070.50 MWD+IFR+MS 7290.81 59.86 171.78 6461.94 6416.14 -2415.09 -1044.52 6033231.44 541080.61 MWD+IFR+MS 7384.50 63.44 170.65 6506.43 6460.63 -2496.56 -1031.91 6033150.05 541093.68 MWD+IFR+MS Halliburton Company Survey Report • ~ Company: BP Amoco Date: 1/30!2007 Time: 10:41:55 ~ Page: 3 Field: Mil ne Point Co-ordinate(NE) Reference: W eII: MPF-99, True North Site: M Pt F Pad Vertical {TVD) Reference: MPF-99: 45.8 Well: MPF-99 ~ ~ Section (~S) Rct'erence: W eII (O.OON,O.OOE,1 88.44Azi) Wellpath: MPF-99 T Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Tncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ti ft fi ft ft ft 7477.79 67.11 168.11 6545.45 6499.65 -2579.81 -1016.27 6033066.89 541109.79 MWD+IFR+MS 7573.57 70.00 165.33 6580.47 6534.67 -2666.55 -995.78 6032980.28 541130.77 MWD+IFR+MS 7666.92 68.29 164.44 6613.70 6567.90 -2750.77 -973.04 6032896.20 541153.99 MWD+IFR+MS 7757.31 69.43 164.29 6646.30 6600.50 -2831.95 -950.31 6032815.15 541177.17 MWD+IFR+MS 7855.39 68.73 163.65 6681.32 6635.52 -2920.00 -925.02 6032727.26 541202.96 MWD+IFR+MS 7909.58 68.64 163.01 6701.02 6655.22 -2968.36 -910.54 6032678.98 541217.71 MWD+IFR+MS 7992.54 68.11 162.30 6731.59 6685.79 -3041.98 -887.54 6032605.51 541241.12 MWD+IFR+MS 8090.63 68.78 161.98 6767.63 6721.83 -3128.81 -859.56 6032518.84 541269.59 MWD+IFR+MS 8183.10 68.18 162.31 6801.55 6755.75 -3210.69 -833.19 6032437.12 541296.43 MWD+IFR+MS 8273.09 68.13 161.71 6835.03 6789.23 -3290.14 -807.39 6032357.83 541322.67 MWD+IFR+MS 8366.47 67.64 162.89 6870.19 6824.39 -3372.55 -781.09 6032275.58 541349.44 MWD+IFR+MS 8459.83 67.45 164.07 6905.85 6860.05 -3455.26 -756.55 6032193.01 541374.44 MWD+IFR+MS 8557.55 66.91 164.25 6943.75 6897.95 -3541.92 -731.97 6032106.51 541399.51 MWD+IFR+MS 8602.50 66.15 163.96 6961.65 6915.85 -3581.57 -720.68 6032066.92 541411.03 MWD+IFR+MS 8695.57 67.28 165.04 6998.44 6952.64 -3663.95 -697.84 6031984.68 541434.33 MWD+IFR+MS 8752.23 69.80 165.28 7019.17 6973.37 -3714.92 -684.33 6031933.80 541448.12 MWD+IFR+MS 8773.36 70.87 164.73 7026.28 6980.48 -3734.14 -679.18 6031914.61 541453.38 MWD+IFR+MS 8828.80 72.06 164.61 7043.90 6998.10 -3784.83 -665.29 6031864.00 541467.56 MWD+IFR+MS 8884.48 70.61 165.57 7061.72 7015.92 -3835.80 -651.71 6031813.11 541481.43 MWD+IFR+MS 8978.82 69.22 165.22 7094.12 7048.32 -3921.54 -629.37 6031727.51 541504.25 MWD+IFR+MS 9069.44 65.88 164.76 7128.72 7082.92 -4002.42 -607.69 6031646.76 541526.39 MWD+IFR+MS 9106.00 65.88 164.76 7143.66 7097.86 -4034.62 -598.92 6031614.62 541535.34 PROJECTED to TD Schlumberger Alaska Data & Consul4ing Services 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh ~ ~~~~~a~ 1, ~. ~~Q ., ~''~ N -~ ; _p~, ~CYIT1tY11Sa4t~Y1 °l11,~t:.~C Lnn Descrintinn NO. 4281 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Data RI Cnler CD 06/06/07 05-22A, 11745219 MEMORY CBL OS/24/07 1 09-15 11557116 USIT 04/09/07 1 F-09A 11657123 CBL 05106107 1 MPS-01A 11886746 USIT (CORROSION) 05/18/07 1 MPS-01A~ 11886746 USIT (CEMENT) 05/18/07 1 MPF-99 11638629 SCMT 05!03!07 1 J-12 11686735 RST 04/14/07 1 1 L1-14 11421033 RST 10111/06 1 1 R-13 11686733 RST 04N1/07 1 1 J-19 11686738 RST 04/21/07 1 1 L2-33 11421034 RST 10N 1106 1 1 N-04A 11540225 RST 12/11/08 1 1 15-05A 11054307 RST 07/15/05 1 1 YLtASt AGRNUWLtUGt KtGt1Y I I3Y SIGNING ANU Ktl UKNING UNt GUYY EAGK IU: BP Exploration (Alaska) Inc. Petrotechnical Data Genter LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ d ~ "~ rl ~~„ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: ~~ Milne Point F-99 Single Well Chemical Tracer Test Maunder, Thomas E (DOA) From: Leonard, Nathan (Nathan.l.eonardt~BP.com] Sent: Wednesday, May 09, 2007 7:19 AM To: tom maunder@admin.state.ak.us Subject: Milne Point F-99 Single Well Chemical Tracer Test Tom, Page 1 of 1 ~~~~-15~ BP is planning to perform a Single Well Chemical Tracer Test on the F-99 wet) in June. I believe that Danielle ohms had notified you of the test back in December of 2006. The test was delayed for several months due to our inability to get core. We have since sidetracked, cored, and completed the F-99. The #est will be carried out in June. It has been mentioned that sundry approval is not needed, but !wanted to inform you of our intentions to pump the tracer test. Let me know if anything else is needed before starting this test. Thanks Nathan Leonard Petroleum Engineer Milne Point Subsurtace Team 564-4745 748-1387 cell P~`~~~ ~~ ~ ~v~` 9/6/2007 WELL LOG TRANSiVIITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-99, March 1 ~ , 2007 AK-MW-4794046 1 LIS formatted CD with verification listing. API#: 50-029-233 32-00 PLEASE ACKNOWLEDGE RECEIPT BY SIG_'vLNG A COPY OF THE TRANS~IITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99649-6612 ~' i ~ y" Date: Signed: t __ ~ ,; ~-_-..- ,a, _. ~- r ._~ a ~ ~ ~ _ - Ly .A w~ L~ v ~ J ~ ~~ ,r _ t~~ ~ [Fwd: Data Corrections/Data Submittal Requ~nts] . Subject: [Fwd: Data Corrections/Data Subrrlittal Requirements] From: Art Saltmarsh <art_saltn7arsh@admin.state.ak.us> Date: Tue, 03 Apr 2007 06:3:13 -~g(1(1 To: H«~ward I) C?iaartd ~ho~~~ird okland'~rad~nin.stat~.ak.us> -------- Original Message -------- Subject:Data Corrections/Data Submittal Requirements Date:Mon, 02 Apr 2007 18:11:20 -0800 From:Johnson, James H <James,Johnson~abp.coni=~ To:a~~t saltmarsh(~a;admin.state.ak.us Art There has been a header change for all the data collected for MPF-99, the data that was for MPF-J9 now becomes the data for MPF-99PB1. Please make the changes to any data submitted to the state for MPF-9 so for. We are sorry for any inconver;ience. On a very different note. spoke with you a couple weeks ago, regarding data submittal requirements for new wells. We are having problems meeting, the thirty day time frame for data submittal to the state within 30 days. The vendors are working with a huge backlog, and barely getting us the field data for new wells within 30 days. As you know some of the data will take longer to receive i.e., geochemical formation fluid analyses etc. 111/hat I would like to propose is, „getting the field data out in electronic format within 30 days" and pushing the final da#a out to 6(3 days. I think having a little more flexibility will benefit everyone. We will still require the vendors to deliver the data as aeon as possible. Please reply. Regards games x ,~oknson Data Manager Act! Subsurface Team ~P~pCorationAlaska, Inc. 907-564-4173 Office ~c~~~cs~ 1 of 2 4/3/2007 7:09 AM S~4RLiH Pe4LIN, .GOVERNOR ~T~+ ~~~~ ®~ ~~+c~~~T 333 W. 7th AVENUE, SUITE 100 ®i~s7~~~~~^®ig C®~~-7-7I®1~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPF-99 Sundry Number: 307-100 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. - When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend.. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of March, 2007 Encl. ~OCo- c ~ 6 Sincerely, ~~ ,~,/ ~ ~~ R~~~IVED STATE OF ALASKA ~; ~~~~ 2 0 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION la ~ APPLICATION FOR SUNDRY APPROVAL ?'#Pasiia Cii `~ Gas Cons. Corrtmissiort 20 AAC 25.280 Rrac~toraae 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Resume O erations 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-156 ~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23332-00-00• i 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPF-99 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~ ADL 025509 ~ 44.5 ~ Milne Point Unit / Kuparuk River Sands 'i2_ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9106 7144 8570 6948 8570 None Ca in L n th iz MD TVD Burst Colla e Structur I Conductor 112' 20" 112' 112' 1490 470 Surface 4892' 13-3/8" 4892' 4607' 4930 2270 Interm diat Production 7954' 9-5/8" 7954' 6717' 6870 4760 Liner 866' 7-5/8" 7804' - 8670' 6663' - 6989' 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 2-7/8", 6.5# L-80 2225' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ^ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ® Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 21, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Signature Phone 564-4750 Date3~~~a7 Sondra Stewman, 564-4750 Commission Use Onl _ Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity '(BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: __ `` ~~ ~~ ~~ ~~~ ~7~~~ Q~~~~ . 1 Subsequent Form Required: ~,~~~ -® ` ~ APPROVED BY ~ +~ ~ A roved B COMMISSIONER THE COMMISSION Date !i Form 10-403 Revised 06/2006 ~./ ~' p Submit In Duplicate by Tom Maunder • 1. J~. .nk/o {~' Alaska Oil & Gas Conservation Commission March 13th, 2007 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Notification of Resumption of Operations MPF-99 (Drilling Permit 206-156) Mr. Maunder, As you are aware, we temporarily shut down operations on MPF-99 on 01/12/2007 due to problems with our coring equipment in the Kuparuk A-3 and A-2 intervals. This decision was made in order to give our coring services provider sufficient time to analyze the failure and take corrective actions. At the time we left MPF-99 we had plugged the 6-3/4" hole by filling it with 15.8 ppg Class G cement back into the 7-5/8" liner. Cement was tagged at 8620' (50' inside the liner), and pressure-tested to 1200 psi as recorded for 30 minutes (13.3 ppg EMW). The details of the temporary suspension are covered in a previous letter to the commission on January 15, 2007. BP plans to return to MPF-99 in late April or early May to obtain core over the Kuparuk interval, log, pressure sample using GeoTap, and complete the well per the original Well Plan and Drilling Permit. Resumption of operations will require; 1. MIRU on MPF-99 2. ND tree/NU BOPE and test to 4,500 psi 3. Circulate out freeze-protect 4. Pull the Kill String 5. RIH w/ Drilling BHA, Displace to MOBM Coring Fluid 6. Drill out cement and ~20' new hole and FTT to 12.5 7. Drill to core point, POOH and PU coring BHA Remaining activities will be conducted in accordance with the original drilling permit. I have attached schematics showing the current condition of the well and our intended temporary ESP completion for a Single Well Tracer Test. Ultimately, this well will be completed as a 4-1/2" ~-. monobore injector. However, these activities will be addressed at a latter date under a separate Svy~Cy ~.~ Thank you for your continued assistance. If I can provide any additional information, 1 please contact me @ 564-4195. S' ly,. Paul Ha son Drilling Engineer - BPXA /ACT by r.~. ~; BP EXPLORATION ~ „~ r ,;.~ M P F-99 Temporary Operational Shutdown (Current Condition) Field: Milne Point Kuparuk A Sand ENG: P. Hanson Pad: F-Pad Injector RIG: Doyon 14 RKB: 44.5 ft DIR / LWD OH DEPTH HOLE CASING MUD INFO FORM MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 112' 30" Welded, Insul 20" x 11" 5K MWD/GR/PWD None Lead Cement Test Csg to Gyro as needed 585 bbl 2000 psi IFR/Cansandra 10.7 ppg-4.49 ft3/s Base Permafrost 1949' 1850' 2225' Surface Csa 13-3/8" 68# 150% Excess TUZC 3,652' 3450' L-80, BTC In Permafrost Int. Yield 5020 psi Collaspse 2260 psi Schrader Bluff-NB 4,205' 3,970' Tail Cement 40% Excess Below 124 bbl Permafrost Schrader Bluff-OA 4,334' 4,090' 15.8 ppg-1.17 ft3/s Casing Point 4892' 4,607' 20° 16" MWD/GR/RES None PWD IFR/Cansandra Inter. Casing Cement Slurry 40% Excess 9-5/8" 165 bbl 47 Ibs/ft 15.8 ppg L-80, 1.17 ft3/sx TCII /BTC-M Class "G" Int. Yield 6870 psi Collaspse 4790 psi Top/LNR/ZXP/PBR 7804' 6663' 66° KLGM 7954' 6717' 12.25" MWD/GR/RES ; ; Prod Liner Liner Cement eu/Den/Geo Ta TOC 8,570' ) s;;.~ ) 7-5/8" , 29.7# 60 bbl, 289 sx W D +/- 270' Cor ~ a ~ Liner L-80, HYD 513 Class G, 15.8# 8,670' ~ ~ Point Int. Yield 6890 psi IFR/Cansandra ~ ; ' 15.8 ppy ; , ~ ~ ; Collapse 4790 psi 1.17 ft3/sx NMR TD Pilot 106' 9 7 249' r i i i i Pug ~ i i 6-3/4" lug=27 bbl 15 8 pp , , . 3/14/2007 MPF-99 Suspension Schematic.xls TREE: Car^teron2-9/16".5M ~ROPOSED COMPLETION ~ _ WELLHEAD: FMC Gen 5 11" 6. 5M M P F-99 i CellarDBox) ELEV = 11.5 ft Tubing Head: FMC 11-in x 2.875-in 1I 1I 2' 20" 92 Ib/ft, H-40 Welded Insulated 13.375-in 68-Ib/ft, L-80, BTC Casing Drift: 12.259-in Casing ID: 12.415-in Burst: 5,020-psi Collapse: 2,260-psi 2.875-in 6.5-Ib/ft, L-80, 8rd, EUE Tubing ID: 2.441-in Tubing Capacity: 0.00579-bbl/ft Tensile (100%): 145-k.lbf Burst: 10,570-psi Collapse:13,870-psi 12-1/4" Hole 4-1/2" 12.6# L-80 IBT-M @ 7,675-ft MD Liner Top 100` above shoe. 7-5/8" 29.7#, L-80, Hydril 513 Casing Drift: 6.750-in Casing ID: 6.875-in Coupling OD: 8.500-in Burst: 6,890-psi COIlapse:4,790-psi 42" Hole 2.875-in x 1.0-in Gas Lift Mandrel @ 116-ft TVD 16" Hole 13.375-in @ 4,892-ft MD, 4,607-ft TVDrkb 9-5/8" 47#, L-80,TC11/ BTC-M Casing Drift: 8.525-in Casing ID: 8.681-in Burst: 6,870-psi Collapse: 4,750-psi Halliburton Sliding Sleeve --160` above XN Nipple 2.875-in XN nipple (ID 2.25") Pump, GC1700 Tandem Gas Separator Tandem Seal Section Motor, 171 HP PumpMate Sensor w/6 fin Centralizer 7-5/8 in liner top @ 7,775-ft MD (150-ft lap) 9.625-in casing shoe @ 7,954 MD Well Inclination 67 Degrees 8-1/2" Hole opened to 9-/12" 7-5/8" Shoe @ 8,670-ft MD, 6,989-ft TVD Well Inclination @ Shoe = 67 Degrees TD @ 9,247-ft MD, 7,230-ft TVD Well Inclination @ Shoe = 65 Degrees DATE ~ REV. BY ~ COMMENTS 6-3/4" Hole BP Exploration (Alaska) ~ r 31-Jan-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-99i Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 34.30' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 9,106.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen~HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF~: Sperry-Sun Drilling Services Attn: Timothy ~\Ilen 6900 Arctic Blvd. Anchorage/, AK_99518 Date a ?~~1.0~1 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~, 6 ~, ~ t s'c~ 02/12/2007 Schlumber~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou i~ti ~ ~O~v ° l ~ ~a NO. 4131 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay L5-25 11538589 LDL 72/28/06 1~ VV Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01124/07 1 1-33 11631645 USIT 01109/07 1 A-05A 11533393 USIT 01/04/07 1 DS 05-106 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14/07 1 R-12 11414757 RST 09/01/06 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWDILWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01105107 1 DS 07-04A 11533394 LOL 01/05/07 1 F-23A 11626066 LDL 01/08/07 1 P2-19 11630449 LDL 01/14/07 1 Y-09A 11630450 LDL 01/16/07 1 o~ cnec nrvunun cnnc o BP Exploration (Alaska) Inc. ~ .V.,._.._., v'-~ vv, ~^v'~ ~v. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data 8 Cons -°- 2525 Gambell Street, i Anchorage, AK 99503-2838 ATTN: Beth {i ~° ~ +~r,p~ 7 f' [_ ~ ~ P_111.R1 Received by: ;~~ Via! ~~.~ t~~. t~g~9~5l~31~ Inc ., , -- ~~I I `i ., ~/ STATE OF ALASKA ~~ ~~~`~~ V ~~ AI~KA OIL AND GAS CONSERVATION COti'14~ISSION REPORT OF SUNDRY WELL OPERATIONS DEB 0 8 2007 1. Operations Performed: ' ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Ent~~~~ed Well . ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ®Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 206-156 ~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23332-00-00 ~ 7. KB Elevation (ft): 44.5 d 9• Well Name and Number: ~ MPF-99 ' 8. Property Designation: ~ 10. Field /Pool(s): ~ ADL 025509 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9106 - feet true vertical 7144 feet Plugs (measured) 8570 Effective depth: measured 8570 feet Junk (measured) None true vertical 6948 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 4892' 13-3/8" 4892' 4607' 4930 2270 Intermediate Production 7954' 9-5/8" 7954' 6717' 6870 4760 Liner 866' 7-5/8" 7804' - 8670' 6663' - 6989' 6890 4790 Perforation Depth MD (ft): None Perforation Depth TVD (ft): None Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 2225' Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after proposed work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Wel! Status after proposed work : ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Hanson, 564-4195 307-036 Printed Name Sondra Stewman Title Technical Assistant ~,- Signature ~ `~; ~-;~~__ .,^._...._ Prepared By NamelNumber: Phone 564-4750 Date< - r~'"~ ~ ondra Stewman, 564-4750 n Form 10-404 Revised 04/2006 ~j Submit Original Only ~~~~~~~ by a. ~' ;F~. BP EXPLORATION M P F-99 Temporary Operational Shutdown Field: Milne Point Kuparuk A Sand ENG: P. Hanson Pad: F-Pad InjeCtOr RIG: Doyon 14 RKB: 44.5 ft DIR / LWD OH M DEP TH HOLE CASING MUD INFO MWD LOGS FOR MD TVD SIZE ~ SPECS PIT INFO INFO ~. - 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 112' 30" Welded, Insul 20" x 11 ° 5K MWD/GR/PWD None Lead Cement Test Csg to Gyro as needed t, 585 bbl 2000 psi IFR/Cansandra ~;{`,- 10.7 ppg-4.49 ft3/s Base Permafrost 1949' 1850' - `~-; -'; T~ :..,,~ 2225' - Surface Csg :~ ~ 13-3/8" ~' ' "~ 68# 150% Excess TUZC 3,652' 3450' -` _ L-80, BTC In Permafrost _ - Int. Yield 5020 psi - Collaspse 2260 psi Schrader Bluff-NB 4,205' 3,970' :rx-~ Tail Cement 40 % Excess Below 124 bbl Permafrost Schrader Bluff-OA 4,334' 4,090' t~' 15.8 ppg-1.17 ft3/s Casing Point 4892' 4,60T. ~" 20° ~ 16" MWD/GR/RES None PWD i IFR/Cansandra i i ; = Inter. Casing Cement Slurrv 40% Excess 9-5/8" 165 bbl = 47 Ibs/ft 15.8 ppg L-80, 1.17 ft3/sx TCII /BTC-M Class °G" i Int. Yield 6870 psi Collaspse 4790 psi Top/LNR/ZXP/PBR 7804' 6663' 66° i h _i t .. ~ _ ',, .:;KLGM ,: ~ :7954't ':,'6717. e: ;,12.25" . . ,. ~ :. .. _ MWD/GR/RES ~ ; Prod Liner Liner Cement eu/Den/Geo Ta TOC 8,570' ~¢" r 7-5/8" , 29.7# 60 bbl, 289 sx WD +/- 270' Cor """''~ Liner L-80, HYD 513 Class G, 15.8ff 8,670' Point Int. YIeId 6890 psl IFR/Cansandra Collapse 4790 psi 1.17 ft3/sx 1/19/20 07 MPF- 99 Suspension Sche matic.xls BP AMERICA Page 1 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/9/2006 13:00 - 14:00 1.00 MOB P PRE 14:00 - 15:30 1.50 MOB P PRE 15:30 - 16:30 1.00 MOB P PRE 16:30 - 20:00 3.50 MOB P PRE 20:00 - 00:00 4.00 MOB P PRE 12/10/2006 00:00 - 12:00 12.00 MOB P PRE 12:00 - 00:00 12.00 MOB P PRE 12/11/2006 00:00 - 12:00 12.00 MOB P PRE 12:00 - 22:30 10.50 MOB P PRE 22:30 - 23:00 0.50 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 12/12/2006 00:00 - 02:00 2.00 MOB P PRE 02:00 - 05:00 3.00 MOB P PRE 05:00 - 06:30 1.50 RIGU P PRE 06:30 - 08:00 1.50 RIGU P PRE 08:00 - 15:30 7.50 RIGU P PRE 15:30 - 22:00 6.50 RIGU P PRE 22:00 - 23:30 1.50 R-GU P PRE 23:30 - 00:00 0.50 DRILL P SURF 12/13/2006 00:00 - 02:30 2.50 DRILL P SURF 02:30 - 03:30 1.00 DRILL P SURF 03:30 - 04:00 0.50 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 06:00 1.50 DRILL P SURF 06:00 - 07:00 1.00 DRILL P SURF 07:00 - 11:00 4.00 DRILL P SURF 11:00 - 12:30 1.50 DRILL N DPRB SURF 12:30 - 17:00 4.50 DRILL P SURF 17:00 - 21:30 4.50 DRILL N DPRB SURF 21:30 - 00:00 2.50 DRILL P SURF j 12/14/2006 100:00 - 16:30 16.501 DRILL I P I I SURF 16:30 - 18:30 2.00 DRILL P SURF 18:30 - 20:30 2.00 DRILL P SURF 20:30 - 21:00 0.50 DRILL P SURF 21:00 - 22:00 1.00 DRILL P SURF Skid rig floor Move off well #GNI-02A -Phase 1 conditions Remove cellar doors, heaters, mousehole, and rams Install front and rear boosters -Remove rockwasher landing Move rig off GNI pad on Spine road by PBOC -Phase 1 conditions Move rig from Spine road by PBOC to Spine road and Oxbow Move rig from Spine and Oxbow to across East Channel Bridge Move rig from East Kuparuk Bridge to Texaco Pad Move rig from Texaco Pad to F-pad Attempt to turn rig on pad -Call pad maintenance to remove snow berms on edge of pad Remove front boosters and support frame Remove rear boosters and frame Turn rig around -Move down pad -Spot & shim rig over MPF-99 PJSM -Skid rig floor (Rig accepted @ 0600 hrs due to 2 hr delay waiting on security) Spot & berm rockwasher - R/U mud lines, beaver slide, and rig floor Clear floor - N/U 20" annular, riser, and flowline -Load 153 joints drill pipe and MW D tools in pipeshed -Check and calibrate gas alarms P/U 153 joints of drill pipe from pipeshed and stand in derrick P/U HWDP and jars from pipeshed and stand in derrick Mobilize BHA to floor M/U BHA #1 Upload MWD Fire drill -Evacuation drill -Pre-spud meeting with rig personal and service hands on rig floor Fill hole checking for leaks -Test MW D Drill from 112' to 267' with HWDP (PU 68, SO 68, RW 68, RPM 60, TO 1, 462 gpm, 1100 psi) Stand back 2 stands HWDP - P/U non-mag DC -RIH 1 stand HWDP Drill from 267' to 540' (PU 86, SO 86, RW 86, RPM 60, TO 1, gpm 462, 1100 psi, WOB 25) Close approach issues -Wait on orders from town Drill from 540' to 809' with Gyro surveys (PU 92, SO 94, RW 92, 488 gpm, 1730 psi, RPM 80, TQ 2) Ream out dogleg from 701' to 809' Drill from 809' to 999' with Gyro surveys -AST 4.13, ART 2.01, ADT 6.14 (PU 97, SO 95, RW 97, 552 gpm, 1530 psi, RPM 80, TO 2-5, W OB 19-25) Directional Drill from 999' to 2416' 550-650 gpm 1350-1850 psi - WOB 25k -AST 4.79 ART 5.24 ADT 10.03 - PU 130k - SO 110k RW 123k -RPM 80 - TO 4-6k CBU 3X - w/ 650 gpm 2080 psi -Rotate w/ 80 rpm & reciprocate pipe 90' PJSM -Pump out of hole w/ full drilling rate to 720' (No problems) RIH from 702' to 2322' -Wash last stand down to 2385' Circulate thick mud out -Stage up to 1120 psi ~ 455 GPM Printed: 1/30/2007 11:42:40 AM BP AMERICA Operations Summary Report Page 2 of 15 ~ Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 12/14/2006 22:00 - 00:00 2.00 DRILL N RREP SURF 12/15/2006 00:00 - 02:00 2.00 DRILL N RREP SURF 02:00 - 02:30 0.50 DRILL P SURF 02:30 - 00:00 21.50 DRILL P SURF 12/16/2006 100:00 - 10:30 10.501 DRILL I P I SURF 10:30 - 13:00 I 2.501 DRILL I P I I SURF 13:00 - 18:00 5.00 DRILL P SURF 18:00 - 20:00 2.00 DRILL P SURF 20:00 - 00:00 4.00 DRILL P SURF 112/17/2006 100:00 - 04:00 I 4.001 DRILL I P I I SURF 04:00 - 10:30 ! 6.501 DRILL I P I I SURF 10:30 - 14:00 I 3.501 DRILL I P I I SURF 14:00 - 16:30 2.501 DRILL I P SURF 16:30 - 00:00 I 7.501 CASE I P I I SURF 12/18/2006 100:00 - 03:30 I 3.501 CASE I P I I SURF 03:30 - 05:00 I 1.501 CASE P I SURF 05:00 - 06:00 1.00 CASE P SURF 06:00 - 1,0:00 4.00 CASE P SURF 10:00 - 13:00 3.00 CEMT P SURF 13:00 - 15:00 2.00 CASE P SURF #1 conveyor chain jumped sprocket -Trouble shooting conveyor Re-install chain on sprocket - Re-align sprocket on #1 conveyor Wash to 2416' staging pumps up to 650 gpm / 2140 psi Directional drill from 2416' to 4210' (AST = 4.35, ART = 11.14, ADT = 15.49, TST = 13.27, TRT = 18.39, TDT = 31.66, PU 175, SO 128, RW 150, RPM 80, TO on 10, TO off 7, WOB 30, 640 gpm ~ 2480 psi on/ 2160 psi off) Directional drill from 4210' to 4777' (ART = 4.48, AST = 4.48, ADT = 8.69, PU 187, SO 140, RW 160, RPM 160, TO 9, WOB 25) Circulate and condition mud (PU 187, SO 140, RW 160, RPM 80, TO 9, 440 gpm, 740 psi} -Work on #2 mud pump Pump out of hole from 4779' to 720' (424 gpm ~ 1110 psi) - Flow check -Blow down top drive -Working on # 2 mud pump RIH from 720' to 4779' -Wash last stand to bottom Drill from 4779' to 4902' (AST=1.34, ART=1.96, ADT=3.3, TST=19.09, TRT=24.56, TDT=43.65, PU 185, SO 140, RW 160, RPM 80, TO 12 on, TO 9 off, WOB 35, GPM 645, 2500 psi on, 2340 psi off) Circulate and condition ~ 4902' (PU 190, SO 140, RW 160, RPM 100, TQ 8, 656 GPM, 2260 psi) Observe well -Pump out of hole stringing "G"seal pill - Continue to pump out w/ 650 gpm 1800 psi to 177' Stand back DC's - LD UBHO -Down load MWD - LD MW D, stab, motor & bit PJSM -Clean/Clear rig floor of BHA - MU Franks fill up tool - Change to long bales - RU casing equipment PJSM -Run 93 joints of 13 3/8" 68# L-80 BTC casing to 3700' - Fill every joint -Break circ. every 10 jts. -Run 25 centralizers on jts #1 to #25 - (PU 340, SO 205, GPM 212, 360 psi) Continue run 13 3/8" L-80 68# casing from 3700' to 4892' (122 joints total) -Break circulation every 10 jts - (210 gpm ~ 360 psi) -Circulate last 2 jts down -Land casing Stage up from 2 bpm to 5 bpm with Frank's running tool - Circulate bottom's up (5 bpm ~ 340 psi) Rig down Frank's tool -Make up cement head - Circulate & condition mud for cement job PJSM w/ all involved with upcoming operation -Give to Schlumberger -Pump 10 bbls H2O • Test lines to 4000 psi - Pump 20 bbls CW 100 - 100 bbls Mud Push II at 10.6 ppg - Drop bottom plug -Pump lead cement, 585 bbls ASL at 10.7 ppg w/ 5 bpm 300 psi -Stage up to 6.75 bpm 460 psi followed by tail cement, 124 bbls 15.8 ppg class "G" w/ .2% D046 - .3% D065 - .33% D167 - .1 % D013 & .02 gal/sk D110 w/ 4 bpm 375 psi -Stage up to 5 bpm 675 psi -Drop top plug, kick out w/ 10 bbls H2O Displace cement w/ rig pumps - 10 bpm 330 psi -Caught up w/ cement at 400 stks -Slow to 8 bpm 400 psi -Cement to surface at 3600 strokes away -Slow pumps to 5 bpm - Continue displacing.- Final circ. pressure 1300 psi -Bump plug w/ 2500 psi -Hold 10 min -Check floats - OK - CIP ~ 15:00 i hrs -Total cement to surface 320 bbls rnnreo: v;iwzwi 77:4L:4U AM i • BP AMERICA Page 3 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 12/18/2006 15:00 - 17:30 2.50 CASE P SURF 17:30 - 20:30 3.00 CASE P SURF 20:30 - 22:30 2.00 BOPSU P SURF 22:30 - 00:00 1.50 BOPSU P SURF 12/19/2006 00:00 - 02:00 2.00 BOPSU P SURF 02:00 - 03:30 1.50 BOPSU P SURF 03:30 - 07:00 3.50 BOPSU P SURF 07:00 - 08:00 1.00 CASE P SURF 08:00 - 11:30 3.50 BOPSU P SURF 11:30 - 12:30 I 1.001 BOPSUF# P I I SURF 12:30 - 13:30 1.00 CASE P SURF 13:30 - 18:00 4.50 CASE P SURF 18:00 - 21:30 3.50 CASE P SURF 21:30 - 23:00 1.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 12/20/2006 00:00 - 01:00 1.00 CASE P SURF 01:00 - 02:00 1.00 CASE P SURF 02:00 - 04:00 I 2.001 DRILL P I I SURF 04:00 - 05:00 1.00 CASE P SURF 05:00 - 09:00 4.00 CASE P SURF 09:00 - 10:00 1.00 EVAL P SURF 10:00 - 11:30 1.50 DRILL N WAIT INT1 11:30 - 00:00 12.50 DRILL P (NT1 12/21/2006 100:00 - 09:00 9.001 DRILL I P I I INT1 09:00 - 12:30 3.50 DRILL P INTi 12:30 - 13:30 1.00 DRILL P INT1 13:30 - 15:00 1.50 DRILL P INT1 R/D cement head -Flush stack - UD landing joint -Clear and clean floor Safety stand down w/ Doyon and service personnel assigned to Rig 14 PJSM - R/D riser, knife valve, annular preventor, and remove from cellar area Install and orient FMC wellhead NU BOP stack, riser, flowline, and install secondary annulus valve on OA -Test metal to metal seal to 1000 psi for 10 minutes with FMC PJSM - MU test joint - R/U test equipment Safety stand down Doyon and service personnel assigned to rig 14 Service rig Test BOPE -Annular to 250 psi low, 2500 high f/ 5 min each - Top VBR's -Choke manifold -Choke /Kill HCR -Choke /Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's -Perform accumulator test -Test Blind rams to 250 psi low, 4500 high f/ 5 min. each -Jeff Jones with AOGCC witnessed test -All tests witnessed by WSL RD testing equipment -Install wear ring -Blow down Choke / Kill lines -Choke manifold Install Bails -Elevators - Moblize BHA to rig floor PJSM - MU Geo-Pilot -Bit -MWD - Up load MWD -Float sub - Flex collars -HWDP -Test Geo-Pilot -HWDP -Jars PU5"DP1X1 Cut drlg line -Service Blocks /Crown /Top Drive Con't RIH from 3923' to 4772' -CBU -GPM 500 - PP 1430 - PU 200 - SO 140 -ROT 165 - Con't CBU RU testing equip -Test casing to 2100 psi for 30 chart recorded minutes -Test good - RD testing equip -Blow down choke /kill lines -choke manifold Tag cement 4798' -Drill cement to 4808' drill plugs and float f~ 4811' -Drill cement shoe to 4892' -Clean out 16" hole to 4902' - Drill 20' new hole to 4922' -GPM 512' - PP 1480 -RPM 100 - TO 10 to 20k -POW 210 - SO 140 -ROT 160 Circulate hole clean -GPM 600 - PP 2005 -RPM 50 - TO 10 Displace to LSND 8.9 ppg -Pump 40 bbls fresh water - 70 bbls Hi-vis spacer -Followed by 690 bbls 8.9 ppg LSND mud RU test equipment -Perform F.I.T. to 12.0 EMW - w/ 8.9 ppg - 750 psi -Shoe TVD = 4606' = 12.0 EMW - 2.8 bbls pumped - .5 bbls back - RD test equip. Working disposal issues - GNI and 1 R disposal wells down Directional Drill f/ 4922` to 5540' - WOB 25 to 35 -RPM 100 to 150-TO on 10 to15K-Off14K-GPM650-PPon1890off 1840 -POW 225 -SOW 140 - ROTW 175 -ECD 9.35 Directional Drill from 5540' to 6110'- WOB 30k -RPM 100 to - 150-TOon 10 to15K-Off13K-GPM550-PPon1640off 1590 -POW 240 -SOW 152 - ROTW 183 -ECD 9.41 CBU 3x w/ 596 gpm 1850 psi - 120 rpm - 8k tq ,Pump out of hole f/ 6110' to 4863' w/ 500 gpm 1290 psi CBU at shoe w/ 500 gpm 1290 psi - R&R DP w/ 100 rpm -Flow Printetl: 1/30/2007 11:42:40 AM BP AMERICA Operations Summary Report Page 4 of 15 ~ Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2006 13:30 - 15:00 1.50 DRILL P INT1 15:00 - 16:30 1.50 DRILL N DFAL INTt 16:30 - 20:00 3.50 DRILL N DFAL INT1 20:00 - 20:30 0.50 DRILL N DFAL INTt 20:30 - 00:00 3.50 DRILL N DFAL INT1 12/22/2006 00:00 - 01:00 1.00 DRILL N DFAL INT1 01:00 - 03:00 2.00 DRILL P INT1 03:00 - 05:00 2.00 DRILL P INT1 05:00 - 07:00 2.00 DRILL P INT1 07:00 - 00:00 17.00 DRILL P INT1 12/23/2006 00:00 - 06:00 6.00 DRILL P INT1 12/24/2006 00:00 - 05:00 5.00 DRILL P INT1 05:00 - 08:30 3.50 CASE P INT1 08:30 - 11:30 3.00 CASE P INTi 11:30 - 12:30 1.00 CASE P INT1 12:30 - 14:00 1.50 CASE P INT1 14:00 - 15:30 1.50 CASE P INT1 15:30 - 20:00 4.50 CASE N DPRB INT1 20:00 - 21:30 1.50 CASE P INTi 21:30 - 23:00 1.50 CASE P INT1 23:00 - 00:00 1.00 CASE P INTt 12/25/2006 00:00 - 03:00 3.00 CASE P INT1 03:00 - 05:30 2.50 CASE P INT1 check -Dry job POH f/ 4863' to 801' Stand back HWDP -Collars -Down load MWD -Clean Geo-pilot -Bit PJSM -Clear /clean rig floor -Mobilize BHA to rig floor MU BHA -Bit -Motor -Stabilizer - Mwd -Orient - Up Load MWD -Surface test MWD -HWDP -Jars RIH f/ 818' to 13 3/8" casing shoe at 4892' -Fill pipe every 25 stands Cont. RIH f/ 4892' to 6110' -Fill pipe every 25 stands -Break circ -Wash last stand to bottom, hole in good shape Directional drill f/ 61 f 0' to 6203' - W OB 30 -RPM 80 - TO on ~ 8/11 k /off 7k -GPM 610 - PP on 2000 /off 1780 -POW 200k - SOW 175k - ROTW 180k -ECD 9.64 ppg Ream hole to reduce DLS -RPM 80 - TO off 6k -GPM 610 - PP 1750 Directional Drill from 6203' to 6933' - WOB 30/38k -RPM 80 - TOon8k/off6k-GPM610-PPon1930/off1700-POW 210k -SOW 174k - ROTW 192k -ECD 9.59 ppg Directional Drill 12 1/4" hole f/ 6933' to 7805' - WOB 30/43k - -~ RPM 80 - TO on 10k /off 7k -GPM 650 - PP on 2600 psi /off 2400 psi -PUW 212k -SOW 170k - ROTW 190k -ECD 10.38 PP9 Directional Drill 12 1/4" hole f/ 7805' to 7958' (TD 12 1/4" hole) ~ -WOB40to43-RPM80-TOonlO-off7-GPM655-PPon 2640 -off 2450 -PUW 212 -SOW 170 - ROTW 190 -ECD 10.33 Circulate hole clean -GPM 650 - PP 2400 - PP 2350 -RPM 80 - TO 8K -Mud wt. 10.1 ppg -ECD 10.28 ppg -Flow check - Well static Pump out to 13 3/8' shoe w/full drlg rate -Observed 40k over pull at 5390' -Ream &Backream to clean up - OK CBU at 13 3/8" shoe (4892') -Rotate & reciprocate - 614 gpm, 1970 psi - 60 rpm- TO 3K Observe well -Well static -Cut drilling line -Service rig RIH f/ 4880' to 6870' -Hit tight spot ~ 6870' - (No issues at 5390'} Ream &Backream from 6870' to 7958' -GPM 525 - PP 1600 - RPM 80 - TO 8K - Clean up hole CBU1.5X -GPM650-PP2430-RPM 80-T07K-ECD 10.35 Flow check -Well static -Pump out from 7958' to 6455' -GPM 487 -Slight pack-off depths - 7743, 7640, 7441, 7345, 6946, 6930, 6911, 6820, 6611 RIH from 6455' to 6926' -Hit tight spot -Set down 15K -Work down to 40K would not pass 6926' -Ream through tight spot from 6910' to 6964' - PU to 6910 -Run through section without pump - No tight area observed - Con't RIH from 6964' to 7958' - No problem areas noted CBU2X-GPM600-PP2130-RPM 80-T012to8-ECD 10.23 Pump out from 7958' to shoe ~ 4880' - 35K overpull @ 5390' - Ream down no issues -Pull through with out pump 30 over - Printed: 1/30/2007 11:42:40 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 112/25/2006 103:00 - 05:30 I 2.501 CASE I P 05:30 - 07:00 I 1.501 CASE I P Start: 12/6/2006 Rig Release: 1 /17/2007 Rig Number: Page 5 of 15 ~ Spud Date: 12/13/2006 End: 1 /10/2007 Phase Description of Operations INT1 INTi 07:00 - 09:00 2.00 CASE P INT1 09:00 - 10:30 1.50 CASE P INT1 10:30 - 13:00 2.50 CASE P INT1 13:00 - 14:00 1.00 CASE P INT1 14:00 - 15:30 1.50 CASE P INT1 15:30 - 19:30 4.00 CASE P INT1 19:30 - 20:00 0.50 CASE P INTt 20:00 - 21:30 1.50 CASE P INT1 21:30 - 22:00 0.50 CASE P INT1 22:00 - 00:00 2.00 CASE P INT1 12/26/2006 00:00 - 03:00 3.00 CASE P INT1 03:00 - 04:00 1.00 CASE P INT1 04:00 - 10:00 6.00 CASE P INT1 10:00 - 14:30 ~ 4.50 ~ CASE ~ P ~ ~ INT1 14:30 - 16:30 I 2.001 CEMT I P I I INTi 16:30 - 18:00 1.501 CEMT P I INT1 18:00 -20:00 2.001 CASE I P INTi 20:00 - 21:00 ( 1.00 CASE I P INT1 21:00 - 00:00 3.00 CASE P INT1 12/27/2006 00:00 - 01:30 1.50 CASE P INTi 01:30 - 03:00 1.50 CASE P INT1 03:00 - 03:30 0.50 CASE P INT1 03:30 - 05:00 1.50 CASE P INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 06:30 0.50 CASE P INT1 06:30 - 07:00 I 0.501 CASE I P I I INT1 RIH with out pump -good - (no packing off) -Hole in good shape Flow check at shoe - CBU w/ 600 gpm 1850 psi - R&R DP 60 rpm, 5k torque POH to BHA Stand back HWT. - LD 8" DC's Down load MWD - LD MWD, motor & bit Clear /Clean rig floor -Pull wear ring -Install test plug Change upper rams to 9 5/8" casing rams -Test door seals to 1500 psi PJSM - RU 9 5/8" casing equipment -PJSM Running casing PJSM - PU float equipment -Check floats PU /Run 9 5/8" BTC-M 47# L-80 casing to 1455' Rig up Torque turn equipment - (Girt casing volume) Con't PU /Run 9 5/8" TC11 47# L-80 casing to 2917' PU /Run 9 5/8" TC11 47# L-80 Casing from 2917' to 4850' Circ casing volume -BPM 8 - PP 560 Con't Run 9 5/8" casing from 4850 to 7905' - Tight ~ 6338 - Work string 4 X - Tight ~ 7061' -work pipe 3 X Break Circulation -Stage up pump from 2 1/2 bpm to 6 1/2 bpm -Wash from 7905' to 7954' - PP from 450 to 300 - PU 430 - SO 250 -Circulate 1.5 casing volume - LD Franks tool - MU Shclumberger cement head /lines -Circulate one bottoms up -Give to Schlumberger Pump 10 bbls water - 3.5 bpm ~ 275 psi Test lines to 4000 Pump 20 bbls CW-100 - 3.5 bpm @ 275 Pump 70 bbls Mud Push mixed at 12 ppg - 4 bpm ~ 250 Drop bottom plug Mix and pump 165 bbls 792 sxs -Yield 1.17 -Class "G" mixed at 15.8 ppg - 4 ~ 200 Drop top plug Pump 10 bbls water - 2.5 ~ 150 Give to rig Displace with 567 bbls of 10.1 ppg mud - 6.5 bpm ~ 220 - Final pump rate 3 bpm ~ 600 psi -Bump plug with 1600 psi - Hold for 10 mins record on chart -Bleed off pressure -Floats holding - CIP 17:50 hrs -Reciprocate string PU 400 to 480 - SO 265 to 235 RD Cement head -Clear rig floor -Void casing -Flush stack / tubing head /well head ND choke -Flow line -Stack -Raise stack for setting slips and cut off Set emergency slips with PUW 3751< -Cut casing - LD cut jt - Length cut 23.40' Install 9 5/8" Pack-off - RILDS Change out tubing spools ,Test pack-off to 3800 psi for 15 mins -Test good NU BOP's -Install secondary valve on tubing spool Change 9 5/8" csing rams to 4 1/2" x 7" VBR's Bullhead 30 bbls mud down OA - 2 BPM -PSI 900 ICP - 750 FCP RU to test BOP's f'nntea: usvizvv~ ii:az:nunrh l~ BP AMERICA Page 6 of 15 ~ Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/27/2006 07:00 - 10:30 I 3.501 CASE I P I INT1 10:30 - 11:00 I 0.501 CASE I P I I INTi 11:00 - 11:30 I 0.501 CASE I P I I INT1 11:30 - 12:00 0.501 CASE P INTi 12:00 - 13:00 1.00 CASE P INT1 13:00 - 16:30 3.50 CASE P INT1 16:30 - 19:30 I 3.001 CASE I P I I INT1 19:30 - 21:00 1.50 CASE P INT1 21:00 - 22:00 1.00 CASE P INT1 22:00 - 22:30 0.50 CASE P INT1 22:30 - 00:00 1.50 EVAL P INT1 12/28/2006 00:00 - 01:00 1.00 EVAL P INT1 01:00 - 03:30 I 2.501 DRILL I P I I INT1 03:30 - 05:00 1.50 CASE P INT1 05:00 - 06:30 1.50 DRILL P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 08:30 1.00 DRILL P INT1 08:30 - 09:30 1.00 DRILL P PROD1 09:30 - 14:00 I 4.501 DRILL I P I I PROD1 14:00 - 19:00 I 5.00 DRILL N DPRB PROD1 Test BOP's -Annular 250 low 2500 high -Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Jeff Jones waived witness of BOP test -All test were witnessed by W SL - RD testing equipment -Shut annulus valve -Pull test plug - Install wear ring Bullhead 30 bbls mud down OA - 2 BPM -PSI 1060 ICP 750 psi FCP Install bails and elevators. RU floor, mobilize BHA, hold PJSM PJSM - MU Geo-Pilot -Bit -MWD - Up load MWD -Float sub - Flex collars -HWDP -Surface test MWD -Jars -HWDP RIH from 804' to 7414' Fill pipe every 25 stands -Function test Geo-pilot Cut Drlg line -Rig service -Blocks -Crown -Top Drive RIH from 7414' to 7696' -Function Geo-pilot seals -Wash down from 7696 to 7853 tag cement RU testing equipment - RU line from test pump Test casing to 4000 psi with rig pump - Con't test with test pump to 4500 psi - Test 9 5/8" casing - RD testing equipment -Blow down choke and kill Drill cement on top of float collar -Shoe track to 7953' - WOB 5 to 10-RPM50-TQ 18 to22-GPM420-PP 1400 CBU -GPM 432 - PP 1358 -RPM 50 - TO 15K Displace with new 10 ppg LSND mud Drill shoe @ 7953 -New hole to 7980' - WOB 5 to 10 - CBU Preform FIT - MD 7954 - TVD 6719 - 10 ppg - 1400 PSI = EMW 14 Directional Drill from 7980 to 8257' - WOB 10 -RPM 140 - TO I 15 to 20 on-15 off-GPM450-PP1950 on-1940off-PUW 242 -SOW 140 - ROTW 175 - ECD 10.97 Flow increase -Shut in well - DP 20 - Casg 50 - 10 bbl gain - Montiorwell /filling gas buster with mud -Notified AOGCC (Chuck Scheve) -Milne PT Well operations supervisor (John Cubbon) -Dan Kara Senior Engineer (Anchorage) -Attempt to circulate influx out using drillers method holding 420 psi on DP - 0 pressure on casg - (SPR 30 Stks 280 psi) - DP pressure varied between 420 to 1200 due to packing off -Shut well in with hydraulic choke -work string through annular 285K up 100K down - String appeared to be free -Bring pump on ,pressure oaring 600 to 920 psi - By-pass Geo-pilot manifold - Pumped total of 1400 stks pit gain 10 bbls -Shut in well with hydraulic choke - DP 20 pressure 150 casing -Gained additional 10 bbls for 31 total -Shut manual valve in front of Hydralic choke - DP pressure 450 psi -Casing 470 -Bring on pump holding casing constant to equivalent mud weight of 12.5 ppg = 1230 DP - 960 casing peessure -Circulate influx out holding 1230 psi on DP -Casing pressure decreased 960 to 740 -Shut down pump bleed off casing pressure to 20 psi - Print2tl: 1/30/2007 11:42:40 AM BP AMERICA Page 7 Of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 12/28/2006 14:00 - 19:00 5.00 DRILL N DPRB PRODi Shut well in with manual valve -Let stablize for 25 mins DP pressure 670 -Casing 520 psi 19:00 - 00:00 5.00 DRILL N DPRB PROD1 Circulate hole using drillers method holding 1100 psi on DP - Casing 660 psi -Order 12.5 ppg kill mud 12/29/2006 00:00 - 15:00 15.00 DRILL N DPRB PROD1 Circulate holding 1080 psi on DP 670 on casing at 30 spm- Waiting on kill mud 15:00 - 16:00 1.00 DRILL N DPRB PROD1 Started displacing hole with 12.5 ppg mud using the Driller's Method. Held casing pressure constant at 670 psi and pumped 12.5 ppg kill mud down the drillpipe at 30 spm. Initial circulating drillpipe pressure 1080 psi decreased to 340 psi as kill mud exited the bit with 1470 strokes pumped. Switch to drillpipe and held drillpipe pressure gauge constant at 340 psi while circulating kill mud up the annulus. At 1900 strokes (50 bbls of kill mud in annulus) well started packing off. Well was completely packed off at 2000 strokes pumped (DP 1120 psi - casing 470 psi). Attempted to work pipe through annular preventor to break pack off with no success. PU 320K SO 100K. 16:00 - 18:00 2.00 DRILL N DPRB PROD1 Bled pressure off of well, Open annular preventer. Worked pipe free with rotation at 50 RPM at 18K torque. Slowly brought up pump to 30 spm at 310 psi. Pumped 14 bbls of mud total with 1 bbl gain. Shut down pump and closed well back in with annular peeventer. Attempted to resume circulating schedule. Drill pipe immediately packed off and DP pressure increase to 600 psi with slow bleed off. Bled off pressure and and opened annular began working pipe. RPM 80 TO 15-20K- Broke circulation at 1.5 bpm and increased to 3.0 bpm. Pumped a total of 34 bbls and gained 2 bbls of mud in pits. Shut down rotary and pump and closed in well with annular preventer. Attempted to resume pumping schedule and drill pipe instantly packed off with 900 psi on drill pipe. Bled off drill pipe pressure. Monitored well and DP pressure increase to 40 psi -casing 170 psi. 18:00 - 19:30 1.50 DRILL N DPRB PROD1 Bled off pressure and opened up annular preventer. Broke pipe free with 260K to 310K and starting rotating pipe slowly bring up pumps. Rotating pipe weight 190 K slowly increased pumps to a max rate 6.5 bpm at 600 to 800 psi. Circulated 12.5 ppg KW mud to surface. Had small amount of gas to surface with bottoms up. 19:30 - 23:30 4.00 DRILL N DPRB PROD1 Attempt to clean up well -Ream to bottom from 8220 to 8210'/ packing off with 5 bpm - pp 650 to 750 - Con't work to bottom - Back ream from 8257' to 8169' -From 8255 to 8200- packing off ratty -from 8200 to 8169 -hole in fairly good shape -Ream back to bottom -From 8210 to 8255 -packing off very ratty - Back ream from 8255 to 8200' hole packing off -hole conditions deteriorating - 4.5 to 5 bpm max flow rate through that section -Back ream from 8200 to 8169' -Flow check well - Well static - (Tested Hydraulic choke with test pump -would not hold any pressure) - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone / Siltstone) over shakers -Loss 25 bbls mud 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Attempt to pump out with 5 bpm - 720 psi -Packing off at 8160' - Back ream from 8160' to 8130 -Packing off - 5 bpm - 730 psi Printed: 1/30/2007 11:42:40 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 '.Common Well Name: MPF-99 'Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT ~ Phase 112/29/2006 123:30 - 00:00 I 0.501 DRILL I N 112/30/2006 100:00 - 02:30 I 2.501 DRILL I N 02:30 - 03:00 I 0.501 DRILL I N 03:00 - 11:30 8.501 DRILL I N 11:30 - 12:30 I 1.001 DRILL I N 12:30 - 00:00 11.501 DRILL I P DPRB I PROD1 DPRB PROD1 DPRB I PROD1 DPRB I PROD1 DPRB IPRODI PROD1 12/31/2006 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 02:00 1.00 DRILL P PROD1 02:00 - 03:30 1.50 DRILL P PROD1 03:30 - 06:00 2.50 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 13:00 4.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PRODi 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00- 16:30 0.50 DRILL P PROD1 16:30- 17:30 1.00 DRILL N RREP PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 23:30 4.50 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 Page 8 of 15 '~~, Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) over shakers Back ream from 8130 to 7887' -Packing off bad / tight ~ 8015' to 7969 - BPM 5 - PP 750 -RPM 110 - T014K - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) - Loss 21 bbls pump out Circulate -Setting deflexion to zero on Geo-pilot -GPM 411 - PP 1700 -RPM 50 - TO 10K -ECD 13.42 CBU -Reciprocate -Casing load with cuttings -RPM 70 - TO 10K -GPM 411 to 480 - PP 1700 to 2130 - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) shale over shakers (Change out Hydraulic choke) While cleaning up 9 5/8" casing -Add black products for shale stability C~ 9 5/8" casing shoe - (Continue change out hydraulic choke) -GPM 411 to 480 - PP 1700 to 2170 -RPM 70 - TO 10k Wash and ream from casing shoe to bottom f~ 8257' - PUWT 215k -SOW 145k - ROWT 175k -GPM 450 PP 1920 -ROT 120 - TO 15 -ECD 13.09 (hole in good shape) Directional drill 8 1/2" hole f/ 8257' - 8260' (minor pack-off - reduced pump rate, back ream stand, hole cleaned up) WOB 8 - RPM 120 - TO on 15 /off 13K -GPM 400 - PP 1950 on / 1950 off -PUW 215 -SOW 145 - ROTW 175 -ECD 13.26 - Con't Directional Drill 8 1/2" hole f/ 8260' to 8575' - WOB 15 / 18-RPM 140-T015Kon-offl3K-GPM 450-PP2210on- 2000 off -PUW 220 -SOW 145 -ROT 175 -ECD 13.36 Directional Drill 8 1/2' hole from 8575' to 8637' -15 WOB - ~ RPM 140-T015Kon/13kKoff-GPM440-PPon 2200/ 2100 off -PUW 220 -SOW 145 - ROTW 175 -ECD 13.4 Circulate and condtion hole to reduce ECD from 13.4 ppg EMW to 13.2 ppg EMW. - 445 GPM C~ 1900 psi Directional Drill 8 1/2" hole from 8637' to 8670' - TD - 15 WOB -RPM 140-TO on 16/off 14-GPM440-PP2190 on/2040 off -PUW 220 -SOW 145 - ROTW 179 -ECD 13.2 CBU - 3X. 450 GPM ~ 2000 psi - 150 RPM - 15K TO - 13.05 Pump out to shoe ~ drlg rate CBU C~J shoe -GPM 470 - PP 2200 -RPM 100 - TO 10K Flow check -Well Static Pump dry job - POH from 7880' to 810' Stand back HWDP -Jars - LD Flex DC's -Float sub Down load MW D -Service Geo-pilot LD - TM, MWD, DM, Geo-pilot, Bit Clear rig floor of vendors tools Repair Iron roughneck -Change out top jaw PU Reaming BHA - 9 1/2" Rhino reamer - Bakerlok / bullnose - Circ sub - 1 HW DP - Stabailzer - 6 HW DP-Jars - 14 HWDP RIH from 687' to 7954 -Filling pipe every 25 stands -RIH to 7974' -Bring up pump to 254 gpm 1200 psi -Open blades - Pick up to locate casing shoe - PU 215 -SOW 145 - ROTW 175 Attempt to rotate -Stalling out at 25K -Shut down pump - Work string -Bring pump back on line - Re-start procedure locating bottom of shoe -Start reaming from 7955' to 8000 ' - Printed: 1/30/2007 17:42:40 AM • BP AMERICA Page 9 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours ! Task Code NPT Phase Description of Operations ~~ 12/31/2006 23:30 - 00:00 0.50 DRILL P PROD1 GPM 450 -PP 2060 -RPM 100 - TO 13K 1/1/2007 00:00 - 00:30 0.50 DRILL P PROD1 Ream from 8000 to 8053' - 6% flow increase -Pit gain of 3 bbls on bottoms up -Work string back up to shoe -Tight overpul- of 100K -packing off -Shut down pump -Work string up to shoe with out pump 00:30 - 01:00 0.50 DRILL P PROD1 Flow check /well flow 2 bbl gain -Shut in well - (More then likely DP air from fill ups) Monitor well 25 mins - No DPP - NO SICP -Open Annular -Well static -Circulate 2200 stks air out of mud 01:00 - 20:30 19.50 DRILL P PROD1 Ream hole from 7979' to 8670' - WOB 2 K -RPM 100 to 130 - TO 13K -GPM 450 - PP 2000 to 2135 (Reaming 45' to 55' fUhr) -Torque or stall depths 8114, 8218, 8264, 8378, 8431, 8455, 8467, 8518, 8532, 8567, 8596 -Increase weight on reamer to 5 to 8K - 8383, 8410, 8419 to 8421', 8467, 8518, 8532, 8596, 8655 -Back ream each stand from 8426' to TD 8670' 20:30 - 22:30 2.00 DRILL P PROD1 CBU 3 X -RPM 130 - TO 10K -GPM 450 - PP 2060 -PUW 200 -SOW 150 - ROTW 175 -Reciprocate string 75' strokes 22:30 - 23:30 1.00 DRILL P PROD1 Pump out from 8670' to 8329' at 450 GPM - PP 1970 -PUW 200 to 215 -Pump out from 8329' to 7990' at 210 GPM - PP 600 -PUW 210 to 220 -Pull from 7990' to 7943'. without pump - PUW 210 to 220 - 7960' PUW 220 - No Pack-off -Hole in good shape 23:30 - 00:00 0.50 DRILL P PRODi CBU - 7943 -GPM 500 - PP 2330 1/2/2007 00:00 - 00:30 0.50 DRILL P PROD1 Con't CBU -GPM 500 - PP 2350 ~ 7944' 00:30 - 01:00 0.50 DRILL P PROD1 Pull 3 stands watch for swab - No Swab observed -RIH 01:00 - 02:30 1.50 DRILL P PROD1 Drop ball to open circ sub -CBU 2 X -GPM 500 - PP 1430 - RPM 120 - TO 6K with rotary -Metal shavings coming back to surface -Shut down rotary -CBU 1 X - Reciprocating string - Shakers clean 02:30 - 03:00 0.50 DRILL P PROD1 Flow check -Well static 03:00 - 06:30 3.50 DRILL P PROD1 Dry job - POH from 7944' to 687' 06:30 - 07:30 1.00 DRILL P PROD1 Stand back HWDP - UD BHA 07:30 - 08:30 1.00 BOPSU P PROD1 Pull wear ring -Install test plug -Test annular to 250 psi low, 2500 psi high for 5 minutes each - R/D -Install wear ring 08:30 - 09:30 1.00 CASE P PROD1 PJSM - R/U to run 7 5/8" liner 09:30 - 12:00 2.50 CASE P PROD1 Run 7 5/8" liner and M/U hanger 12:00 - 13:00 1.00 CASE P PROD1 Install gel seal in packer 13:00 - 20:30 7.50 CASE P PROD1 RIH with 7 5/8" liner on 5" DP from 905' to 7925' (fill pipe every 10 stds, break circulation every 20 stands) 20:30 - 23:00 2.50 CASE P PROD1 Circulate hole clean ~ 7925' (560 psi ~ 5 BPM, PU 210, SO 150) 23:00 - 23:30 0.50 CASE P PROD1 RIH with 7 5/8" liner to 8645' 23:30 - 00:00 0.50 CASE P PROD1 M/U cement head on single drill pipe - M/U to top drive 1/3/2007 00:00 - 03:30 3.50 CASE P PROD1 Circulate hole clean -Stage pump up from 84 GPM to 212 GPM ~ 370 psi to 670 psi -Reciprocate 20' (PU 210, SO 145) 03:30 - 05:00 1.50 CEMT P PROD1 Cement per plan (5 bbls water, Test lines to 4000 psi, 32 bbls 13.5 mud push, 53 bbls 15.8 cement, Drop dart, Displace with rig pump 50 SPM C~3 380 ICP, 680 FCP, slow pump to 1.5 BPM to latch up liner and bump plug ~ 1676 total strokes, Pressure to 2500 psi) -Reciprocate 20' -Cement in place ~ 0500 hours 05:00 - 06:00 1.00 CASE P PROD1 Set hanger and packer per Baker rep -Check floats -Circulate cement above liner lap out of hole (Appr. 5bbls cement back) Printetl: 1/30/2007 11.:42:40 AM r BP AMERICA Page 10 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2007 06:00 - 06:30 0.50 CASE P PROD1 06:30 - 08:00 1.50 CASE P PRODi 08:00 - 09:00 1.00 CASE P PROD1 09:00 - 10:30 1.50 CASE P PROD1 10:30 - 13:30 3.00 CASE P PROD1 13:30 - 14:30 1.00 CASE P PROD1 14:30 - 16:00 1.50 CASE P PROD1 16:00 - 16:30 0.50 BOPSU P PROD1 16:30 - 17:30 1.00 BOPSU P PROD1 17:30 - 22:30 5.00 BOPSU P PROD1 22:30 - 23:00 0.50 BOPSU P PROD1 23:00 - 23:30 0.50 CASE P PROD1 23:30 - 00:00 0.50 CASE P PROD1 1/4/2007 00:00 - 01:00 1.00 CASE P PROD1 01:00 - 01:30 0.50 CASE P PROD1 01:30 - 02:30 1.00 CASE P PROD1 02:30 - 04:00 1.50 CASE P PROD1 04:00 - 05:30 1.50 CASE P PROD1 05:30 - 09:30 4.00 CASE P PROD1 09:30 - 10:00 0.50 CASE P PROD1 10:00 - 11:00 1.00 EVAL P PROD1 11:00 - 13:00 2.00 DRILL P PROD1 13:00 - 14:30 1.50 DRILL P PROD1 14:30 - 17:00 2.50 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 19:30 1.50 DRILL P PROD1 19:30 - 20:30 1.00 DRILL P PRODi 20:30 - 22:30 2.00 DRILL P PROD? 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/5/2007 00:00 - 15:00 15.00 DRILL P PROD1 15:00 - 20:30 5.50 DRILL P PROD1 20:30 - 00:00 I 3.501 DRILL I P I I PROD1 11/6/2007 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 UD cement. head and hoses Pump nut plug sweep and CBU 2X - (560 gpm ~ 1440 psi) - Reciprocate pipe full stand POOH 10 stands to 6825' -Pump dry job Cut and slip drill line -Service top drive POOH from 6825' to 228' POOH UD 6 joints 5" drill pipe and 7.625 packer running tool RIH with 7 stands HWDP and jars from derrick and UD same Pull wear ring and install test plug R/U to test BOPE Test BOP's -Annular 250 low 2500 high -Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Lou Grimaldi with AOGCC waived witness of BOP test -All test were witnessed by WSL Pull test plug -Install wear ring Mobilize drilling BHA to rig floor -Change elevators P/U drilling BHA - M/U MWD, near bit stab, & bit Cont M/U drilling BHA Upload MWD Cont M/U drilling BHA -Surface test MWD (200 gpm @ 1060 psi) P/U 4" HWDP & 4" drill pipe from pipe shed Fill pipe and test MWD 250 GPM ~ 1500 psi -Not getting good detection -Trouble shooting -Aired up mud RIH to 8456' Circulate drill pipe volume (270 GPM ~ 2200 psi) Test casing to 1000 psi for 30 minutes (Good) Drill latch collar, cement, float collar, cement to 8665' (PU 225, SO 140, RW 170, WOB 5-8, 255 GPM, 2020 psi, 80 RPM, 13 TO) Circulate hole clean (255 GPM ~ 2020 psi) Pump 70 bbls treated H2O, 40 bbls high vis sweep -Displace to 10.0 ppg mud (Initial 2300 psi, final 270 gpm ~ 1650 PSI) Drill out shoe and 20' new hole to 8690' (1900 psi ~ 270 GPM, WOB 12, PU 220, SO 160, RW 175, 80 Rpm, 13 TO) Circulate hole clean (1750 psi ~ 290 GPM) R/U -Perform FIT (MD 8670', TVD 6989', MW 10.1 ppg, 872 psi) - EMW = 12.5 ppg (Good test) - R/D Drill from 8690' to 8738' TVD 7014' (PU 215, SO 160, RW 185, WOB 12, 1700 psi, 290 GPM, 80 RPM, 13 TO) ADT= 1.04 hrs Circulate hole clean - R & R (290 GPM, 1700 psi) Check flow (static) -Pull 1 stand into casing Clean pits and prepare for coring fluid Offload oil base mud to pits -Heat oil base mud to 90 degrees using Hot Oil services PJSM -Displace well to 10 ppg oil base mud (pump 100 bbls H2O /soap, 100 bbls high vis 10 ppg spacer, 40 bbls high vis sweep, 520 bbls OBM) (252 GPM ~ 2100 psi) Cont displace w/OBM (PU 225, SO 155, RW 180, 252 GPM, 2100 psi) (Monitoring hole while cleaning pits observed 1 bbl Printed: 1/30/2007 11:42:40 AM • BP AMERICA Page 11 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: From - To Hours Task Code NPT Phase Description of Operations Date _ 1/6/2007 00:00 - 01:30 1.50 DRILL P PROD1 gain over 20 hour period. Had traces of oil with bottoms up.) ~ 01:30 - 02:00 0.50 DRILL P PROD1 Clean out trough, hole fill line -Stand back 1 stand -Observe well 02:00 - 03:00 1.00 DRILL P PROD1 PJSM -Handling core barrel and shuttle practice run 03:00 - 05:30 2.50 DRILL P PROD1 Drill from 8738' to 8786' (PU 225, SO 155, RW 180, RPM 100, / TO 11, 290 GPM, 2750 psi) 05:30 - 06:30 1.00 DRILL P PROD1 CBU - R & R (100 RPM, 290 GPM, 2750 psi) 06:30 - 08:00 1.50 DRILL P PROD1 Pump out of hole from 8786' to 8079' 08:00 - 08:30 0.50 DRILL P PROD1 Clean floor -Observe well -Mobilize coring tools to rig floor 08:30 - 11:00 2.50 DRILL P PROD1 Pump 12 ppg pill -POOH from 8079' to 5240' 11:00 - 12:30 1.50 DRILL P PRODi Review core handling procedures with both crews while changing out Hi-Line breaker 12:30 - 16:30 4.00 DRILL P PROD1 POOH from 5240' to 1628' 16:30 - 20:30 4.00 DRILL P PROD1 C/O elevators & roughneck to handle 4" work string & BHA - POH w/4" DP &HWDP - VD NMDC & stabs 20:30 - 21:00 0.50 DRILL P PROD1 Download MWD 21:00 - 22:00 1.00 DRILL P PROD1 UD MWD, stab, & bit 22:00 - 00:00 2.00 DRILL P PROD1 Clean rig floor (oil base mud) 1/7/2007 00:00 - 00:30 0.50 EVAL P PROD1 Continue clean floor -Mobilize coring tools to floor 00:30 - 03:30 3.00 EVAL P PROD1 PJSM - M/U outer core barrels, 6.75" core bit - P/U & space out inner barrels 03:30 - 06:00 2.50 EVAL P PROD1 P/U DC's &HWDP - M/U core BHA -Surface test BHA (100 GPM ~ 80 psi) 06:00 - 10:00 4.00 EVAL P PROD1 RIH from 1978' to 8588' (fill pipe every 25 stands) 10:00 - 14:00 4.00 EVAL P PROD1 Circulate hole and pit volume mixing tracer into system (180 GPM @ 1060 psi) 14:00 - 16:00 2.00 EVAL P PROD1 M/U space out pups -Wash down to 8786' (PU 205, SO 155, 168 GPM, 910 psi) -Pull up to 8693' -Drop ball -Circulate ball down (psi increase to 1540 psi ~ 150 GPM) ' 16:00 - 00:00 8.00 EVAL P PROD1 Coring from 8786' to 8831' (PU 210, SO 155, RW 180, 1260 ~ psi, 150 GPM, WOB 12/20, TO 6/11) 1/8/2007 00:00 - 02:30 2.50 EVAL P PROD1 Coring to 8831' -Total 45' of core cut -Last 2 1/2 hours no progress, POOH to evaluate (PU 210, SO 155, RW 180, 1260 psi, 150 GPM, WOB 12/20, RPM 60, TO 619) 02:30 - 03:00 0.50 EVAL P PROD1 Pump out of hole 5 stands (25 to 35K overpull up to 7760' or top of liner) 03:00 - 10:00 7.00 EVAL P PROD1 Observe well (static) -Pump dry job -POOH to 1978' 10:00 - 10:30 0.50 EVAL P PROD1 Clean floor - C/O rubbers in mud bucket, and elevators to work 4" work string 10:30 - 14:00 3.50 EVAL P PROD1 POOH with 4" DP, HWDP, DC's 14:00 - 18:00 4.00 EVAL P PROD1 Pull core barrels - Break off bit -Pull inner barrels -Gamma log cores - VD inner cores to pipe shed (Recovered 45' core, bit was not damaged apparently core jammed in inner barrels) 18:00 - 19:00 1.00 EVAL P PROD1 Clean OBM from rig floor 19:00 - 21:00 2.00 EVAL P PROD1 M/U inner core barrels & install in outer barrels - M/U bit & coring BHA 21:00 - 00:00 3.00 EVAL P PROD1 RIH to 7172' (fill pipe every 25 stands) 1/9/2007 00:00 - 00:30 0.50 EVAL P PRODi Cont RIH from 7172' to 7770' 00:30 - 01:30 1.00 EVAL P PROD1 Slip and cut drill line 01:30 - 02:30 1.00 EVAL P PROD1 Service top drive and blocks 02:30 - 03:30 1.00 EVAL P PRODi Space out -RIH from 7770' to 8735' 03:30 - 05:30 2.00 EVAL P PROD1 Wash down to 8828' (tight ~ 8795') -Drop ball and circulate ball down (PU 210, SO 155, RW 180, 100 GPM, 650 psi) Printed: 1/30/2007 11:42:40 AM • BP AMERICA Page 12 of 15 Operations Summary Report ,,Legal Well Name: MPF-99 'Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/9/2007 105:30 - 15:00 I 9.501 EVAL I P I I PROD1 15:00 - 17:00 2.00 EVAL P PROD1 17:00 - 17:30 0.50 EVAL P PROD1 17:30 - 22:00 4.50 EVAL P PROD1 22:00 - 23:00 1.00 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/10/2007 00:00 - 02:00 2.00 EVAL P PROD1 02:00 - 07:00 5.00 EVAL P PROD1 07:00 - 08:30 I 1.501 EVAL I P I I PROD1 08:30 - 12:30 4.00 EVAL P PROD1 12:30 - 13:00 0.50 EVAL P PROD1 13:00 - 14:00 1.00 EVAL P PRODi 14:00 - 17:30 3.50 EVAL P PROD1 17:30 - 18:00 0.50 EVAL P PROD1 18:00 - 20:00 I 2.001 EVAL I P I I PRODi 20:00 - 20:30 0.50 EVAL P PROD1 20:30 - 23:00 2.50 DRILL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/11/2007 00:00 - 02:30 2.50 EVAL P PROD1 02:30 - 04:00 1.50 EVAL P PROD1 04:00 - 06:00 2.00 EVAL P PROD1 06:00 - 09:00 3.00 EVAL P PROD1 09:00 - 10:30 1.50 EVAL P PROD1 10:30 - 11:00 0.50 EVAL P PROD1 11:00 - 12:00 1.00 EVAL P PROD? 12:00 - 13:00 1.00 EVAL P PROD1 13:00 - 17:00 4.00 EVAL P PROD1 17:00 - 19:00 2.00 EVAL P PRODi 19:00 - 22:30 3.50 EVAL P PROD1 22:30 - 00:00 t .50 EVAL P PRODi 1/12/2007 00:00 - 00:30 0.50 EVAL P PROD1 00:30 - 01:30 1.00 EVAL P PRODi 01:30 - 02:30 1.00 EVAL P PROD1 02:30 - 09:00 6.50 EVAL P PROD1 Core from 8831' to 8867' (no progress past 8867') (PU 220, ~ '/ SO 155, RW 180, WOB 15-25, RPM 40/70, TO 5-18, 1240 psi, 150 GPM) Pump out of hole 10 stds Flow check (static) -Pump dry job -Blowdown top drive POOH from 7929' to 1978' C/O elevators & mud bucket rubbers to handle 4" work string - Clean OBM from floor Stand back 11 stands 4" DP & 1 stand 4" HWDP Stand back BHA to core barrels Pull inner core barrels (only 5' of core recovered) -Inspect inner barrels -Pull outer barrels - UD and inspect same - UD bit Clean OBM from rig floor -Service top drive -Discuss options with town M/U cleanout BHA to 250' -Test MWD (good test) Lubricate rig Continue RIH w/ BHA to 2025' - C/O to 5" elevators RIH from 2025' to 8670' (fill every 25 stands) Wash to bottom ~ 8865' (PU 212, SO 155, 1920 psi, 280 GPM) Survey ~ 8865' MD -Pull up to 8809' MD -Survey -Wash to bottom -Mad pass from 8865' to 8721' (PU 212, SO 155, RW 180, RPM 50, TO 12, 1860 psi, 280 GPM) Evaluate logs Drill from 8865' to 8872' MD, 7057' TVD (PU 212, SO 155, RW ~ 180, 100 RPM, TO 9, WOB 13, 1970 psi, 284 GPM) Circulate hole clean - R & R - (100 RPM, TO 10, 2100 psi, 300 GPM) Continue circulate hole clean - R & R (PU 212, SO 155, RW 180, RPM 100, TO 10, GPM 300, 2050 psi) Pump out of hole from 8870' to 7770' Circulate hole clean ~ top of liner w/ 300 gpm 1950 psi - R& R w/ 40 rpm Observe well (static) -Pump dry job -Blowdown top drive - POOH to 2029' Stand back cleanout BHA Download MWD UD MWD, junk basket, bit Clear floor of vendor tools -Clean OBM off floor P/U M/U outer core barrels and stabilizers - M/U inner barrels and space out - M/U bit RIH with core run #3 BHA C/O to 5" elevators -RIH from 1950' to 8653' (fill pipe every 25 stands) Cut and slip drill line -Service top drive -Circulating @ 740 psi, 150 GPM Continue circulate bottoms up (150 GPM ~ 740 psi) Wash from 8653' to 8872' (PU 215, SO 155, RW 180, 740 psi, 150 GPM) Pull up to 8844' - Drop ball -Circulate ball down Coring #3 run from 8872' to 8876' (no progress) (126 gpm 800 psi - WOB 2-17k) Printed: 1/30/2007 11:42:40 AM • BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 ,Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 ~i Rig Name: DOYON 14 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 1/12/2007 09:00 - 11:00 2.00 EVAL P PROD1 11:00 - 15:00 4.00 EVAL P PRODi 15:00 - 17:00 2.00 EVAL P PROD1 17:00 - 20:00 3.00 EVAL P PROD1 20:00 - 20:30 0.50 EVAL P PROD1 20:30 - 00:00 3.50 EVAL P PROD1 1/13/2007 00:00 - 03:00 3.00 EVAL P PROD1 03:00 - 04:30 1.50 EVAL P PROD1 04:30 - 05:00 0.50 EVAL P PROD1 05:00 - 17:00 12.00 DRILL P PROD1 17:00 - 20:00 3.00 DRILL P PRODi 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21:00 0.50 DRILL P PRODi 21:00 - 23:00 2.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 1/14/2007 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 01:30 - 03:00 1.50 DRILL P PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 07:30 1.50 DRILL P PROD1 07:30 - 10:00 2.50 DRILL P PROD1 10:00 - 11:00 1.00 DRILL P PROD1 11:00 - 13:00 2.00 EVAL P PRODi 13:00 - 19:00 6.00 EVAL P PROD1 19:00 - 20:00 1.00 CEMT P PROD1 20:00 - 22:00 2.00 CEMT P PROD1 22:00 - 00:00 2.00 CEMT P PROD1 1/15/2007 00:00 - 00:30 0.50 CEMT P PROD1 00:30 - 01:00 0.50 CEMT P PROD1 01:00 - 01:30 0.50 CEMT P PROD1 01:30 - 03:30 2.00 CEMT P PROD1 03:30 - 04:30 1.00 CEMT P PROD1 04:30 - 05:30 1.00 CEMT P PROD1 05:30 - 07:30 2.00 CEMT P PROD1 07:30 - 14:30 I 7.001 CEMT I P I I PROD1 14:30 - 15:00 I 0.50 EVAL P PROD1 15:00 - 15:30 0.50 EVAL P PROD1 15:30 - 16:30 1.00 EVAL P PRODi Page 13 of 15 Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations Pump out of hole f/ 8876'-7710' w/ 145 gpm, 1000 psi Observe well - POH w/ 5" DP to 1950' Stand back 4" DP, HWT, jars, DC's. PJSM - UD coring assembly #3 (Core catcher was pushed up into core barrel 1 1/2 feet jamming barrel, recovered 5" of cores) Clear and clean rig floor M/U drilling BHA RIH from 2027' to 8637' (fill pipe every 25 stands) CBU (PU 210, SO 155, RW 180, 295 GPM, 2230 psi) Wash to 8876' Drill from 8876' to 9106' (PU 215, SO 155, RW 180, 292 GPM, 2140 psi, 100 RPM, TO 9, WOB 20) CBU 3X - R & R (100 RPM, 300 GPM, 2140 psi) Flow check (static) -Pump out of hole from 9106' to 8670' (300 GPM ~ 2140 psi) Flow check (static) -RIH to 9106' CBU 2X - R & R (300 GPM, 2100 psi, 100 RPM) Pump out of hole from 9106' to 8525' (300 GPM, 2100 psi, PU 210, SO 155) Continue pump out of hole from 8525' to 7692' (300 GPM, 2050 psi) CBU 2X - R & R (300 GPM, 2050 psi, 40 RPM, TO 7) Check flow (static)- Pump dry job -POOH from 7692' to 2027' Stand back 4" DP, HWDP, DC's UD 4 3/4" flex DC's -Download MWD -Flush MWD w/LVT fluid - UD MWD & bit Clear and clean OBM from rig floor Mobilize and R/U SWS wireline Run USIT/CBL logs to 8665' -USIT log failed during operation - Continued w/CBL f/ 8665' to 7745' - R/D SWS Mobilize and R/U to run 3 1/2" tubing PJSM -RIH with 17 joints 3 1/2" IBT tubing and 4" HT-38 drill pipe RIH w/5" drill pipe from 1570' to 7235' (PU 172, SO 140) Cont RIH from 7235' to 8652' Circulate pipe volume ~ 8652' (210 GPM, 700 psi) RIH from 8652' to 9024' -Wash to 9106' (PU 197, SO 155, 256 GPM, 850 psi) Circulate and condition mud -PJSM -Batch up cement PJSM -Pump 10 bbls 12 ppg OBM spacer, Test lines to 2500 psi, Pump 27 bbls 15.8 ppg gas bloc cement, Pump 2.25 bbls 12 ppg OBM spacer, Drop wiper ball, Displace with OBM 1400 strokes with rig (Cement in place ~ 04:30) POOH 10 stands to 8163' Pump nut plug sweeps and circulate hole clean (420 GPM, 1100 psi, 30 bbls contaminated OBM overboard) Circulate ~ 8163' -Wait on cement (155 GPM, 460 psi) - Clean mud pits 3,4 & 5, flush lines, and surface equipment RIH -Tag cement at 8620' MD with 10 K down weight Circulate pipe volume (300 GPM, 1160 psi) R/U test equipment -Test casing to 1200 psi for 30 minutes (good test) - RD test equipment Printed: 1/30/2007 11:42:40 AM • • BP AMERLCA Page 14 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT I Phase Description of Operations .1/15/2007 116:30 - 21:00 I 4.501 EVAL I P I I PROD1 21:00 - 22:00 1.00 EVAL P PROD1 22:00 - 23:00 1.00 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/16/2007 00:00 - 02:30 2.50 TA P ARAN 02:30 - 03:30 1.00 TA P ARAN 03:30 - 06:00 2.50 TA P ABAN 06:00 - 07:00 1.00 TA P ABAN 07:00 - 08:00 1.00 TA P ABAN 08:00 - 11:30 3.50 TA P ABAN 11:30 - 12:30 1.00 TA P ABAN 12:30 - 13:30 1.00 TA P ABAN 13:30 - 14:00 0.50 TA P ARAN 14:00 - 17:00 3.00 TA P ARAN 17:00 - 19:00 2.00 TA P ARAN 19:00 - 20:00 I 1.00 I TA I P I I ABAN 20:00 - 21:00 1.00 TA P ABAN 21:00 - 22:00 1.00 BOPSU P ABAN 22:00 - 22:30 0.50 BOPSU P ARAN 22:30 - 00:00 1.50 TA P ABAN 1/17/2007 00:00 - 01:30 1.50 TA P ARAN 01:30 - 02:30 1.00 TA P ABAN 02:30 - 04:00 1.50 TA P ARAN 04:00 - 04:30 0.50 TA P ARAN 04:30 - 06:30 2.00 BOPSU P ABAN 06:30 - 08:00 1.50 BOPSU P ARAN 08:00 - 09:30 1.50 BOPSU P ARAN 09:30 - 11:00 1.50 TA P ARAN 11:00 - 12:00 1.00 TA P ARAN 12:00 - 14:00 2.00 TA P ABAN 14:00 - 14:30 0.50 TA P ABAN 14:30 - 15:00 0.50 TA P ABAN 15:00 - 17:00 2.00 TA P ARAN PJSM -Circulate while loading pits w/seawater -Displace OBM w/8.5 seawater (pump 20bbls LVT, 80 bbls 10 ppg LSND with safe surf O, 560 bbls sea water, 300 GPM, 990 psi) -Returns did not clean up ,ordered more seawater Turn water on throughout rig -Clean rig floor, drip pan, mud pits of OBM UD 21 jts 5" drill pipe -RIH 7 stds from derrick Continue clean rig and pits of OBM while waiting on seawater Continue cleaning pits, rig floor, and pollution pans of OBM while waiting on clean seawater Pump 30 bbl hi-vis sweep and displace with clean seawater (420 GPM, 1200 psi) Pump dry job - Slowdown top drive -POOH UD 5" drill pipe from 8620' to 6526' Slip & cut drilling line Service rig -Blocks, Top Drive ,Crown, Draw-works Continue UD 5" DP to 1570' Change elevators -Clear floor - UD 4" DP to 522' RIH w/ mule shoe - 3 1/2" tubing - 4 3/4" drill collars - 4" HWDP to 1350' Circulate 120 degree seawater surface to surface / 500 GPM / 970 PSI LD 4" HWDP - 4 3/4" drill collars - 3 1/2" tubing -mule shoe - Clear rig floor PJSM -Change out Saver sub to 4" HT -Clean oil base mud from torque tube -Change out Dies and guide on iron roughneck RU stack washer -Flush out stack w/ hot water /function rams - RD stack washer Pull wear ring -Install test plug PJSM -Change out rams to 2 7/8" x 5" VBR's RU test equipment -Test bonnet door seals to 1500 psi f/ 5 mins. -Record on chart - RD test equip. PJSM - RU tubing equipment -Run 2 7/8" kill string Con't RIH with 2 7/8" Kill string to 2194' MU Head pin -Reverse circ 165 bbls 100 degree seawater RD head pin - MU Tubing hanger -Land tubing ~ 2225' - RILDS -Test from below to 1000 psi for 10 mins LD landing joint - RD tubing equipment -Clear floor of tools and equipment Nipple down BOP's -Riser - Flowline Nipple up Adapter Flange, Tree Test Adapter flange to 5000 psi -Test tree (TWC leaking) - Change hobbit in TWC -Test tree to 5000 psi -Good test -Pull TWC RU Hot Oil truck to pump diesel freeze protect Clear./Clean Rig floor/ cellar -Wait on diesel for freeze protect to arrive from WOA PJSM -Freeze protect tubing - IA -with 156 bbls diesel for Hot Oil - 1.78 bpm - ~ 500 psi U-tube Diesel for 30 mins -Clean pits Install BPV -Test to 1000 psi -Suck lines out - RD hot oil RD lines -Clear cellar area -Secure tree -Rig released ~ Printetl: 1/30/2007 11:42:40 AM • + BP AMERLCA Page 15 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours ~~ Task Code NPT Phase ~ Description of Operations ABAN 17:00 hrs 1 /17/2007 -- 15:00 - 17:00 _ 2.00 I TA - ~ _ P I - - - - PrintOtl: 1/30/2007 11:42:40 AM a ~ ~ a o SARAH PALIN, GOVERNOR ~+~1 oa~ca~7~ ~~ ~`D`~r47 333 W. 7th AVENUE, SUITE 100 C~l~-7.afRQ~~~~ CO1~i15SI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 278-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPF-99 Sundry Number: 307-036 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. c;~„o,.e1., DATED this 30th day of January, 2007 Encl. Chairman ~' ~ ~.~~~ ~EIVED (~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~i ~ ~/~ ~~ ~ ~ ~QQ~ '~ APPLICATION FOR SUNDRY APPROVAL ~ 20 AAC 25.280 ~~~~~~ q~~ ~ Gay COi1S. Commission 1. Type of Request: ^ Abandon ^ Suspend ®Operation Shutdown ^ Perforate ^ Time Extension ~~ 01.8~~' ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 206-156 ~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23332-00-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPF-99 ~ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): r ADL 025509 ~ 44.5 Milne Point Unit / Kuparuk River Sands 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9106 7144 8570 6948 8570 None Casin en th Siz MD TVD Burst Colla se Struct r I Conductor 112' 20" 112' 112' 1490 470 Surface 4892' 13-3/8" 4892' 4607' 4930 2270 In rmedi to Produ ion 7954' 9-5/8" 7954' 6717' 6870 4760 Liner 866' 7-5/8" 7804' - 8670' 6663' - 6989' 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 2-7/8", 6.5# L-80 2225' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ^ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development' ^ Service ® Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 15, 2007 ~ ^ Oil ^ Gas ®Plugged ^ Abandoned 17. Verbal Approval:Date: 1/13/2007 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: om Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Dan Kar Title Senior Drilling Engineer Prepared By Name/Number: ~ Phone ~o~ _~~l Date 1 L7..~ 07 Sondra Stewman, 564-4750 Signature ~ .Commission Use Onl Sundry Number: .. Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~ t~ APPROVED BY /^ ?O ^ O~ J A roved B MMISSIONER THE COMMISSION Date ~• Form 10-403 Revised 06/2006 V v Submit In Duplicate 1 ~ ~ ~I A L ~~~ ~~~ ~ .. ~j ~) ~ soot ~ , z4, /~24~0 • • b p ~,,. ~..~ , January 15t", 2007 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7`" Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Sundry Permit :Temporary Suspension of MPF-99 Mr. Maunder, As I mentioned in our phone conversation Saturday evening, BP intends to temporarily suspend operations on MPF-99 until after the ice-road season (April/May of '07). This was deemed necessary after our third attempt at coring the Kuparuk A-3 interval (one of our primary targets) was unsuccessful. The material that was retained in this last core barrel was believed to be the last ~lh-foot (bottom) of the A-3. Since it was evident that we would not obtain .useable A-3 core, we elected to drill out with a conventional drilling assembly with MWD/GR/RES and log the entire Kuparuk section -eliminating any geologic uncertainty. Upon completion of drilling and logging the section we concluded that the stratigraphy was as expected, and that our coring difficulties were related to equipment issues which could not be remedied in a timely manner. Hence, we made the decision to temporarily suspend operations After receiving your verbal approval on Saturday evening we began planning the suspension. Sunday afternoon we ran a CBL log across the entire 7-5/8" liner, which confirmed good cement. Over the last 12-hours we completed pumping our cement plug, which consisted of 27- bbl of 15.8 ppg Class G cement in a balanced plug. This assumed the 6-3/4" open hole volume from TD at 9106' to our 7-5/8" shoe at 8670' (+20°Io) plus 100' of the 7-5/8" liner. We are currently WOC. As discussed, our plan is to tag TOC and confirm and pressure test to 13.3 ppg EMW. Then, we will displace the well to seawater and run a kill string to 2100' MD and freeze protect with diesel to that depth. The well will be left with a tree and BPV until we return. Thank you for your help over the weekend. If I can provide any additional information, please contact me @ 564-4195. Si rel , Paul Hanson Drilling Engineer BPXA /ACT • • by .;, January 18t", 2007 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7`h Avenue, Suite 100 Anchorage, AK 99501 Re: Notification of Operations Shutdown on MPF-99 Mr. Maunder, We have temporarily shut down operations on MPF-99 due to problems with our coring equipment in the Kuparuk A-3 and A-2 intervals. Our primary objective for this well was to obtain Kuparuk core from an un-swept part of the reservoir in the vicinity of Milne Point F-Pad. Repeated jamming and coring head failures convinced us to suspend operations for ~60 days to allow us to source better, more appropriate equipment. We did not want to jeopardize our ice- pad program with unnecessary delays. After drilling the pilot hole from 8670' to 9106' MD we ran a CBL log across the entire 7-5/8" liner, which confirmed good cement. Then, we pumped a cement plug, which consisted of 27- bbl of 15.8 ppg Class G cement in a balanced pill. This assumed the 6-3/4" open hole volume from TD at 9106' to our 7-5/8" shoe at 8670' (+20%) plus 100' of the 7-5/8" liner. The plug was tagged and tested to 13.3 ppg EMW, which exceeds our FIT of 12.5 ppg, so we are confident that our plug has isolated the Kuparuk interval. MPF-99 was displaced to seawater, and run a kill string installed to 2225' MD and freeze protect with diesel to that depth. The well has left with a tree and BPV installed until we return. We plan to return to MPF-99 in late April or early may to obtain core and finish the well. Thank you for your assistance. If I can provide any additional information, please contact me @ 564- 4195. S' ly, Paul Hanson Drilling Engineer BPXA /ACT i by ~( BP EXPLORATION ~ ~ M P F-99 Temporary Operational Shutdown Field: Milne Point Kuparuk A Sand ENG: P. Hanson Pad: F-Pad Injector RIG: Doyon 14 RKB: 44.5 ft DIR / LWD OH DEPTH HOLE CASING MUD INFO FORM MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 112' 30" Welded, Insul 20" x 11" 5K MWD/GR/PWD None Lead Cement Test Csg to Gyro as needed ~ ~ ~p 585 bbl 200o psi IFR/Cansandra ~~; 10.7 ppg-4.49 ft3/s Base Permafrost 1949' 1850' 2225' Surface Csg u'~~ 13-3/8" s !4~ 68# 150 % Excess TUZC 3,652' 3450' ~ .k-*_; L-80, BTC In Permafrost ,~~"' Int. Yield 5020 psi Collaspse 2260 psi Schrader Bluff-NB 4,205' 3,970' ''r .t Tail Cement aoi° Excess Below ~~~~~~' 124 bbl Permafrost Schrader Bluff-OA 4,334' 4,090' 15.8 ppg-1.17 ft3/s Casing Point 4892' 4,607' 20° 16" MWD/GR/RES None PWD IFR/Cansandra Inter. Casino Cement Slurrv 40% Excess 9-5/8" 165 bbl i ' i 47 Ibs/ft 15.8 ppg L-80, 1.17 ft3/sx TCII /BTC-M Class "G" i Int. Yield 6870 psi Collaspse 4790 psi Top/LNR/ZXP/PBR 7804' 6663' 3F ;~ 66° ~. KLGM 7954' 6717' 12.25" MWD/GR/RES ; Prod Liner Liner Cement eu/Den/Geo Ta TOC 8,570' ~ ~ 7-5/8" , 29.7# 60 bbl, 289 sx W D +/- 270' Cor ~ ~ Liner L-80, HYD 513 Class G, 15.8# 8,670' ~ ~ Point Int. Yield 6890 psi IFR/Cansandra r ~ ; ; Collapse 4790 psi 1.17 ft3/sx NMR TD Pilot 9,106' 7,249' ~ ~ ~ ~ ~ ~ 6-3/4" lug=27 bbl 15.8 pp 1/19/2007 MPF-99 Suspension Schematic.xls BP AMERICA Page 1 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I From - To Hours ~ Task Code'I NPT 12/9/2006 13:00 - 14:00 1.00 MOB P 14:00 - 15:30 1.50 MOB P 15:30 - 16:30 1.00 MOB P 16:30 - 20:00 3.50 MOB P 20:00 - 00:00 4.00 MOB P 12/10/2006 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 12/11/2006 00:00 - 12:00 12.00 MOB P 12:00 - 22:30 10.50 MOB P 22:30 - 23:00 0.50 MOB P 23:00 - 00:00 1.00 MOB P 12/12/2006 00:00 - 02:00 2.00 MOB P 02:00 - 05:00 3.00 MOB P 05:00 - 06:30 I 1.501 RIGU I P 06:30 - 08:00 I 1.501 RIGU I P 08:00 - 15:30 ~ 7.50 ~ RIGU ~ P 15:30 - 22:00 6.50 RIGU P 22:00 - 23:30 1.50 RIGU P 23:30 - 00:00 0.50 DRILL P 12/13/2006 00:00 - 02:30 2.50 DRILL P 02:30 - 03:30 1.00 DRILL P 03:30 - 04:00 0.50 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 07:00 I 1.001 DRILL I P 07:00 - 11:00 1 4.001 DRILL 1 P 11:00 - 12:30 1.50 DRILL N 12:30 - 17:00 4.50 DRILL P 17:00 - 21:30 4.50 DRILL N 21:30 - 00:00 2.50 DRILL P 12/14/2006 100:00 - 16:30 16.501 DRILL P 16:30 - 18:30 I 2.001 DRILL I P 18:30 - 20:30 I 2.001 DRILL I P 20:30 - 21:00 0.50 DRILL P 21:00 - 22:00 1.00 DRILL P Spud Date: 12/13/2006 Start: 12/6/2006 End: 1/10/2007 Rig Release: 1 /17/2007 Rig Number: Phase ~ Description of Operations PRE Skid rig floor PRE Move off well #GNI-02A -Phase 1 conditions PRE Remove cellar doors, heaters, mousehole, and rams PRE Install front and rear boosters -Remove rockwasher landing PRE Move rig off GNI pad on Spine road by PBOC -Phase 1 conditions PRE Move rig from Spine road by PBOC to Spine road and Oxbow PRE Move rig from Spine and Oxbow to across Easf Channel Bridge PRE Move rig from East Kuparuk Bridge to Texaco Pad PRE Move rig from Texaco Pad to F-pad PRE Attempt to turn rig on pad -Call pad maintenance to remove snow berms on edge of pad PRE Remove front boosters and support frame PRE Remove rear boosters and frame PRE Turn rig around -Move down pad -Spot & shim rig over MPF-99 PRE PJSM -Skid rig floor (Rig accepted C~ 0600 hrs due to 2 hr delay waiting on security) PRE Spot & berm rockwasher - R/U mud lines, beaver slide, and rig floor PRE Clear floor - N/U 20" annular, riser, and flowline -Load 153 joints drill pipe and MWD tools in pipeshed -Check and calibrate gas alarms PRE P/U 153 joints of drill pipe from pipeshed and stand in derrick PRE P/U HWDP and jars from pipeshed and stand in derrick SURF Mobilize BHA to floor SURF M/U BHA #1 SURF Upload MWD SURF Fire drill -Evacuation drill -Pre-spud meeting with rig personel and service hands on rig floor SURF Fill hole checking for leaks -Test MW D SURF Drill from 112' to 267' with HWDP (PU 68, SO 68, RW 68, RPM 60, TO 1, 462 gpm, 1100 psi) SURF Stand back 2 stands HWDP - P/U non-mag DC -RIH 1 stand HWDP SURF Drill from 267' to 540' (PU 86, SO 86, RW 86, RPM 60, TO 1, gpm 462, 1100 psi, WOB 25) Close approach issues -Wait on orders from town Drill from 540' to 809' with Gyro surveys (PU 92, SO 94, RW 92, 488 gpm, 1730 psi, RPM 80, TO 2) Ream out dogleg from 701' to 809' Drill from 809' to 999' with Gyro surveys -AST 4.13, ART 2.01, ADT 6.14 (PU 97, SO 95, RW 97, 552 gpm, 1530 psi, RPM 80, TO 2-5, WOB 19-25) SURF Directional Drill from 999' to 2416' 550-650 gpm 1350-1850 psi - WOB 25k -AST 4.79 ART 5.24 ADT 10.03 - PU 130k - SO 110k RW 123k -RPM 80 - TO 4-6k SURF CBU 3X - w/ 650 gpm 2080 psi -Rotate w/ 80 rpm & reciprocate pipe 90' SURF PJSM -Pump out of hole w/full drilling rate to 720' (No problems) SURF RIH from 702' to 2322' -Wash last stand down to 2385' SURF Circulate thick mud out -Stage up to 1120 psi @ 455 GPM Printed: 1/23/21x17 11:04:29 AM DPRB SURF SURF DPRB SURF SURF BP AMERICA Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPF-99 MPF-99 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Date !From - To i Hours Task ,Code NPT i. ---- - - 12/14/2006 122:00 - 00:00 2.00 ~ DRILL ~ N RREP 12/15/2006 00:00 - 02:00 2.00 DRILL N 02:00 - 02:30 0.50 DRILL P 02:30 - 00:00 21.50 DRILL P 12/16/2006 100:00 - 10:30 I 10.501 DRILL I P 10:30 - 13:00 2.501 DRILL P 13:00 - 18:00 I 5.001 DRILL I P 18:00 - 20:00 2.00 DRILL P 20:00 - 00:00 4.00 DRILL P 12/17/2006 00:00 - 04:00 4.00 DRILL P 04:00 - 10:30 6.50 DRILL P 10:30 - 14:00 I 3.501 DRILL I P 14:00 - 16:30 I 2.501 DRILL I P 16:30 - 00:00 7.50 CASE I P 12/18/2006 100:00 - 03:30 I 3.501 CASE I P 03:30 - 05:00 I 1.501 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 10:00 4.00 CASE P 10:00 - 13:00 3.00 CEMT P 13:00 - 15:00 I 2.001 CASE I P RREP Page 2 of 15 Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1/17/2007 Rig Number: Phase Description of Operations SURF #1 conveyor chain jumped sprocket -Trouble shooting conveyor SURF Re-install chain on sprocket - Re-align sprocket on #1 conveyor SURF Wash to 2416' staging pumps up to 650 gpm / 2140 psi SURF Directional drill from 2416' to 4210' (AST = 4.35, ART = 11.14, ADT = 15.49, TST = 13.27, TRT = 18.39, TDT = 31.66, PU 175, SO 128, RW 150, RPM 80, TO on 10, TO off 7, WOB 30, 640 gpm ~ 2480 psi on/ 2160 psi off) SURF Directional drill from 4210' to 4777' (ART = 4.48, AST = 4.48, ADT = 8.69, PU 187, SO 140, RW 160, RPM 160, TO 9, WOB 25) SURF Circulate and condition mud (PU 187, SO 140, RW 160, RPM 80, TO 9, 440 gpm, 740 psi) -Work on #2 mud pump SURF Pump out of hole from 4779' to 720' (424 gpm ~ 1110 psi) - Flow check -Blow down top drive -Working on # 2 mud pump SURF RIH from 720' to 4779' -Wash last stand to bottom SURF Drill from 4779' to 4902' (AST=1.34, ART=1.96, ADT=3.3, TST=19.09, TRT=24.56, TDT=43.65, PU 185, SO 140, RW 160, RPM 80, TO 12 on, TO 9 off, WOB 35, GPM 645, 2500 psi on, 2340 psi off) SURF Circulate and condition ~ 4902' (PU 190, SO 140, RW 160, RPM 100, TO 8, 656 GPM, 2260 psi) SURF Observe well -Pump out of hole stringing "G"seal pill - Continue to pump out w/ 650 gpm 1800 psi to 177' SURF Stand back DC's - LD UBHO -Down load MWD - LD MWD, stab, motor & bit SURF PJSM -Clean/Clear rig floor of BHA - MU Franks fill up tool - Change to long bales - RU casing equipment SURF PJSM -Run 93 joints of 13 3/8" 68# L-80 BTC casing to 3700' - Fill every joint -Break circ. every 10 jts. -Run 25 centralizers on jts #1 to #25 - (PU 340, SO 205, GPM 212, 360 psi) SURF Continue run 13 3/8" L-80 68# casing from 3700' to 4892' (122 joints total) -Break circulation every 10 jts - (210 gpm ~ 360 psi) -Circulate last 2 jts down -Land casing SURF Stage up from 2 bpm to 5 bpm with Frank's running tool - Circulate bottom's up (5 bpm C 340 psi) SURF Rig down Frank's tool -Make up cement head - SURF Circulate & condition mud for cement job SURF PJSM w/ all involved with upcoming operation -Give to Schlumberger -Pump 10 bbls H2O -Test lines to 4000 psi - Pump 20 bbls CW 100 - 100 bbls Mud Push II at 10.6 ppg - Drop bottom plug -Pump lead cement, 585 bbls ASL at i0.7 ppg w/ 5 bpm 300 psi -Stage up to 6.75 bpm 460 psi followed by tail cement, 124 bbls 15.8 ppg class "G" w/ .2% D046 - .3% D065 - .33% D167 - .1 % D013 & .02 gal/sk D110 w/ 4 bpm 375 psi -Stage up to 5 bpm 675 psi -Drop top plug, kick out w/ 10 bbls H2O SURF Displace cement w/ rig pumps - 10 bpm 330 psi -Caught up w/ cement at 400 stks -Slow to 8 bpm 400 psi -Cement to surface at 3600 strokes away -Slow pumps to 5 bpm - Continuedisplacing -Final circ. pressure 1300 psi -Bump plug w/ 2500 psi -Hold 10 min -Check floats - OK - CIP ~ 15:00 hrs -Total cement to surface 320 bbls Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 3 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date 1 From - To Hours Task ~, Code' NPT 12/18/2006 1 15:00 - 17:30 2.50 ~ CASE I P 17:30 - 20:30 3.00 CASE P 20:30 - 22:30 2.00 BOPSU P 22:30 - 00:00 1.50 BOPSU P 12/19/2006 00:00 - 02:00 2.00 BOPSU P 02:00 - 03:30 1.50 BOPSU~ P 03:30 - 07:00 3.50 BOPSU P 08:00 - 08:30 3.50 BOPSUR P 11:30 - 12:30 I 1.001 BOPSUp P 12:30 - 13:30 1.00 CASE P 13:30 - 18:00 4.50 CASE P 18:00 - 21:30 3.50 CASE P 21:30 - 23:00 1.50 CASE P 23:00 - 00:00 1.00 CASE P 12/20/2006 00:00 - 01:00 1.00 CASE P 01:00 - 02:00 1.00 CASE P 02:00 - 04:00 I 2.001 DRILL I P 04:00 - 05:00 1.00 CASE P 05:00 - 09:00 4.00 CASE P 09:00 - 10:00 1.00 EVAL P 10:00 - 11:30 1.50 DRILL N WAIT 11:30 - 00:00 12.50 DRILL P 12/21/2006 100:00 - 09:00 I 9.00 DRILL P 09:00 - 12:30 3.50 DRILL P 12:30 - 13:30 1.00 DRILL P 13:30 - 15:00 1.50 DRILL P Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1/17/2007 Rig Number: Phase Description of Operations SURF R/D cement head -Flush stack - UD landing joint -Clear and clean floor SURF Safety stand down w/ Doyon and service personnel assigned to Rig 14 SURF PJSM - R/D riser, knife valve, annular preventor, and remove from cellar area SURF Install and orient FMC wellhead SURF NU BOP stack, riser, flowline, and install secondary annulus valve on OA -Test metal to metal seal to 1000 psi for 10 minutes with FMC SURF PJSM - MU test joint - R/U test equipment SURF Safety stand down Doyon and service personnel assigned to rig 14 SURF Service rig SURF Test BOPE -Annular to 250 psi low, 2500 high f! 5 min each - Top VBR's -Choke manifold -Choke /Kill HCR -Choke !Kill manual -Upper /Lower IBOP -Floor safety valves -Lower VBR's -Perform accumulator test -Test Blind rams to 250 psi low, 4500 high f/ 5 min. each -Jeff Jones with AOGCC witnessed test -All tests witnessed by WSL SURF RD testing equipment -Install wear ring -Blow down Choke / Kill lines -Choke manifold SURF Install Bails -Elevators - Moblize BHA to rig floor SURF PJSM - MU Geo-Pilot -Bit -MWD - Up load MWD -Float sub - Flex collars -HWDP -Test Geo-Pilot -HWDP -Jars SURF PU 5" DP 1 X 1 SURF Cut drlg line -Service Blocks /Crown /Top Drive SURF Con't RIH from 3923' to 4772' -CBU -GPM 500 - PP 1430 - PU 200 - SO 140 -ROT 165 - SURF Con't CBU SURF RU testing equip -Test casing to 2100 psi for 30 chart recorded minutes -Test good - RD testing equip -Blow down choke /kill lines -choke manifold SURF Tag cement 4798' -Drill cement to 4808' drill plugs and float 4811' -Drill cement shoe to 4892' -Clean out 16" hole to 4902' - Drill 20' new hole to 4922' -GPM 512' - PP 1480 -RPM 100 - TO 10 to 20k -POW 210 - SO 140 -ROT 160 SURF Circulate hole clean -GPM 600 - PP 2005 -RPM 50 - TO 10 SURF Displace to LSND 8.9 ppg -Pump 40 bbls fresh water - 70 bbls Hi-vis spacer -Followed by 690 bbls 8.9 ppg LSND mud SURF RU test equipment -Perform F.I.T. to 12.0 EMW - w/ 8.9 ppg - 750 psi -Shoe TVD = 4606' = 12.0 EMW - 2.8 bbls pumped - .5 bbls back - RD test equip. INT1 Working disposal issues - GNI and 1 R disposal wells down INT1 Directional Drill f/ 4922' to 5540' - WOB 25 to 35 -RPM 100 to 150-TO on 10 to15K-Off14K-GPM650-PPon1890off 1840 -POW 225 -SOW 140 - ROTW 175 -ECD 9.35 INT1 Directional Drill from 5540' to 6110'- WOB 30k -RPM 100 to 150-TO on 10 to 15K-Off 13K-GPM550-PPon 1640 off 1590 -POW 240 -SOW 152 - ROTW 183 -ECD 9.41 INT1 CBU 3x w/ 596 gpm 1850 psi - 120 rpm - 8k tq INTi Pump out of hole f/ 6110' to 4863' w/ 500 gpm 1290 psi INTi CBU at shoe w/ 500 gpm 1290 psi - R&R DP w/ 100 rpm -Flow Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 4 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPL ETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLI NG INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours Task Code '- NPT ~ Phase ~ Description of Operations 12/21/2006 13:30 - 15:00 1.50 DRILL P INT1 check -Dry job 15:00 - 16:30 1.50 DRILL N DFAL INT1 POH f/ 4863' to 801' 16:30 - 20:00 3.50 DRILL N DFAL INT1 Stand back HWDP -Collars -Down load MWD -Clean Geo-pilot -Bit 20:00 - 20:30 0.50 DRILL N DFAL INT1 PJSM -Clear /clean rig floor -Mobilize BHA to rig floor 20:30 - 00:00 3.50 DRILL N DFAL INT1 MU BHA -Bit -Motor -Stabilizer - Mwd -Orient - Up Load MWD -Surface test MWD -HWDP -Jars 12/22/2006 00:00 - 01:00 1.00 DRILL N DFAL INT1 RIH f/ 818' to 13 3/8" casing shoe at 4892' -Fill pipe every 25 stands 01:00 - 03:00 2.00 DRILL P INTi Cont. RIH f! 4892' to 6110' -Fill pipe every 25 stands -Break circ -Wash last stand to bottom, hole in good shape 03:00 - 05:00 2.00 DRILL P INT1 Directional drill f/ 6110' to 6203' - WOB 30 -RPM 80 - TO on 8/11k /off 7k -GPM 610 - PP on 2000 /off 1780 -POW 200k - SOW 175k - ROTW 180k -ECD 9.64 ppg 05:00 - 07:00 2.00 DRILL P INTi Ream hole to reduce DLS -RPM 80 - TO off 6k -GPM 610 - PP 1750 07:00 - 00:00 17.00 DRILL. P INT1 Directional Drill from 6203' to 6933' - WOB 30/38k -RPM 80 - TOon8k/off6k-GPM 610-PPon 1930/off 1700-POW 210k -SOW 174k - ROTW 192k -ECD 9.59 ppg 12/23/2006 00:00 - 06:00 6.00 DRILL P INT1 Directional Drill 12 1/4" hole f/ 6933' to 7805' - WOB 30/43k - RPM 80 - TO on 10k /off 7k -GPM 650 - PP on 2600 psi /off 2400 psi -PUW 212k -SOW 170k - ROTW 190k -ECD 10.38 PP9 12/24/2006 00:00 - 05:00 5.00 DRILL P INT1 Directional Drill 12 1/4" hole f/ 7805' to 7958' (TD 12 1/4" hole) -WOB40to43-RPM80-TOonlO-off?-GPM 655-PPon 2640 -off 2450 -PUW 212 -SOW 170 - ROTW 190 -ECD 10.33 05:00 - 08:30 3.50 CASE P INT1 Circulate hole clean -GPM 650 - PP 2400 - PP 2350 -RPM 80 - TO 8K -Mud wt. 10.1 ppg -ECD 10.28 ppg -Flow check - Well static 08:30 - 11:30 3.00 CASE P INT1 Pump out to 13 3/8' shoe w/full drlg rate -Observed 40k over pull at 5390' -Ream &Backream to clean up - OK 11:30 - 12:30 1.00 CASE P INT1 CBU at 13 3/8" shoe (4892') -Rotate & reciprocate - 614 gpm, 1970 psi - 60 rpm- TO 3K 12:30 - 14:00 1.50 CASE P INT1 Observe well -Well static -Cut drilling line -Service rig 14:00 - 15:30 1.50 CASE P INT1 RIH f/ 4880' to 6870' -Hit tight spot ~ 6870' - (No issues at 5390') 15:30 - 20:00 4.50 CASE N DPRB INT1 Ream &Backream from 6870' to 7958' -GPM 525 - PP 1600 - RPM 80 - TO 8K - Clean up hole 20:00 - 21:30 1.50 CASE P INT1 CBU 1.5 X -GPM 650 - PP 2430 -RPM 80 - TO 7K -ECD 10.35 21:30 - 23:00 1.50 CASE P INT1 Flow check -Well static -Pump out from 7958' to 6455' -GPM 487 -Slight pack-off depths - 7743, 7640, 7441, 7345, 6946, 6930, 6911, 6820, 6611 23:00 - 00:00 1.00 CASE P INT1 RIH from 6455' to 6926' -Hit tight spot -Set down 15K -Work down to 40K would not pass 6926' -Ream through tight spot from 6910' to 6964' - PU to 6910 -Run through section without pump - No tight area observed - Con't RIH from 6964' to 7958' - No problem areas noted 12/25/2006 00:00 - 03:00 3.00 CASE P INT1 CBU 2 X -GPM 600 - PP 2130 -RPM 80 - TO 12 to 8 -ECD 10.23 03:00 - 05:30 2.50 CASE P INT1 Pump out from 7958' to shoe C~ 4880' - 35K overpull C~ 5390' - Ream down no issues -Pull through with out pump 30 over - Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 5 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 i ~ i Date From - To I Hours Task Code; 12/25/2006 ~ 03:00 - 05:30 ~ 2.501 CASE P Start: 12/6/2006 Rig Release: 1/17/2007 Rig Number: Spud Date: 12/13/2006 End: 1 /10/2007 05:30 - 07:00 I 1.501 CASE I P I I INT1 07:00 - 09:00 2.00 CASE P INT1 09:00 - 10:30 1.50 CASE P INT1 10:30 - 13:00 2.50 CASE P INT1 13:00 - 14:00 1.00 CASE P INT1 14:00 - 15:30 1.50 CASE P INT1 15:30 - 19:30 4.00 CASE P INTi 19:30 - 20:00 0.50 CASE P INTi 20:00 - 21:30 1.50 CASE P INT1 21:30 - 22:00 0.50 CASE P INT1 22:00 - 00:00 2.00 CASE P INT1 12/26/2006 00:00 - 03:00 3.00 CASE P INT1 03:00 - 04:00 1.00 CASE P INT1 04:00 - 10:00 6.00 CASE P INT1 10:00 - 14:30 I 4.501 CASE I P I I INTi 14:30 - 16:30 I 2.001 CEMT I P I I INT1 16:30 - 18:00 1.501 CEMT P INT1 18:00 - 20:00 I 2.001 CASE f P I I tNTi 20:00 - 21:00 I 1.001 CASE I P I I INT1 21:00 - 00:00 I 3.001 CASE I P I I INT1 12/27/2006 00:00 - 01:30 1.50 CASE P INT1 01:30 - 03:00 1.50 CASE P INT1 03:00 - 03:30 0.50 CASE P INT1 03:30 - 05:00 1.50 CASE P INT1 05:00 - 06:00 1.00 CASE P INT1 06:00 - 06:30 0.50 CASE P INT1 06:30 - 07:00 I 0.501 CASE I P I I INT1 Description of Operations RIH with out pump -good - (no packing off) -Hole in good shape Flow check at shoe - CBU w/ 600 gpm 1850 psi - R&R DP 60 rpm, 5k torque POH to BHA Stand back HWT. - LD 8" DC's Down load MWD - LD MWD, motor & bit Clear /Clean rig floor -Pull wear ring -Install test plug Change upper rams to 9 5/8" casing rams.- Test door seals to 1500 psi PJSM - RU 9 5/8" casing equipment -PJSM Running casing PJSM - PU float equipment -Check floats PU /Run 9 5/8" BTC-M 47# L-80 casing to 1455' Rig up Torque turn equipment - (Circ casing volume) Con't PU /Run 9 5/8" TC11 47# L-80 casing to 2917' PU /Run 9 5/8" TC11 47# L-80 Casing from 2917' to 4850' Circ casing volume -BPM 8 - PP 560 Con't Run 9 5/8" casing from 4850 to 7905' -Tight Ca? 6338 - Work string 4 X -Tight C~3 7061' -work pipe 3 X Break Circulation -Stage up pump from 2 1/2 bpm to 6 1/2 bpm -Wash from 7905' to 7954' - PP from 450 to 300 - PU 430 - SO 250 -Circulate 1.5 casing volume - LD Franks tool - MU Shclumberger cement head /lines -Circulate one bottoms up -Give to Schlumberger Pump 10 bbls water - 3.5 bpm G 275 psi Test lines to 4000 Pump 20 bbls CW-100 - 3.5 bpm @ 275 Pump 70 bbls Mud Push mixed at 12 ppg - 4 bpm ~ 250 Drop bottom plug Mix and pump 165 bbls 792 sxs -Yield 1.17 -Class "G" mixed at 15.8 ppg - 4 C~ 200 Drop top plug Pump 10 bbls water - 2.5 @ 150 Give to rig Displace with 567 bbls of 10.1 ppg mud - 6.5 bpm C~ 220 - Final pump rate 3 bpm @ 600 psi -Bump plug with 1600 psi - Hold for 10 mins record on chart -Bleed off pressure -Floats holding - CIP 17:50 hrs -Reciprocate string PU 400 to 480 - SO 265 to 235 RD Cement head -Clear rig floor -Void casing -Flush stack / tubing head /well head ND choke -Flow line -Stack -Raise stack for setting slips and cut off Set emergency slips with PUW 375K -Cut casing - LD cut jt - Length cut 23.40' Install 9 5/8" Pack-off - RILDS Change out tubing spools Test pack-off to 3800 psi for 15 mins -Test good NU BOP's -Install secondary valve on tubing spool Change 9 5/8" csing rams to 4 1/2" x 7" VBR's Bullhead 30 bbls mud down OA - 2 BPM -PSI 900 ICP - 750 FC P RU to test BOP's NPT ~ Phase INT1 Printed: 1/23/2007 11:04:29 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date From - To I' Hours Task ~ Code - --- 12/27/2006 07:00 - 10:30 ~ 3.50 CASE P 10:30 - 11:00 I 0.50 I CASE I P 11:00 - 11:30 0.501 CASE ~ P 11:30 - 12:00 0.50 CASE P 12:00 - 13:00 1.00 CASE P 13:00 - 16:30 3.50 CASE P 16:30 - 19:30 I 3.00 I CASE I P 19:30 - 21:00 1.50 CASE P 21:00 - 22:00 1.00 CASE P 22:00 - 22:30 0.50 CASE P 22:30 - 00:00 1.50 EVAL P 12/28/2006 100:00 - 01:00 I 1.001 EVAL I P 01:00 - 03:30 I 2.501 DRILL I P 03:30 - 05:00 1.50 CASE P 05:00 - 06:30 1.50 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 08:30 1.00 DRILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 14:00 I 4.501 DRILL I P 14:00 - 19:00 I 5.00 I DRILL I N Page 6 of 15 Spud Date: 12/13/2006 Start: 12/6/2006 End: 1 /10/2007 Rig Release: 1/17/2007 Rig Number: ( NPT Phase ! Description of Operations INT1 Test BOP's -Annular 250 low 2500 high - Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Jeff Jones waived witness of BOP test -All test were witnessed by WSL - INT1 RD testing equipment -Shut annulus valve -Pull test plug - Install wear ring INTi Bullhead 30 bbls mud down OA - 2 BPM -PSI 1060 ICP 750 psi FCP INT1 Install bails and elevators. INT1 RU floor, mobilize BHA, hold PJSM INT1 PJSM - MU Geo-Pilot -Bit - MW D - Up load MW D -Float sub - Flex collars - HW DP -Surface test MW D -Jars - HW DP INT1 RIH from 804' to 7414' Fill pipe every 25 stands -Function test Geo-pilot INT1 Cut Drlg line -Rig service -Blocks -Crown -Top Drive INT1 RIH from 7414' to 7696' -Function Geo-pilot seals -Wash down from 7696 to 7853 tag cement INT1 RU testing equipment - RU line from test pump INT1 Test casing to 4000 psi with rig pump - Con't test with test pump to 4500 psi - INT1 Test 9 5/8" casing - RD testing equipment -Blow down choke and kill INT1 Drill cement on top of float collar -Shoe track to 7953' - WOB 5 to 10-RPM 50-T018to 22-GPM420-PP1400 INT1 CBU -GPM 432 - PP 1358 -RPM 50 - TO 15K INT1 Displace with new 10 ppg LSND mud INT1 Drill shoe @ 7953 -New hole to 7980' - WOB 5 to 10 - INT1 CBU PROD1 Preform FIT - MD 7954 - TVD 6719 - 10 ppg - 1400 PSI = EMW 14 PROD1 Directional Drill from 7980 to 8257' - WOB 10 -RPM 140 - TO 15 to 20 on-15 off-GPM450-PP1950 on-1940off-PUW 242 -SOW 140 - ROTW 175 - ECD 10.97 DPRB PROD1 Flow increase -Shut in well - DP 20 - Casg 50 - 10 bbl gain - Montior well /filling gas buster with mud -Notified AOGCC (Chuck Scheve) -Milne PT Well operations supervisor (John Cubbon) -Dan Kara Senior Engineer (Anchorage) -Attempt to circulate influx out using drillers method holding 420 psi on DP - 0 pressure on casg - (SPR 30 Stks 280 psi) - DP pressure varied between 420 to 1200 due to packing off -Shut well in with hydraulic choke -work string through annular 285K up 100K down - String appeared to be free -Bring pump on pressure oaring 600 to 920 psi - By-pass Geo-pilot manifold - Pumped total of 1400 stks pit gain 10 bbls -Shut in well with hydraulic choke - DP 20 pressure 150 casing -Gained additional 10 bbls for 31 total -Shut manual valve in front of Hydralic choke - DP pressure 450 psi -Casing 470 -Bring on pump holding casing constant to equivalent mud weight of 12.5 ppg = 1230 DP - 960 casing perssure -Circulate influx out holding 1230 psi on DP -Casing pressure decreased 960 to 740 -Shut down pump bleed off casing pressure to 20 psi - Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 7 of 15 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date I; Name: ell Name: e: Name: From - To MPF-99 MPF-99 DRILL+C DOYON DOYON Hours OMPLE DRILLIN 14 Task TE G INC Code ~I . NPT 12/28/2006 14:00 - 19:00 5.00 DRILL N DPRB 19:00 - 00:00 5.00 DRILL N DPRB 12/29/2006 00:00 - 15:00 15.00 DRILL N DPRB 15:00 - 16:00 1.00 DRILL N DPRB 16:00 - 18:00 2.00 DRILL N DPRB 18:00 - 19:30 1.50 DRILL N DPRB 19:30 - 23:30 4.00 DRILL N DPRB 23:30 - 00:00 0.50 DRILL N DPRB Spud Date: 12/13/2006 Start: 12/6/2006 End: 1/10/2007 Rig Release: 1/17/2007 Rig Number: Phase Description of Operations PROD1 Shut well in with manual valve -Let stablize for 25 mins DP pressure 670 -Casing 520 psi PROD1 Circulate hole using drillers method holding 1100 psi on DP - Casing 660 psi -Order 12.5 ppg kill mud PRODi Circulate holding 1080 psi on DP 670 on casing at 30 spm- Waiting on kill mud PROD1 Started displacing hole with 12.5 ppg mud using the Driller's Method. Held casing pressure constant at 670 psi and pumped 12.5 ppg kill mud down the drillpipe at 30 spm. Initial circulating drillpipe pressure 1080 psi decreased to 340 psi as kill mud exited the bit with 1470 strokes pumped. Switch to drillpipe and held drillpipe pressure gauge constant at 340 psi while circulating kill mud up the annulus. At 1900 strokes (50 bbls of kill mud in annulus) well started packing off. Well was completely packed off at 2000 strokes pumped (DP 1120 psi - casing 470 psi). Attempted to work pipe through annular preventor to break pack off with no success. PU 320K SO 100K. PROD1 Bled pressure off of well. Open annular preventer. Worked pipe free with rotation at 50 RPM at 18K torque. Slowly brought up pump to 30 spm at 310 psi. Pumped 14 bbls of mud total with 1 bbl gain. Shut down pump and closed well back in with annular peeventer. Attempted to resume circulating schedule. Drill pipe immediately packed off and DP pressure increase to 600 psi with slow bleed off. Bled off pressure and and opened annular began working pipe. RPM 80 TO 15-20K- Broke circulation at 1.5 bpm and increased to 3.0 bpm. Pumped a total of 34 bbls and gained 2 bbls of mud in pits. Shut down rotary and pump and closed in well with annular preventer. Attempted to resume pumping schedule and drill pipe instantly packed off with 900 psi on drill pipe. Bled off drill pipe pressure. Monitored well and DP pressure increase to 40 psi -casing 170 j psi. PROD1 Bled off pressure and opened up annular preventer. Broke pipe free with 260K to 310K and starting rotating pipe slowly bring up pumps. Rotating pipe weight 190 K slowly increased pumps to a max rate 6.5 bpm at 600 to 800 psi. Circulated 12.5 ppg KW mud to surface. Had small amount of gas to surface with bottoms up. PROD1 Attempt to clean up well -Ream to bottom from 8220 to 8210' packing off with 5 bpm - pp 650 to 750 - Con't work to bottom - Back ream from 8257' to 8169' -From 8255 to 8200- packing off ratty -from 8200 to 8169 -hole in fairly good shape -Ream back to bottom -From 8210 to 8255 -packing off very ratty - Back ream from 8255 to 8200' hole packing off -hole conditions deteriorating - 4.5 to 5 bpm max flow rate through that section -Back ream from 8200 to 8169' -Flow check well - Well static - (Tested Hydraulic choke with test pump -would not hold any pressure) - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone / Siltstone) over shakers -Loss 25 bbls mud PROD1 Attempt to pump out with 5 bpm - 720 psi -Packing off at 8160' - Back ream from 8160' to 8130 -Packing off - 5 bpm - 730 psi Printed: 1/23/2007 11:04:29 AM BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 From - To 12/29/2006 123:30 - 00:00 12/30/2006 00:00 - 02:30 02:30 - 03:00 03:00 - 11:30 11:30 - 12:30 MPF-99 MPF-99 DRILL+COMPLETE Start: 12/6/2006 DOYON DRILLING INC. Rig Release: 1/17/2007 DOYON 14 Rig Number: Hours I Task I Code I NPT I Phase 0.50 DRILL N 2.50 DRILL N 0.50 DRILL N 8.50 DRILL N DPRBPRODI DPRBPROD7 DPRBIPRODI DPRB IPRODI 1.001 DRILL I N 12:30 - 00:00 I 11.501 DRILL I P DPRB PROD1 PROD1 12/31/2006 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 02:00 1.00 DRILL P PRODi 02:00 - 03:30 1.50 DRILL P PROD1 03:30 - 06:00 2.50 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 13:00 4.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 16:30 0.50 DRILL P PROD1 16:30 - 17:30 1.00 DRILL N RREP PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 23:30 I 4.501 DRILL I P 23:30 - 00:00 I 0.501 DRILL I P PROD1 PROD1 Page 8 of 15 Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) over shakers Back ream from 8130 to 7887' -Packing off bad / tight ~ 8015' to 7969 - BPM 5 - PP 750 -RPM 110 - T014K - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) - Loss 21 bbls pump out Circulate -Setting deflexion to zero on Geo-pilot -GPM 411 - PP 1700 -RPM 50 - TO 10K -ECD 13.42 CBU -Reciprocate -Casing load with cuttings -RPM 70 - TO 10K -GPM 411 to 480 - PP 1700 to 2130 - 65% Clay 35% shale (consisting of 20% Shale 15% Sandstone /Siltstone) shale over shakers (Change out Hydraulic choke) While cleaning up 9 5/8" casing -Add black products for shale stability ~ 9 5/8" casing shoe - (Continue change out hydraulic choke) -GPM 411 to 480 - PP 1700 to 2170 -RPM 70 - TO 10k Wash and ream from casing shoe to bottom ~ 8257' - PUWT 215k -SOW 145k - ROWT 175k -GPM 450 PP 1920 -ROT 120 - TO 15 -ECD 13.09 (hole in good shape) Directional drill 8 1/2" hole f/ 8257' - 8260' (minor pack-off - reduced pump rate, back ream stand, hole cleaned up) WOB 8 -RPM 120-TO on 15/off 13K-GPM400-PP 1950 on/ 1950 off -PUW 215 -SOW 145 - ROTW 175 -ECD 13.26 - Con't Directional Drill 8 1/2" hole f/ 8260' to 8575' - WOB 15 / 18-RPM 140-T015Kon-off 13K-GPM 450-PP2210on- 2000 off -PUW 220 -SOW 145 -ROT 175 -ECD 13.36 Directional Drill 8 1/2' hole from 8575' to 8637 ' -15 WOB - RPM 140-TO 15Kon/13kKoff-GPM440-PPon2200/ 2100 off -PUW 220 -SOW 145 - ROTW 175 -ECD 13.4 Circulate and condtion hole to reduce ECD from 13.4 ppg EMW to 13.2 ppg EMW. - 445 GPM @ 1900 psi Directional Drill 8 1/2" hole from 8637' to 8670' - TD - 15 WOB -RPM140-TOon16/off 14-GPM440-PP2190 on/2040 off -PUW 220 -SOW 145 - ROTW 179 -ECD 13.2 CBU - 3X. 450 GPM @ 2000 psi - 150 RPM - 15K TO - 13.05 Pump out to shoe ~ drlg rate CBU @ shoe -GPM 470 - PP 2200 -RPM 100 - TO 10K Flow check -Well Static Pump dry job - POH from 7880' to 810' Stand back HWDP -Jars - LD Flex DC's -Float sub Down load MWD -Service Geo-pilot LD - TM, MWD, DM, Geo-pilot, Bit Clear rig floor of vendors tools Repair Iron roughneck -Change out top jaw PU Reaming BHA - 9 1/2" Rhino reamer - Bakerlok ! bullnose - Circ sub - 1 HWDP - Stabailzer - 6 HWDP -Jars - 14 HWDP RIH from 687' to 7954 -Filling pipe every 25 stands - RIH to 7974' -Bring up pump to 254 gpm 1200 psi -Open blades - Pick up to locate casing shoe - PU 215 -SOW 145 - ROTW 175 Attempt to rotate -Stalling out at 25K -Shut down pump - Work string -Bring pump back on line - Re-start procedure locating bottom of shoe -Start reaming from 7955' to 8000' - Printed: 1/23/2007 11:04:29 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task ~ Code NPT ~ Phase 12/31/2006 23:30 - 00:00 0.50 DRILL P PROD1 1/1/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:00 I 0.501 DRILL I P I I PROD1 01:00 - 20:30 I 19.501 DRILL I P I I PROD1 20:30 - 22:30 I 2.001 DRILL I P I I PROD1 22:30 - 23:30 I 1.001 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/2/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:00 0.50 DRILL P PROD1 01:00 - 02:30 1.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 06:30 3.50 DRILL P PROD1 06:30 - 07:30 1.00 DRILL P PROD1 07:30 - 08:30 1.00 BOPSU P PROD1 08:30 - 09:30 1.00 CASE P PROD1 09:30 - 12:00 2.50 CASE P PRODi 12:00 - 13:00 1.00 CASE P PROD1 13:00 - 20:30 7.50 CASE P PROD1 20:30 - 23:00 I 2.501 CASE I P I I PROD1 23:00 - 23:30 0.50 CASE P PROD1 23:30 - 00:00 0.50 CASE P PRODi 1/3/2007 00:00 - 03:30 3.50 CASE P PROD1 03:30 - 05:00 I 1.501 CEMT I P I I PROD1 05:00 - 06:00 ~ 1.00 ~ CASE ~ P ~ ~ PROD1 Page 9 of 15 Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations GPM 450 -PP 2060 -RPM 100 - TO 13K Ream from 8000 to 8053' - 6% flow increase -Pit gain of 3 bbls on bottoms up -Work string back up to shoe -Tight overpull of 100K -packing off -Shut down pump -Work string up to shoe with out pump Flow check /well flow 2 bbl gain -Shut in well - (More then likely DP air from fill ups) Monitor well 25 mins - No DPP - NO SICP -Open Annular -Well static -Circulate 2200 stks air out of mud Ream hole from 7979' to 8670' - WOB 2 K -RPM 100 to 130 - TO 13K -GPM 450 - PP 2000 to 2135 (Reaming 45' to 55' fUhr) -Torque or stall depths 8114, 8218, 8264, 8378, 8431, 8455, 8467, 8518, 8532, 8567, 8596 -Increase weight on reamer to 5 to 8K - 8383, 8410, 8419 to 8421', 8467, 8518, 8532, 8596, 8655 -Back ream each stand from 8426' to TD 8670' CBU 3 X -RPM 130 - TO 10K -GPM 450 - PP 2060 -PUW 200 -SOW 150 - ROTW 175 -Reciprocate string 75' strokes Pump out from 8670' to 8329' at 450 GPM - PP 1970 -PUW 200 to 215 -Pump out from 8329' to 7990' at 210 GPM - PP 600 -PUW 210 to 220 -Pull from 7990' to 7943' without pump - PUW 210 to 220 - 7960' PUW 220 - No Pack-off -Hole in good shape CBU - 7943 -GPM 500 - PP 2330 Con't CBU -GPM 500 - PP 2350 ~ 7944' Pull 3 stands watch for swab - No Swab observed -RIH Drop ball to open circ sub -CBU 2 X -GPM 500 - PP 1430 - RPM 120 - TO 6K with rotary -Metal shavings coming back to surface -Shut down rotary -CBU 1 X - Reciprocating string - Shakers clean Flow check -Well static Dry job - POH from 7944' to 687' Stand back HWDP - UD BHA Pull wear ring -Install test plug -Test annular to 250 psi low, 2500 psi high for 5 minutes each - R/D -Install wear ring PJSM - R/U to run 7 5/8" liner Run 7 5/8" liner and M/U hanger Install gel seal in packer RIH with 7 5/8" liner on 5" DP from 905' to 7925' (fill pipe every 10 stds, break circulation every 20 stands) Circulate hole clean @ 7925' (560 psi C~ 5 BPM, PU 210, SO 150) RIH with 7 5/8" liner to 8645' M/U cement head on single drill pipe - M/U to top drive Circulate hole clean -Stage pump up from 84 GPM to 212 GPM ~ 370 psi to 670 psi -Reciprocate 20' (PU 210, SO 145) Cement per plan (5 bbls water, Test lines to 4000 psi, 32 bbls 13.5 mud push, 53 bbls 15.8 cement, Drop dart, Displace with rig pump 50 SPM ~ 380 ICP, 680 FCP, slow pump to 1.5 BPM to latch up liner and bump plug @ 1676 total strokes, Pressure to 2500 psi) -Reciprocate 20' -Cement in place @ 0500 hours Set hanger and packer per Baker rep -Check floats -Circulate cement above liner lap out of hole (Appr. 5bbls cement back) Printed: 1/23/2007 11:04:29 AM BP AMERICA Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Event Name: DRILL+COMPLETE Start: 12/6/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date 1 /3/2007 From - To ; Hours I Task j Code NPT Phase I ~ 06:00 - 06:30 0.50 CASE P PROD 06:30 - 08:00 1.50 CASE P PROD 08:00 - 09:00 1.00 CASE P PROD 09:00 - 10:30 1.50 CASE P PROD 10:30 - 13:30 3.00 CASE P PROD 13:30 - 14:30 1.00 CASE P PROD 14:30 - 16:00 1.50 CASE P PROD 16:00 - 16:30 0.50 BOPSU P PROD 16:30 - 17:30 1.00 BOPSU P PROD 17:30 - 22:30 5.00 BOPSU P PROD 22:30 - 23:00 0.50 BOPSU P PROD 23:00 - 23:30 0.50 CASE P PROD 23:30 - 00:00 0.50 CASE P PROD 1/4/2007 00:00 - 01:00 1.00 CASE P PROD 01:00 - 01:30 0.50 CASE P PROD 01:30 -02:30 1.00 CASE P PROD 02:30 - 04:00 1.50 CASE P PROD 04:00 - 05:30 1.50 CASE P PROD 05:30 - 09:30 4.00 CASE P PROD 09:30 - 10:00 0.50 CASE P PROD 10:00 - 11:00 1.00 EVAL P PROD 11:00 - 13:00 2.00 DRILL P PROD 13:00 - 14:30 1.50 DRILL P PROD 14:30 - 17:00 2.50 DRILL P PROD 17:00 - 18:00 I 1.001 DRILL I P I I PROD 18:00 - 19:30 1.50 DRILL P PROD 19:30 - 20:30 1.00 DRILL P PROD 20:30 - 22:30 I 2.001 DRILL I P I I PROD 22:30 - 23:30 1.00 DRILL P PROD 23:30 - 00:00 0.50 DRILL P PROD 1/5/2007 00:00 - 15:00 15.00 DRILL P PROD 15:00 - 20:30 5.50 DRILL P PROD 20:30 - 00:00 I 3.501 DRILL I P 1/6/2007 100:00 - 01:30 I 1.501 DRILL I P PROD PROD Page 10 of 15 Spud Date: 12/13/2006 End: 1 /10/2007 Description of Operations 1 UD cement head and hoses 1 Pump nut plug sweep and CBU 2X - (560 gpm @ 1440 psi) - Reciprocate pipe full stand 1 POOH 10 stands to 6825' -Pump dry job 1 Cut and slip drill line -Service top drive 1 POOH from 6825' to 228' 1 POOH UD 6 joints 5" drill pipe and 7.625 packer running tool 1 RIH with 7 stands HWDP and jars from derrick and UD same 1 Pull wear ring and install test plug 1 R/U to test BOPE 1 Test BOP's -Annular 250 low 2500 high -Top VBR's -Choke manifold - HCR Choke /Kill -Manual Choke /Kill -Upper / Lower IBOP -Floor safety valves -Bottom VBR's -250 low 4500 high -Perform Accumulator test -Test Blind Rams 250 low 4500 high - 5 mins each test -Lou Grimaldi with AOGCC waived witness of BOP test -All test were witnessed by WSL 1 Pull test plug -Install wear ring 1 Mobilize drilling BHA to rig floor -Change elevators 1 P/U drilling BHA - M/U MWD, near bit stab, & bit 1 Cont M/U drilling BHA 1 Upload MWD 1 Cont M/U drilling BHA -Surface test MWD (200 gpm ~ 1060 psi) 1 P/U 4" HWDP & 4" drill pipe from pipe shed 1 Fill pipe and test MWD 250 GPM @ 1500 psi -Not getting good detection -Trouble shooting -Aired up mud 1 RIH to 8456' 1 Circulate drill pipe volume (270 GPM @ 2200 psi) 1 Test casing to 1000 psi for 30 minutes (Good) 1 Drill latch collar, cement, float collar, cement to 8665' (PU 225, SO 140, RW 170, WOB 5-8, 255 GPM, 2020 psi, 80 RPM, 13 TO) 1 Circulate hole clean (255 GPM @ 2020 psi) 1 Pump 70 bbls treated H2O, 40 bbls high vis sweep -Displace to 10.0 ppg mud (Initial 2300 psi, final 270 gpm ~ 1650 PSI) 1 Drill out shoe and 20' new hole to 8690' (1900 psi ~ 270 GPM, WOB 12, PU 220, SO 160, RW 175, 80 Rpm, 13 TO) 1 Circulate hole clean (1750 psi @ 290 GPM) 1 R/U -Perform FIT (MD 8670', TVD 6989', MW 10.ippg, 872 psi) - EMW = 12.5 ppg (Good test) - R/D 1 Drill from 8690' to 8738' TVD 7014' (PU 215, SO 160, RW 185, WOB 12, 1700 psi, 290 GPM, 80 RPM, 13 TO) ADT= 1.04 hrs 1 Circulate hole clean - R & R (290 GPM, 1700 psi) 1 Check flow (static) -Pull 1 stand into casing 1 Clean pits and prepare for coring fluid 1 Offload oil base mud to pits -Heat oil base mud to 90 degrees using Hot Oil services 1 PJSM -Displace well to 10 ppg oil base mud (pump 100 bbls H2O /soap, 100 bbls high vis 10 ppg spacer, 40 bbls high vis sweep, 520 bbls OBM) (252 GPM C~ 2100 psi) 1 Cont displace w/OBM (PU 225, SO 155, RW 180, 252 GPM, 2100 psi) (Monitoring hole while cleaning pits observed 1 bbl Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 11 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ' it Description of Operations ~~ ~ Phase --~ 1/6/2007 00:00 - 01:30 1.50 DRILL P PROD1 gain over 20 hour period. Had traces of vil with bottoms up.) 01:30 - 02:00 0.50 DRILL P PROD1 Clean out trough, hole fill line -Stand back 1 stand -Observe well 02:00 - 03:00 1.00 DRILL P PROD1 PJSM -Handling core barrel and shuttle practice run 03:00 - 05:30 2.50 DRILL P PROD1 Drill from 8738' to 8786' (PU 225, SO 155, RW 180, RPM 100, TO 11, 290 GPM, 2750 psi) 05:30 - 06:30 1.00 DRILL P PROD1 CBU - R & R (100 RPM, 290 GPM, 2750 psi) 06:30 - 08:00 1.50 DRILL P PROD1 Pump out of hole from 8786' to 8079' 08:00 - 08:30 0.50 DRILL P PROD1 Clean floor -Observe well -Mobilize coring tools to rig floor 08:30 - 11:00 2.50 DRILL P PROD1 Pump 12 ppg pill -POOH from 8079' to 5240' 11:00 - 12:30 1.50 DRILL P PROD1 Review core handling procedures with both crews while changing out Hi-Line breaker 12:30 - 16:30 4.00 DRILL P PROD1 POOH from 5240' to 1628' 16:30 - 20:30 4.00 DRILL P PROD1 C/O elevators & roughneck to handle 4" work string & BHA - POH w/4" DP &HWDP - L/D NMDC & stabs 20:30 - 21:00 0.50 DRILL P PROD1 Download MW D 21:00 - 22:00 1.00 DRILL P PROD1 L/D MW D, stab, & bit 22:00 - 00:00 2.00 DRILL P PROD1 Clean rig floor (oil base mud) 1/7/2007 00:00 - 00:30 0.50 EVAL P PROD1 Continue clean floor -Mobilize coring tools to floor 00:30 - 03:30 3.00 EVAL P PRODi PJSM - M/U outer core barrels, 6.75" core bit - P/U & space out inner barrels 03:30 - 06:00 2.50 EVAL P PROD1 P/U DC's &HWDP - M/U core BHA -Surface test BHA (100 GPM @ 80 psi) 06:00 - 10:00 4.00 EVAL P PROD1 RIH from 1978' to 8588' (fill pipe every 25 stands) 10:00 - 14:00 4.00 EVAL P PROD1 Circulate hole and pit volume mixing tracer into system (180 GPM @ 1060 psi) 14:00 - 16:00 2.00 EVAL P PROD1 M/U space out pups -Wash down to 8786' (PU 205, SO 155, 168 GPM, 910 psi) - Pulf up to 8693' -Drop ball -Circulate ball down (psi increase to 1540 psi C~3 150 GPM) 16:00 - 00:00 8.00 EVAL P PROD1 Coring from 8786' to 8831' (PU 210, SO 155, RW 180, 1260 psi, 150 GPM, WOB 12/20, TO 6/11) 1/8/2007 00:00 - 02:30 2.50 EVAL P PROD1 Coring to 8831' -Total 45' of core cut -Last 2 1/2 hours no progress, POOH to evaluate (PU 210, SO 155, RW 180, 1260 psi, 150 GPM, WOB 12/20, RPM 60, TO 6/9) 02:30 - 03:00 0.50 EVAL P PROD1 Pump out of hole 5 stands (25 to 35K overpull up to 7760' or top of liner) 03:00 - 10:00 7.00 EVAL P PROD1 Observe well (static) -Pump dry job -POOH to 1978' 10:00 - 10:30 0.50 EVAL P PROD1 Clean floor - C/O rubbers in mud bucket, and elevators to work 4" work string 10:30 - 14:00 3.50 EVAL P PROD1 POOH with 4" DP, HWDP, DC's 14:00 - 18:00 4.00 EVAL P PROD1 Pull core barrels - Break off bit -Pull inner barrels -Gamma log cores - L/D inner cores to pipe shed (Recovered 45' core, bit was not damaged apparently core jammed in inner barrels) 18:00 - 19:00 1.00 EVAL P PROD1 Clean OBM from rig floor 19:00 - 21:00 2.00 EVAL P PROD1 M/U inner core barrels & install in outer barrels - M/U bit & coring BHA 21:00 - 00:00 3.00 EVAL P PROD1 RIH to 7172' (fill pipe every 25 stands) 1/9/2007 00:00 - 00:30 0.50 EVAL P PROD1 Cont RIH from 7172' to 7770' 00:30 - 01:30 1.00 EVAL P PROD1 Slip and cut drill line 01:30 - 02:30 1.00 EVAL P PROD1 Service top drive and blocks 02:30 - 03:30 1.00 EVAL P PROD1 Space out -RIH from 7770' to 8735' 03:30 - 05:30 2.00 EVAL P PROD1 Wash down to 8828' (tight ~ 8795') -Drop ball and circulate ball down (PU 210, SO 155, RW 180, 100 GPM, 650 psi) Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 12 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To I Hours Task Code NPT ~ Phase Description of Operations 1/9/2007 05:30 - 15:00 9.50 EVAL P ~ ~ PROD1 ~ Core from 8831' to 8867' (no progress past 8867') (PU 220, 15:00 - 17:00 2.00 EVAL P PROD1 17:00 - 17:30 0.50 EVAL P PROD1 17:30 - 22:00 4.50 EVAL P PROD1 22:00 - 23:00 1.00 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/10/2007 00:00 - 02:00 2.00 EVAL P PROD1 02:00 - 07:00 5.00 EVAL P PROD1 07:00 - 08:30 I 1.501 EVAL I P I I PROD1 08:30 - 12:30 4.00 EVAL P PROD1 12:30 - 13:00 0.50 EVAL P PROD1 13:00 - 14:00 1.00 EVAL P PROD1 14:00 - 17:30 3.50 EVAL P PROD1 17:30 - 18:00 0.50 EVAL P PROD1 18:00 - 20:00 I 2.001 EVAL I P I I PROD1 20:00- 20:30 0.50 EVAL P PROD1 20:30 - 23:00 2.50 DRILL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/11/2007 00:00 - 02:30 2.50 EVAL P PROD1 02:30 - 04:00 1.50 EVAL P PROD1 04:00 - 06:00 2.00 EVAL P PROD1 06:00 - 09:00 3.00 EVAL P PROD1 09:00 - 10:30 1.50 EVAL P PROD1 10:30 - 11:00 0.50 EVAL P PROD1 11:00 - 12:00 .1.00 EVAL P PROD1 12:00 - 13:00 1.00 EVAL P PROD1 13:00 - 17:00 4.00 EVAL P PROD1 17:00 - 19:00 2.00 EVAL P PROD1 19:00 - 22:30 3.50 EVAL P PROD1 22:30 - 00:00 1.50 EVAL P PROD1 1/12/2007 00:00 - 00:30 0.50 EVAL P PROD1 00:30 - 01:30 1.00 EVAL P PROD1 01:30 - 02:30 1.00 EVAL P PROD1 02:30 - 09:00 6.50 EVAL P PROD1 SO 155, RW 180, WOB 15-25, RPM 40/70, TO 5-18, 1240 psi, 150 GPM) Pump out of hole 10 stds Flow check (static) -Pump dry job -Blowdown top drive POOH from 7929' to 1978' C/O elevators & mud bucket rubbers to handle 4" work string - Clean OBM from floor Stand back 11 stands 4" DP & 1 stand 4" HWDP Stand back BHA to core barrels Pull inner core barrels (only 5' of core recovered) -Inspect inner barrels -Pull outer barrels - UD and inspect same - UD bit Clean OBM from rig floor -Service top drive -Discuss options with town M/U cleanout BHA to 250' -Test MWD (good test) Lubricate rig Continue RIH w/ BHA to 2025' - C/O to 5" elevators RIH from 2025' to 8670' (fill every 25 stands) Wash to bottom @ 8865' (PU 212, SO 155, 1920 psi, 280 GPM) Survey @ 8865' MD -Pull up to 8809' MD -Survey -Wash to bottom -Mad pass from 8865' to 8721' (PU 212, SO 155, RW 180, RPM 50, TO 12, 1860 psi, 280 GPM) Evaluate logs Drill from 8865' to 8872' MD, 7057' TVD (PU 212, SO 155, RW 180, 100 RPM, TO 9, WOB 13, 1970 psi, 284 GPM) Circulate hole clean - R & R - (100 RPM, TO 10, 2100 psi, 300 GPM) Continue circulate hole clean - R & R (PU 212, SO 155, RW 180, RPM 100, TO 10, GPM 300, 2050 psi) Pump out of hole from 8870' to 7770' Circulate hole clean ~ top of liner w/ 300 gpm 1950 psi - R& R w/ 40 rpm Observe well (static) -Pump dry job -Blowdown top drive - POOH to 2029' Stand back cleanout BHA Download MWD UD MWD, junk basket, bit Clear floor of vendor tools -Clean OBM off floor P/U M/U outer core barrels and stabilizers - M/U inner barrels and space out - M/U bit RIH with core run #3 BHA C/O to 5" elevators -RIH from 1950' to 8653' (fill pipe every 25 stands) Cut and slip drill line -Service top drive - Circulating ~ 740 psi, 150 GPM Continue circulate bottoms up (150 GPM Cat 740 psi) Wash from 8653' to 8872' (PU 215, SO 155, RW 180, 740 psi, 150 GPM) Pull up to 8844' - Drop ball -Circulate ball down Coring #3 run from 8872' to 8876' (no progress) (126 gpm 800 psi - WOB 2-17k) Printed: 1/23/2007 77:04:29 AM BP AMERICA Page 13 of 15 Operations Summary Report Legal Well Name: MPF-99 Common Well Name: MPF-99 Spud Date: 12/13/2006 Event Name: DRILL+COMPLETE Start: 12/6/2006 End: 1/10/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 1/17/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ;Code ~I NPT Phase Description of Operations 1/12/2007 09:00 - 11:00 2.00 EVAL P PRODi 11:00 - 15:00 4.00 EVAL P PROD1 15:00 - 17:00 2.00 EVAL P PROD1 17:00 - 20:00 3.00 EVAL P PROD1 20:00 - 20:30 0.50 EVAL P PROD1 20:30 - 00:00 3.50 EVAL P PROD1 1/13/2007 00:00 - 03:00 3.00 EVAL P PROD1 03:00 - 04:30 1.50 EVAL P PROD1 04:30 - 05:00 0.50 EVAL P PROD1 05:00 - 17:00 12.00 DRILL P PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21:00 0.50 DRILL P PROD1 21:00 - 23:00 2.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 1/14/2007 100:00 - 01:30 I 1.501 DRILL I P I I PROD1 01:30 - 03:00 1.50 DRILL P PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 07:30 1.50 DRILL P PROD1 07:30 - 10:00 2.50 DRILL P PROD1 10:00 - 11:00 1.00 DRILL P PROD1 11:00 - 13:00 2.00 EVAL P PROD1 13:00 - 19:00 6.00 EVAL P PROD1 19:00 - 20:00 1.00 CEMT P PROD1 20:00 - 22:00 2.00 CEMT P PROD1 22:00 - 00:00 2.00 CEMT P PROD1 1/15/2007 00:00 - 00:30 0.50 CEMT P PROD1 00:30 - 01:00 0.50 CEMT P PROD1 01:00 - 01:30 0.50 CEMT P PROD1 01:30 - 03:30 2.00 CEMT P PROD1 03:30 - 04:30 1.00 CEMT P PROD1 04:30 - 05:30 1.00 CEMT P PROD1 05:30 - 07:30 2.00 CEMT P PRODi 07:30 - 14:30 I 7.00! CEMT I P I I PROD1 14:30 - 15:00 0.50 EVAL P PROD1 15:00 - 15:30 0.50 EVAL P PROD1 15:30 - 16:30 1.00 EVAL P PROD1 Pump out of hole f/ 8876'-7710' w/ 145 gpm, 1000 psi Observe well - POH w/ 5" DP to 1950' Stand back 4" DP, HWT, jars, DC's. PJSM - UD coring assembly #3 (Core catcher was pushed up into core barrel 1 1/2 feet jamming barrel, recovered 5" of cores) Clear and clean rig floor M/U drilling BHA RIH from 2027' to 8637' (fill pipe every 25 stands) CBU (PU 210, SO 155, RW 180, 295 GPM, 2230 psi) Wash to 8876' Drill from 8876' to 9106' (PU 215, SO 155, RW 180, 292 GPM, 2140 psi, 100 RPM, TO 9, WOB 20) CBU 3X - R & R (100 RPM, 300 GPM, 2140 psi) Flow check (static) -Pump out of hole from 9106' to 8670' (300 GPM ~ 2140 psi) Flow check (static) -RIH to 9106' CBU 2X - R & R (300 GPM, 2100 psi, 100 RPM) Pump out of hole from 9106' to 8525' (300 GPM, 2100 psi, PU 210, SO 155) Continue pump out of hole from 8525' to 7692' (300 GPM, 2050 psi) CBU 2X - R & R (300 GPM, 2050 psi, 40 RPM, TO 7) Check flow (static)- Pump dry job -POOH from 7692' to 2027' Stand back 4" DP, HWDP, DC's UD 4 3/4" flex DC's -Download MWD -Flush MWD w/LVT fluid - UD MWD & bit Clear and clean OBM from rig floor Mobilize and R/U SWS wireline Run USIT/CBL logs to 8665' -USIT log failed during operation - Continued w/ CBL f/ 8665' to 7745' - R/D SWS Mobilize and R/U to run 3 1/2" tubing PJSM -RIH with 17 joints 3 1/2" IBT tubing and 4" HT-38 drill pipe RIH w/5" drill pipe from 1570' to 7235' (PU 172, SO 140) Cont RIH from 7235' to 8652' Circulate pipe volume @ 8652' (210 GPM, 700 psi) RIH from 8652' to 9024' -Wash to 9106' (PU 197, SO 155, 256 GPM, 850 psi) Circulate and condition mud -PJSM -Batch up cement PJSM -Pump 10 bbls 12 ppg OBM spacer, Test lines to 2500 psi, Pump 27 bbls 15.8 ppg gas bloc cement, Pump 2.25 bbls 12 ppg OBM spacer, Drop wiper ball, Displace with OBM 1400 strokes with rig (Cement in place @ 04:30) POOH 10 stands to 8163' Pump nut plug sweeps and circulate hole clean (420 GPM, 1100 psi, 30 bbls contaminated OBM overboard) Circulate C~3 8163' -Wait on cement (155 GPM, 460 psi) - Clean mud pits 3,4 & 5, flush lines, and surface equipment RIH -Tag cement at 8620' MD with 10 K down weight Circulate pipe volume (300 GPM, 1160 psi) R/U test equipment -Test casing to 1200 psi for 30 minutes (good test) - RD test equipment Printed: 1/23/2007 11:04:29 AM BP AMERICA Page 14 of 15 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPF-99 MPF-99 DRILL+C DOYON DOYON Hours j 1 OMPLE DRILLIN 14 Task TE G INC Code . NPT Start Rig Rig ~ Phase Spud Date: 12/13/2006 : 12/6/2006 End: 1/10/2007 Release: 1/17/2007 Number: Description of Operations 1/15/2007 16:30 - 21:00 4.50 EVAL P PROD1 PJSM -Circulate while loading pits w/seawater -Displace OBM w/8.5 seawater (pump 20bbls LVT, 80 bbls 10 ppg LSND with safe surf O, 560 bbls sea water, 300 GPM, 990 psi) -Returns did not clean up ,ordered more seawater 21:00 - 22:00 1.00 EVAL P PROD1 Turn water on throughout rig -Clean rig floor, drip pan, mud pits of OBM 22:00 - 23:00 1.00 EVAL P PROD1 UD 21 jts 5" drill pipe -RIH 7 stds from derrick 23:00 - 00:00 1.00 EVAL P PROD1 Continue clean rig and pits of OBM while waiting on seawater 1/16/2007 00:00 - 02:30 2.50 TA P ABAN Continue cleaning pits, rig floor, and pollution pans of OBM while waiting on clean seawater 02:30 - 03:30 1.00 TA P ABAN Pump 30 bbl hi-vis sweep and displace with clean seawater (420 GPM, 1200 psi) 03:30 - 06:00 2.50 TA P ABAN Pump dry job - Slowdown top drive -POOH UD 5" drill pipe from 8620' to 6526' 06:00 - 07:00 1.00 TA P ABAN Slip & cut drilling line 07:00 - 08:00 1.00 TA P ABAN Service rig -Blocks, Top Drive ,Crown, Draw-works 08:00 - 11:30 3.50 TA P ABAN Continue UD 5" DP to 1570' 11:30 - 12:30 1.00 TA P ABAN Change elevators -Clear floor - UD 4" DP to 522' 12:30 - 13:30 1.00 TA P ABAN RIH w/ mule shoe - 3 1/2" tubing - 4 3/4" drill collars - 4" HWDP to 1350' 13:30 - 14:00 0.50 TA P ABAN Circulate 120 degree seawater surface to surface / 500 GPM / 970 PSI 14:00 - 17:00 3.00 TA P ABAN LD 4" HWDP - 4 3/4" drill collars - 3 1/2" tubing -mule shoe - Clear rig floor 17:00 - 19:00 2.00 TA P ABAN PJSM -Change out Saver sub to 4" HT -Clean oil base mud from torque tube -Change out Dies and guide on iron roughneck 19:00 - 20:00 1.00 TA P ABAN RU stack washer -Flush out stack w/ hot water /function rams - RD stack washer 20:00 - 21:00 1.00 TA P ABAN Pull wear ring -Install test plug 21:00 - 22:00 1.00 BOPSU P ABAN PJSM -Change out rams to 2 7/8" x 5" VBR's 22:00 - 22:30 0.50 BOPSU P ABAN RU test equipment -Test bonnet door seals to 1500 psi f/ 5 mins. -Record on chart - RD test equip. 22:30 - 00:00 1.50 TA P ABAN PJSM - RU tubing equipment -Run 2 7/8" kill string 1/17/2007 00:00 - 01:30 1.50 TA P ABAN Con't RIH with 2 7/8" Kill string to 2194' 01:30 - 02:30 1.00 TA P ABAN MU Head pin -Reverse circ 165 bbls 100 degree seawater 02:30 - 04:00 1.50 TA P ABAN RD head pin - MU Tubing hanger -Land tubing C~? 2225' - RILDS -Test from below to 1000 psi for 10 mins 04:00 - 04:30 0.50 TA P ABAN LD landing joint - RD tubing equipment -Clear floor of tools and equipment 04:30 - 06:30 2.00 BOPSU P ABAN Nipple down BOP's -Riser - Flowline 06:30 - 08:00 1.50 BOPSU P ABAN Nipple up Adapter Flange, Tree - 08:00 - 09:30 1.50 BOPSU P ABAN Test Adapter flange to 5000 psi -Test tree (TWC leaking) - Change hobbit in TWC -Test tree to 5000 psi -Good test -Pull TWC 09:30 - 11:00 1.50 TA P ABAN RU Hot Oil truck to pump diesel freeze protect 11:00 - 12:00 1.00 TA P ABAN Clear /Clean Rig floor/ cellar -Wait on diesel for freeze protect to arrive from WOA 12:00 - 14:00 2.00 TA P ABAN PJSM -Freeze protect tubing - IA -with 156 bbls diesel for Hot Oil - 1.78 bpm - @ 500 psi 14:00 - 14:30 0.50 TA P ABAN U-tube Diesel for 30 mins -Clean pits 14:30 - 15:00 0.50 TA P ABAN Install BPV -Test to 1000 psi -Suck lines out - RD hot oil -, 15:00 - 17:00 2.00 TA P ABAN RD lines -Clear cellar area -Secure tree -Rig released ~ Printed: 1/23/2007 11:04:29 AM Printed: 1/23/2007 77:04:29 AM Suspension of MPF-99 • • Subject: Suspension of MPF-99 From: "Hanson, Paul" ~Paul.Hansonl@bp.com> Date: Tue, 16 Jan 2007 16:42:46 -0900 To: Thomas Maunder 'tom nrnm~er ~r`:~~tmin.state.~il~.ls> «Request for Sundry for Temporary Suspension.ZlP» Tom, Per our conversation and your verbal approval, I wrote the attached letter yesterday, which describes our plan for suspending MPF-99. Since this time, we tested the plug to a 13.3 ppg EMW, exceeding our fit test below the liner and tagged hard cement, and our CBL log shows good cement across the liner, so It looks like we're in good shape. We have also displaced the coring fluid to brine. Over the evening we should be running the kill string to 2100' and freeze-protecting with diesel. The well should be buttoned up by sometime tommorrow, expect, and we'll be moving to MPS-33. I will get the Sundry Permit form to you in the next couple days, if this is acceptable. Best Regards, Paul Hanson ODE - ADW/ACT Drilling __ _ Request for Sundry for Content-Description: Temporary Suspension.ZIP Request for Sundry for Temporary Suspension.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 1/26/2007 9:02 AM ~ • Maunder, Thomas E (DOA) From: Dave Roby [dave_roby@admin.state.ak.usj Sent: Tuesday, December 19, 2006 1:33 PM To: 7F~amas Maunder Cc: Steve Davies Subject: Re: [Fwd: MPF-99 plans after drilling] Attachments: dave roby.vcf ~, "" '-1 dave_roby.vcF (2 KB) I'd ask for a little more specifics on the "various waters" they want to inject so that we can ensure that they are already on the list of approved fluids. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 Thomas Maunder wrote: > AIO 10, l0A and lOB apply to the 3 pools at Milne Point. MPF-99 will > be a Kuparuk well. Source water from the Prince Creek is authorized. > This is the source of the "low sal" water so far as I know. Tracer > fluids are also authorized. I'd agree that multiple sundries is > something to avoid. > Looks like they have all in place necessary to conduct the operations. > Just have to keep track of "in" and "out". > Tom > Dave Roby wrote, On 12/19/2006 1:16 PM: » Do they have an approved AIO for the pool that this well is completed » in? If not they will need to apply for a pilot FOR project with its » mandatory public notice and comment provisions. » If they do have an AIO is LoSal and the tracer fluid among the fluids » approved for injection? If not we can probably add these fluids » through an administrative approval. » Do we need a sundry every time they change it from an injector to a » producer? Hopefully not. » Dave Roby » Reservoir Engineer » Alaska Oil and Gas Conservation Commission » 907-793-1232 » Thomas Maunder wrote: »> Does this take anything special? Looks like a pilot to me. »> »> -------- Original Message -------- »> Subject: MPF-99 plans after drilling »> Date: Tue, 19 Dec 2006 11:53:14 -0900 »> From: Ohms, Danielle H <Danielle.Ohms@bp.com> 1 »> To: Thomas Maunder <tom maunder@admin.state.ak.us> »> »> »> »> Tom, »> »> Just wanted to run by you what the plans for MPF-99 were after »> drilling is complete and facilities are hooked up since it will be »> used for a special test. I don't believe any special Sundries will »> be required, but want to run by you to make sure. »> »> The permit to Drill (approved 11-21-06) for MPF-99 has this well as »> an ESP Producer which it is initially being completed as. As the »> request stated, a ~3 month Single Weli Chemical Tracer Test (SWCTT) »> will be conducted. This test involves pre-producing the well for ~2 »> weeks, then injection 5,000-10,000 bbls of Produced Water into the »> well below frac pressure (as ensuring we test the matrix is »> criticalJ. The tail end of this will have a some propyl alcohol and »> ethyl acetate injected as the tracer, the well will then flowed back »> for several days. Another 3 rounds of injecting1000 bbls of »> various waters (below frac pressure) with the propyl alcohol and »> ethyl acetate then flowing back will be performed. This is all part »> of some extensive work to help quantify the benefits of LoSal (low »> salinity) water injection at MPU. This SWCTT will be very similar »> to several others performed on the slope. »> When this SWCTT is complete we are planning to convert this well to »> an injector and the appropriate Sundry Permit Applications will be »> applied for then. If any special permits will be needed for the »> SWCTT associated with F-99 please let me know, otherwise I'm »> assuming we are ok without one. Thanks. »> »> Danielle Qhms »> Lead PE »> Milne Point Subsurface Team »> (907) 564-5759 office »> (907) 440-9082 cell »> 2 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Milne Point Unit, Kuparuk River Oil Pool, MPF-99 BP Exploration (Alaska) Inc. Permit No: 206-156 Surface Location: 2200' FSL, 2449' FEL, SEC. 06, T13N, R10E, UM Bottomhole Location: 3284' FSL, 3040' FEL, SEC. 07, T13N, RlOE, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~ day of November, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~JN ti ~~~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^~xploratory ~^ Development Gas r ~ervice ~/,r(i ^ Multiple Zone ^ Stratigraphic Test ~/~j~evelopment Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: MPF-99 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9213' - TVD 7249' • 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surtace: 2449' FEL 2200' FSL T13N R10E SEC 06 UM 7. Property Designation: ADL 025509 Sands , , , . , , (Punned) Top of Productive Horizon: 3549' FSL, 3111' FEL, SEC. 07, T13N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 28, 2006 Total Depth: 3284' FSL, 3040' FEL, SEC. 07, T13N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7414' - 4b. Location of Well (State Base Plane Coordinates): Surface: x-542112 ~ y-6035652 Zone-ASP4 10. KB Elevation (Height above GL): 44.5 feet 15. Distance to Nearest Well Within Pool: 1540' away from MPL-02 16. Deviated Wells: Kickoff Depth: 300' feet Maximum Hole An le: 67 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4433 Surface: 3750 18. C i Pr ram: 5 cifi ns To - S in D th - B ttom u nti f merit c.f. or acks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 92# H-40 Welded 72' 34' 34' 106' 106' 260 sx Arctic Set A rox. 16" 13-3/8" 68# L-80 BTC 4795' Surface Surface 4795' 4795' 511 sx AS Lite 653 sx Class 'G' 12-1/4" 9-518" 47# L-8 TCII/BTC-M 7 urf ce Surfac 7899' 6724' 402 sx I s' ' 8-1/2" 7" 26# L-8 BTC-M 1464' 7749' 6665' 9213' 7249' 289 sx Class 'G' 19. PRESE NT-WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): using Length: ize ementVolume MD D Conductor /Structural Surface Intermediate Pro uc ion Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Paul Hanson, 564-4195 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~~~ Phone ~ `-~o Date « l ~ DSo Sondra Stewman, 564-4750 Commission Use: Onl Permit To Drill Number: ~~.~5~ API Number: 50- bL9- 23332-off Permit Approval f ~ See cover letter for Date: l "~~-( other re irement Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: `"G4T~Csc-~'vcch~C~vU.`~~~ ~p a t{~(~~) ~S, ~~amples Req'd: ^ Yes ~No Mud Log Req'd: ,^-/Yes Ly No `~ ~~.~~~~,~~~~ ~C ~ Q~S~ ~S ~~> `~~ HZS Measures: Yes ^ No a Tonal Survey Req'd: L"7 Yes ^ No Other: ~ .~•-~ ~.,.G.~ 6 ~~~Z b r~ ~ h C~CCSJ r~ "~' ~ ~ ~~ ~ APPROVED BY THE COMMISSION Date ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ R I G I f~'A ~~~-- Submit In~D~u~plicate ~~~"~~ • • by November 14`", 2005 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7`" Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Permit to Drill, Core and Complete MPF-99i (Pre-Produced Injector) Mr. Maunder: Doyon 14 is presently scheduled to spud MPF-99i on November 28±. As is detailed in this permit application package, the plan is to drill 16" surface to 4795' MD and set 13-3/8"below the SBF, drill 12-1/4" hole to 7899' MD in the Kalubik (KLGB = Kalubik Gamma Ray Marker) and set 9-5/8" 47#. From this depth, we will dri118-1/2" hole to TD at 9213' MD in the Base case and set 7" 26#. However, if we encounter overpressure in the Lower Kalubik/Kuparuk Dand take a / kick, we will kill the well, and drill ahead to above core point, under-ream the hole to 9-1/2" and seta 7-5/8" 29.7# drilling liner (150' of lap with the 9-5/8") 8500' MD. At this point we would dri116-3/4" hole to TD and tie the liner all the way back into the 9-5/8". ',`' With respect to coring, the cored interval will be from about 8600' +/- MD to 8900" +/- (roughly 3 - 90' Cores covering the Kup A sands (at ~66 degrees) with a priority of retrieving a minimum of the A3 sands. 8-/1/2" x 4" and 6-3/4" x 3-1/2" core barrels will be available to cover the base and contingency cases. The coring fluid will be a ~ 10 ppg mineral oil-based (waterless) system. ~ After the coring and evaluation program are concluded, we will run a temporary 2-7/8" ESP completion to conduct a ~3-month Single Well Tracer Test. The conversion of this well to a designated injector will be covered in a future Sundry Permit Application. If I can provide any additional information, please contact me C 564-4195 Sincerely, __~ ,. ,- ~~7, a Paul Hanson Drilling Engineer BPXA /ACT • • by ~:~~ November lOt", 2005 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue, Suite 100 Anchorage, AK 99501 'T~~~~('` ~S ~~ EtJC~~ V C~cJ Re: Request for Exception to 20 AAC 25.035 (c) ~o ~~b~..~S ~~~~~~~~^~~ MPU F-Pad /MPF-99i ~~~~~~~`~`~'~"~~~ S~c~ ~~~ Mr. Maunder: ~-1 BP Exploration (Alaska) Inc. ("BP") hereby requests an exception to 20 AAC 25.035(c) in accordance with 20 AAC 25.035(h)(2) allowing Doyon 14 to drill the surface hole without using a diverter. The requested exception pertains to the drilling of MPF-99i, a Kuparuk A sand injector, and references a similar exception granted for MPF-89i in 2005. The MPF-99i well plan includes 13-3/8" surface casing to be set through the Schrader Bluff sands. It is this hole section for which this exception is requested. In excess of 50 wells have been drilled from MPU F-Pad. According to drilling records and the Pad Data Sheet, none of the F-Pad wells ~ have experienced gas, gas hydrates or abnormal pressure in this geologic section. Furthermore, the only hydrocarbon show noted in this hole section was a Schrader Bluff heavy oil show in MPF-50 back in 1997. No subsequent shows have been reported even though the subsequent wells have drilled this hole section with 9.5 ppg mud or (in most cases) less. The only potential hydrocarbon bearing zone in this hole section is the Schrader Bluff "O" sands. The Schrader Bluff "O" sands that underlie F-Pad are low on structure, and in most cases, water bearing. Any potential oil bearing sands would contain heavy, viscous oil with extremely low GOR and low mobility. An oil bearing sand in this hole section would not be capable of flow to surface. Additionally, the nearest Schrader Bluff injection well, MPJ-15i, is located 3.5 miles away from F-Pad and it is surrounded by producers (see attached map). If you have any questions or require any additional information, please contact the undersigned at 564-4195, or Dan Kara at 564-5667. Sincerely, ~~- ,~ ~~' 1 Ha ~on ~ ~~ Drilling Engineer BPXA /ACT • • Tod Schrader Time- Structure Map with current Schrader Bluff injectors ~ 1 ~ / ;' ti \~ ~ V ~~ ~ r~ ~ )wie ~.,~ ~ ~ ~~ ~4t ~ ~ IP4,9 /~ ff , j / / i~ a~ ~~ ~ ~ ~t '. ~ ~ 1 ~, /1 r~~ `,'~ y~: \~~ 1 ~' t ~>. ---- - ~~ ~~ F-Pad is 3 S miles ne~u~e~t ~-~~ '~~ Schrader Bluit injectorMPJ-ISi ~ r~r-~a 1P]-16 , IP~IS 1~7 I' IPlfi') 1Ff-tt 41 ~-08~~ IPl-,7 ~, .~,\ ,; ~~ ~r~~~ ~`~ .,may ~. ~~~~- -==-,.~ ~, ~-~ F ,~~~~. ~'t~', • • rr~~~seu ~,~nuuc~~r wcau~n Milne Point MPF-99i ~, Conductor Location _, J OK a~ ~~ ~ MPF-99i ' ~ 7Y.rrarnwr pescrohon ~ Cancd PNIp WeFeadLocdion Ne4 ~r~ \` ~' S~ yarns ° ~' Ollsd hom Ste Nattls r'-:' ~~ ft ~esc~- h 6. q ° ~ ~ S / ~ t: MaD Ngthng 603565?.36 ft Egsting Sd?1 t 7 97 h ;~ ~ s f ~ GeogepFvc LaNude: 7Q'30'29.937N Lorgtude 119'39'79.588W Oa{ ~ t i Q1 Pos2ionUnceaenty ~~ ~ s p~ Wdj?os6onEna-. 0.00 h dWetlRd Pow !~ Tilt D91 ~ S ~ ~ WdRderencePant _-__._-...... - C ~ ~ ^ i ~ ~ Vntical Distance ~. 10.00 N Atwve Syalem o g9 D~ ~ S a ~ (- Nan vaticd ICuved CardueeorlSlant Rgl 0 D~ ~ ^ 1 ~ Additgnal Measued Deph at WRP ~ n `'-' ~ ~ ~ ~ ~ r~ Ollsd hom Wefxad North: ~~ It East ~ N r FwdtlrJo s ~ Z~ IncGsetion: ^ ~ 18 s ~ ~ T ~ deg Axmuth I -deg Looked f 14 s ;f 18 -- _ - _- °81 l0~ ^9 a 8D 6 ~ ~ ~ E8r ~ ' ^ 79 2 ~ ,~ 1 'Need 20" conductor set in- ~P~ '' _ ' ~~I line with the existing well ~~ ~ 'I row, 30' N-E of MPF-77. T~B~mr ~ ! sanm~ oae:>two+ ~:r-tllll IMrOKtE:twg NPU- FPJ1D rnLnsotta~ ~ • ~ by Well Name: MPF-99i Kuparuk A Sand Injector Drilling and Completion Plan Summary T e of Well: Kuparuk A Sand Injector Surface Location: 2,200' FSL and 2,449' FEL (As Planned) Section 6, T13N, R10E UM E = 542,111.97' N = 6,035,652.36' T1 - KLGM Near Base of Colville 4446' FSL and 3029' FEL 7,854' TMD -7,899' MD(rkb) Section 7, T13N, R10E UM E = 541,561' N = 6,032,616' Z = 6,680' TVDss T2 -Top of TMLV 3,549' FSL and 3,111 FEL 8,868' TMD - 8,913 MD(rkb) Section 7, T13N, R10E UM E = 541,488' N = 6,031,719' Z = 7,085' TVDss T3 - TD 3,284' FSL and 3,040' FEL 9,168' TMD - 9,213' MD(rkb) Section 7, T13N, R10E UM E = 541,561' N = 6,031,454' Z = 7,205' TVDss Distance to Pro ert line 7,414' Distance to nearest well 1,540' from MPL-02 AFE Number: Estimated Start Date: 12/~A3f2006 i~ 28Io4 Ri Do on 14 Ri da s to com lete: 29 MD: 9,213 ~ TVD: 7,249' ~ Max Inc: 67° KOP: 300' KBE: 44.5' Well Desi n: Sin le Zone, Bi -Bore Pre-Produced Injector Ob'ective: Ku aruk A Sand - Mud Program: 16" Surface Hole (0' - 4,795'): LSND Densit PV YP H API Filtrate Chlorides 9.2 - 9.6 30 - 55 35 - 50 8.0-9.0 NC - 8.0 < 1200 12-1/4" Intermediate Hole 4,795' - 7899' : LSND Densit PV YP H API Filtrate HT-HP 8.8-9.6 8-14 18-26 9-10 <6 N/A To 7,000' 10.0 14 - 20 18 - 26 9-10 4-6 < 10 To KLG M 8-1/2" Kuparuk Section to Core Point (7899 to ~*8600~'): Bland LSND :Densit PV YP H API Filtrate HT-HP`' 10.0-10.1 14-20 18-26 9-10 4-6 <10 8-1/2" Kuparuk Coring Section (8600± to 8900±'): 100% Mineral Oil-Based ~- :Densit PV YP ' H HTHPfiltrate ~9.3 20-35 20 - 30 N/A < 2 Upon completion of coring operations, the well will be displaced back to LSND fluid for drilling of rathole to 9213' and logging/pressure survey program. * It is possible that overpressure could be encountered in the Lower Kalubik/Kuparuk D, with overpressures as high as 12.5 ~ ppg. If this occurs, 7-5/8" contingency liner will be set, and the`corin--crop duction hole section will be downsized to 6-3/4". Mudweight and properties will be determined by degree of overpressure. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program Hole Size Csg / Tb O.D. Wt/Ft Grade Conn Length Top MD / TVD Bottom MD / TVD 42" 20" 92# H-40 Welded 72' 34' 106' / 106' 16" 13.375" 68# L-80 BTC 4,795' 0' 4,795' / 4,544' 12.25" 9.625" 47# L-80 TCII/BTC- M 7,899' 0' 7,899' / 6,724' 8.5" 7" 26# L-80 BTC-M 1,464' 7,749'/6,665' 9,213' / 7,249' N/A 2.875" 6.5# L-80 EUE 7,749' 0 7,749'/6,665' Evaluation Program 2 i 16" Section Open Hole: MWD/GR Gyro IFR/CASANDRA S er InSite 12-1/4" Section Open Hole: MWD/GR/RES IFR/CASANDRA S er InSite 8-1/2" Section Open Hole: MWD/GR/RES Neu/Den/Geo Tap/NMR +/- 270' Core (4") IFR/CASANDRA S er InSite Cased Hole: GR / SCMT in PDC mode * / CCL * Also re uired for contin enc and roduction liner if set. Cement Program: Casin Size 13-3/8", 68#, L-80, BTC Surface Casin at 4,795' MD Basis Excess from Base of the Permafrost to Surface = 150% over gauge hole. Use 40% excess below the Base of the Permafrost. Tail cement = 500' MD. Total Cement Volume: 527 bbl Wash 10 bbl water 25 bbl CW 100 S acer 50 bbl of MudPush Lead 410 bbl, 511 sx of Arctic Set Lite: 10.7 and 4.49 ft /sx Tail 117 bbl, 653 sx "G" mixed at 15.6 Ib/ al & 1.20 ft /sx Tem Casin Point BHST 80° F estimated b Dowell Casin Size 9-5/8",47#, L-80, TCII/BTC-M Intermediate Casin at 7,899' MD Basis Tail cement = 1000' MD above shoe. 40% Excess over Gauge Hole. Total Cement Wash 10-bbl water Volume: 84 bbl 25 bbl CW 100 S acer 45 bbl of MudPush Tail 84 bbl, 402 sx "G" mixed at 15.6 Ib/ al & 1.17 ft /sx Tem BHST =150°F from Schlumber er Chart Liner Size 7", 26#, L-80, BTC-M Production Liner: 7,749' to 9,213 MD Basis Top of cement to be 200' above the TOL. Liner Lap > 150'. O en Hole excess = 40%. Total Cement Volume: 60 bbl Wash 5-bbl water 20 bbl CW 100 S acer 30 bbl of MudPush Tail 60 bbl, 289 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST X180°F from SOR Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 16 in Surf - 4,795' 4,795' MX-09D .666 550 - 800 2 12.25 in 4,795' - 7,899' 3,104' PDC 1.162 650-900 3 8.5 in 7,899' - 9,213' 1,314' PDC 0.7-0.9 450-500 Formation Markers: Formation Tops MD ft TVDss (ft) Pore Pressure si EMW Ib/ al BPRF 1949 1850 803 8.35 TUZC 3652 3450 1498 8.35 SBF1-NB 4205 3970 1724 8.35 OA 4334 4090 1776 8.35 Deepest SBF sand 4666 4390 1906 8.35 THRZ Not present B H RZ 7812 6645 KLGM 7899 6680 2900 8.35 TKUD 8249 6820 2961 8.35 TKUC1 8575 6950 2530 7.00 TKUB 8575 6950 2530 7.00 TKUA 8675 6990 2544 7.00 TKA3 8700 7000 2548 7.00 TKA2 8750 7020 2555 7.00 TKA1 8818 7047 2565 7.00 TMLV 8963 7105 2586 7.00 Well Control: . ta~s~~-~.~ Intermediate/Production hole: ~,` • Maximum anticipated BHP: 2,586 psi at 7105' TVD (Top of the MLV) (BASE CASE) • Maximum anticipated BHP: 4,433 psi at 6820' TVD (TKUD) (CONTINGENCY CASE) ~ • Maximum surface pressure: 3750 psi = (4,433 - 682) psi (Based on a full column of gas at 0.1 psi/ft) • Planned BOP test pressure: • Integrity tests: Kick tolerance: • Integrity tests: • Kick tolerance • Planned completion fluid: 4,500 psi FIT to 11.3 Ib/gal 20' below the 13-3/8" shoe. 57-bbl with 9 Ib/gal mud at the 13-3/8" shoe. ~ FIT to 14.0 Ib/gal 20' below the 9-5/8" shoe. Infinite with 10.0 Ib/gal mud at the 9-5/8" shoe (Base Case) Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: y r 4 • Hydrates have not been reported on any of the F-Pad wells ari are not expected in MPF-99. • Tight hole and stuck pipe due to gravel beds, reactive clays and poor hole cleaning have all occurred in F Pad wells. Lost Circulation • Lost Circulation is not reported as a major problem for F-Pad. Irregardless, of this good drilling practices need to be maintained. Expected Pressures • The Schrader Bluff sands are expected to be normally pressured: 8.35 ppg. • The Kuparuk A sands are expected to be slightly depleted down to 7.00 ppg EMW. • Higher pressure could be encountered in the Kuparuk D sand. ~ Pad Data Sheet • Please Read the F-Pad Data Sheet thoroughly. Breathing Hazards • Breathing problems are not anticipated unless ECD exceeds 11.5 ppg. ~ • Appropriate precautions will be employed while drilling (ie: wind socks, H2S detectors, etc.) Hydrocarbons • Hydrocarbons may be encountered in the Ugnu through the Schrader Bluff sands, and will be encountered in the Kuparuk sands. Faults • No faults are anticipated in this well plan. Hydrogen Sulfide • MPF Pad is not designated as an H2S Pad, however, low concentrations of H2S have been ~ detected from Kuparuk wells on the pad: MPF-45 <2 ppm 2/2001 MPF-85 <2 ppm 2/2003 MPF-92 6.7 ppm 9/2003 MPF-88i 7 ppm 9/2003 MPF-30i 32 ppm ~ 9/2003 MPF-621 16.4 ppm 2/2001 MPF-53 32 ppm ~ 9/2003 The highest concentration of H2S on MPF MPF-69 47 ppm ~ 9/2003 Anti-collision Issues • MPF-99 passes the Major Risk Criteria, however, gyro surveys will be required for close approach issues and magnetic interference down to ± 800 ft MD. ~/ Distance to Nearest Property • MPF-99 is 7,414 ft from the nearest Milne Point unit boundary. Distance to Nearest Well Within Pool • MPF-99 is 1,540 ft from the nearest Kuparuk A sand penetration in MPL-02. DRILL & COMPLETION PROCEDURE 5 Pre-Ri O erations q p 1. The 20" conductor will be installed pre-rig. Drillin 1. MIRU. (Install diverter unless waived by AOGCC) 2. Drill 16" surface hole through Schrader Bluff sands to +/-4544' TVD. 3. Run and cement 13.375" surface casing. 4. Install wellhead and NU/Test BOPE. 5. Drill 12.25" intermediate hole into the KLGM. 6. Run and cement 9-5/8" intermediate casing. 7. Drill 8-1/2" hole to core point at ~ 8,600' in the Kuparuk. 8. Displace to waterless coring fluid and condition. 9. RIH w/ coring assembly. Cut a 270' 8.5" X 4" core. 10. Displace (back) to LSND mud. 11. Ream core run and continue drilling 8-1/2" hole through the Kuparuk sands and into the Miluveach. 12. Collect pressure samples with GeoTap and log. 13. Run and cement a 7" liner with HGR, ZXP & PBR. 14. Run SCMT back to point above liner lap */' 15. Displace the well with kill weight brine. 16. RU a-line. Perforate. 17. Run a temporary 2-7/8" tubing string /ESP Completion for Single Well Tracer Test. 18. ND BOP/NU Tree. Freeze protect. 19. RD & MO Doyon 14. 6 by BP EXPLORATION ~~,•,;,aF,,_ ,; , M P F-99 Field: Milne Point Kuparuk A Sand ENG: P. Hanson Pad: F-Pad Injector RIG: Doyon 14 RKB: 44.5 ft DIR / LWD OH DEPTH HOLE CASING MUD INFO FORM MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 106' 30" Welded, Insul 20" x 11" 5K MWD/GR/PWD None Lead Cement Test Csg to Gyro as needed 410 Bbls, 511 sx 2000 psi IFR/Cansandra 10.7 ppg-4.49 ft3/s Base Permafrost 1949' 1850' Surface Csa 13-3/8" 68# 150% Excess TUZC 3,652' 3450' L-80, BTC In Perrnafrost Int. Yield 5020 psi Collaspse 2260 psi Schrader Bluff-NB 4,205' 3,970' Tail Cement ~ 40% Excess Below 117 bbls, 653 sx Permafrost Schrader Bluff-OA 4,334' 4,090' 15.8 ppg-1.17 ft3/s Casing Point 4,795' 4,544' 20° 16" MWD/GR/RES None PWD IFR/Cansandra Inter. Casing Cement Slurry 40% Excess 9-5/8" 84 bbls, 402 sx 47 Ibs/ft 15.8 ppg Test Csg to L-80, 1.17 ft3/sx 4800 psi TCII /BTC-M Class "G" Surface Test Int. Yield 6870 psi Pressure Collaspse 4790 psi 4250 psi TOC 6,899' with 10 ppg Mud Top/LNR/ZXP/PBR 7,749' 6,625' 66° KLGM 7,899' 6,724' 66° 12.25" f MWD/GR/RES ~ ~ Prod Liner liner Cement Test LNR to eu/Den/Geo Ta Top / Kuparuk D 8,249' 6,820' ~ = Liner 7" , 26# 60 bbl, 289 sx 4800 psi W D +/- 270' Cor Top / Kuparuk A 8,675' 6,990' i ~~ ? ~ ~i Point L-80, BTM-Mod Class G, 15.8# 4200 psi Surface IFR/Cansandra Top /Miluveach 8,963' 7,105' ~ ' '= Int. Yield 72ao psi 1.17 ft3/sx 40% Excess NMR Liner Point 9,213' 7,249' >, 66° ' 8.5" Collapse 5410 psi Miluveach 11/15/2006 MPF-99 Well Plan Schematic.xls _ ~ n o V N,~O __ y _ .-. _ . j N c 55 . N FF ~- ~ ~ m - . . ._ _ a -- > L ~ O 6. _ ~ ~~ ° < L "' ii 0.m QMN- F ~ L~CJ~ m ~ NNW, a~:70v»¢¢¢¢Q~ ~ - _ _ . ° P ;n z F ~~ D o a~mQ v2~1:LYIYYY~ ] Y 00 - '~ I ... P u ++ y r.,_ o G1 F V~ FFFFFFFF Q Q ;o: z ~ - y p S ~ u 00P~n0~n .DN?M~maoP v V ~ Nor--.OOJPP,nP rx- ~ '^_ ~ . 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V'v~.D l~oOa------ S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/30/2006 'Cime: 11:09:16 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-99, Tru e North Site: M Pt F Pad Vertical (TVD) Reference: 34.5K6+10GL 44.5 Well: Plan MPF-99 Section (VS) Reference: Well (O.OON,O.OOE,187 .81Azi) Wellpath: MPF-99 Survey Calculation Method: Minimum Curvature Dh: Oracle Plan: MPF-99 Wp 4.0 Date Composed: 10/12/2006 Version: 22 Principal: Yes Tied-to: From Well Ref. Point Field: Milne Point North Slope UNITED STATES Map Syste-rl~S State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumiVAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: M Pt F Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6029958.49 ft Latitude: 70 29 34.438 N From: Map Easting: 531814.44 ft Longitude: 149 44 23.616 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.25 deg Well: Plan MPF-99 Slot Name: Well Position: +N/-S 5650.31 ft Northing: 6035652.36 ft Latitude: 70 30 29.937 N +E/-W10322.82 ft Easting : 542111.97 ft Longitude: 149 39 19.588 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 4795.39 4544.50 13.375 17.500 13 3/8" 7898.70 6724.50 9.625 12.250 9 5/8" 9212.91 7249.34 7.000 8.500 7" Formations MD TVD Formations. Lithology Dip Angle Dip Direction ft ft deg deg 1949.12 1894.50 BPRF 0.00 0.00 3651.80 3494.50 TUZC 0.00 0.00 4205.17 4014.50 SBF1-NB 0.00 0.00 4333.31 4134.50 OA 0.00 0.00 4665.71 4434.50 Deepest SBF sand 0.00 0.00 7811.06 6689.50 BHRZ 0.00 0.00 7898.70 6724.50 KLGM (truncated?) 0.00 0.00 8249.26 6864.50 TKUD 0.00 0.00 8574.79 6994.50 TKC1 0.00 0.00 8574.79 6994.50 TKUB 0.00 0.00 8674.95 7034.50 TKUA 0.00 0.00 8699.99 7044.50 TKA3 0.00 0.00 8750.07 7064.50 TKA2 0.00 0.00 8817.68 7091.50 TKA1 0.00 0.00 8962.91 7149.50 TMLV 0.00 0.00 Targets Map Map ` <---- Latitude ---- > <--- Longitude --- Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPF-100 T1 Rev2 6724.50 -3032.00 -887.87 6032615.67 541241.39 70 30 0.118 N 149 39 45.726 W -Plan hit target MPF-100 T2Rev 1 7149.50 -3974.22 -634.59 6031675.00 541499.98 70 29 50.851 N 149 39 38.268 W -Plan hit target S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/30/2006 Time: 11:09:16 Page: 2 Field: Milne Point C o-ordinate( NE) Reference: Well: Plan MPF-99, True North Site: M Pt F Pad Vertical (TV D) Reference: 34. 5K6+10GL 44.5 Well: Plan MPF-99 Section (VS) Referenc e: Well {O.OON,O.OOE,1 87.81Azi) Wellpath: MPF-99 S urvey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ftdeg/100 ftdeg/100ft deg 34.50 0.00 0.00 34.50 0.00 0.00 0.00 0.00 0.00 0.00 244.50 0.00 0.00 244.50 0.00 0.00 0.00 0.00 0.00 0.00 444.50 5.00 120.00 444.25 -4.36 7.55 2.50 2.50 0.00 120.00 644.50 10.00 120.00 642.47 -17.41 30.15 2.50 2.50 0.00 0.00 844.50 15.00 120.00 837.67 -39.05 67.63 2.50 2.50 0.00 0.00 1656.10 20.00 190.00 1619.15 -230.25 135.19 2.50 0.62 8.62 112.06 4237.10 20.00 190.00 4044.50 -1099.59 -18.09 0.00 0.00 0.00 0.00 4847.76 35.75 232.26 4587.45 -1314.89 -179.77 4.00 2.58 6.92 71.86 6150.08 35.75 232.26 5644.34 -1780.60 -781.54 0.00 0.00 0.00 0.00 7598.70 66.46 164.95 6604.69 -2766.39 -959.26 4.00 2.12 -4.65 -86.37 7898.70 66.46 164.95 6724.50 -3032.00 -887.87 0.00 0.00 0.00 0.00 MPF-100 T1Rev2 8962.91 66.46 164.95 7149.50 -3974.22 -634.59 0.00 0.00 0.00 0.00 MPF-100 T2Rev 1 9212.91 66.46 164.95 7249.34 -4195.56 -575.09 0.00 0.00 0.00 0.00 Survey MD incL Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg ..deg ft #t ft ft ft deg/100ft ft ft 34.50 0.00 0.00 34.50 -10.00 0.00 0.00 0.00 0.00 6035652.36 542111.97 MWD+IFR 100.00 0.00 0.00 100.00 55.50 0.00 0.00 0.00 0.00 6035652.36 542111.97 MWD+IFR 200.00 0.00 0.00 200.00 155.50 0.00 0.00 0.00 0.00 6035652.36 542111.97 MWD+IFR 244.50 0.00 0.00 244.50 200.00 0.00 0.00 0.00 0.00 6035652.36 542111.97 Start Dir 2. 300.00 1.39 120.00 299.99 255.49 0.25 -0.34 0.58 2.50 6035652.03 542112.55 MWD+IFR 400.00 3.89 120.00 399.88 355.38 1.99 -2.64 4.57 2.50 6035649.75 542116.55 MWD+IFR 444.50 5.00 120.00 444.25 399.75 3.29 -4.36 7.55 2.50 6035648.04 542119.55 MWD+IFR 500.00 6.39 120.00 499.47 454.97 5.37 -7.11 12.32 2.50 6035645.32 542124.33 MWD+IFR 600.00 8.89 120.00 598.58 554.08 10.39 -13.76 23.83 2.50 6035638.74 542135.88 MWD+IFR 644.50 10.00 120.00 642.47 597.97 13.15 -17.41 30.15 2.50 6035635.12 542142.22 MWD+IFR 700.00 11.39 120.00 697.01 652.51 17.04 -22.56 39.07 2.50 6035630.03 542151.17 MWD+IFR 800.00 13.89 120.00 794.58 750.08 25.31 -33.50 58.02 2.50 6035619.20 542170.17 MWD+IFR 844.50 15.00 120.00 837.67 793.17 29.50 -39.05 67.63 2.50 6035613.70 542179.81 MWD+IFR 900.00 14.53 125.13 891.34 846.84 35.41 -46.65 79.55 2.50 6035606.17 542191.77 MWD+IFR 1000.00 14.00 135.05 988.27 943.77 48.49 -62.43 98.36 2.50 6035590.49 542210.67 MWD+IFR 1100.00 13.89 145.43 1085.34 1040.84 64.69 -80.88 113.72 2.50 6035572.13 542226.13 MWD+IFR 1200.00 14.22 155.64 1182.36 1137.86 83.96 -101.96 125.60 2.50 6035551.12 542238.13 MWD+IFR 1300.00 14.96 165.14 1279.14 1234.64 106.28 -125.64 133.98 2.50 6035527.50 542246.64 MWD+IFR 1400.00 16.05 173.57 1375.51 1331.01 131.59 -151.85 138.84 2.50 6035501.31 542251.65 MWD+IFR 1500.00 17.43 180.83 1471.29 1426.79 159.86 -180.57 140.17 2.50 6035472.61 542253.15 MWD+IFR 1600.00 19.02 186.98 1566.27 1521.77 191.02 -211.72 137.97 2.50 6035441.44 542251.13 MWD+IFR 1656.10 20.00 190.00 1619.15 1574.65 209.75 -230.25 135.19 2.50 6035422.91 542248.45 End Dir : 1 1700.00 20.00 190.00 1660.41 1615.91 224.76 -245.03 132.59 0.00 6035408.11 542245.93 MWD+IFR 1800.00 20.00 190.00 1754.38 1709.88 258.93 -278.72 126.65 0.00 6035374.39 542240.18 MWD+IFR 1900.00 20.00 190.00 1848.34 1803.84 293.11 -312.40 120.71 0.00 6035340.68 542234.44 MWD+IFR 1949.12 20.00 190.00 1894.50 1850.00 309.90 -328.94 117.79 0.00 6035324.12 542231.61 BPRF 2000.00 20.00 190.00 1942.31 1897.81 327.29 -346.08 114.77 0.00 6035306.97 542228.69 MWD+IFR 2100.00 20.00 190.00 2036.28 1991.78 361.46 -379.76 108.83 0.00 6035273.26 542222.94 MWD+IFR 2200.00 20.00 190.00 2130.25 2085.75 395.64 -413.44 102,89 0.00 6035239.55 542217.19 MWD+IFR 2300.00 20.00 190.00 2224.22 2179.72 429.82 -447.13 96.95 0.00 6035205.83 542211.45 MWD+IFR 2400.00 20.00 190.00 2318.19 2273.69 464.00 -480.81 91.01 0.00 6035172.12 542205.70 MWD+IFR 2500.00 20.00 190.00 2412.16 2367.66 498.17 -514.49 85.07 0.00 6035138.41 542199.95 MWD+IFR 2600.00 20.00 190.00 2506.13 2461.63 532.35 -548.17 79.13 0.00 6035104.70 542194.20 MWD+IFR 2700.00 20.00 190.00 2600.10 2555.60 566.53 -581.86 73.20 0.00 6035070.98 542188.46 MWD+IFR 2800.00 20.00 190.00 2694.07 2649.57 600.70 -615.54 67.26 0.00 6035037.27 542182.71 MWD+IFR 2900.00 20.00 190.00 2788.04 2743.54 634.88 -649.22 61.32 0.00 6035003.56 542176.96 MWD+IFR 3000.00 20.00 190.00 2882.01 2837.51 669.06 -682.90 55.38 0.00 6034969.85 542171.21 MWD+IFR 3100.00 20.00 190.00 2975.98 2931.48 703.23 -716.59 49.44 0.00 6034936.14 542165.47 MWD+IFR ment S err -Sun P Y BP Planning Report Company: BP Amoco Field: Milne Point Site: M PtF Pad Well: Plan MPF-99 Wellpath: MPF-99 Survey MD Incl Azim ft deg deg 3200.00 20.00 190.00 3300.00 20.00 190.00 3400.00 20.00 190.00 3500.00 20.00 190.00 3600.00 20.00 190.00 3651.80 20.00 190.00 3700.00 20.00 190.00 3800.00 20.00 190.00 3900.00 20.00 190.00 4000.00 20.00 190.00 4100.00 20.00 190.00 4200.00 20.00 190.00 4205.17 20.00 190.00 4237.10 20.00 190.00 4300.00 20.91 196.71 4333.31 21.50 200.02 4400.00 22.85 206.12 4500.00 25.25 213.99 4600.00 27.99 220.49 4665.71 29.94 224.14 4700.00 30.99 225.88 4795.39 34.03 230.18 4800.00 34.48 230.37 4847.76 35.75 232.26 4900.00 35.75 232.26 5000.00 35.75 232.26 5100.00 35.75 232.26 5200.00 35.75 232.26 5300.00 35.75 232.26 5400.00 35.75 232.26 5500.00 35.75 232.26 5600.00 35.75 232.26 5700.00 35.75 232.26 5800.00 35.75 232.26 5900.00 35.75 232.26 6000.00 35.75 232.26 6100.00 35.75 232.26 6150.08 35.75 232.26 6200.00 35.93 228.87 6300.00 36.56 222.18 6400.00 37.55 215.75 6500.00 38.88 209.65 6600.00 40.50 203.92 6700.00 42.39 198.59 6800.00 44.50 193.65 6900.00 46.82 189.08 7000.00 49.30 184.86 7100.00 51.92 180.96 7200.00 54.66 177.32 7300.00 57.51 173.94 7400.00 60.44 170.76 7500.00 63.44 167.76 TVD ft 3069.94 3163.91 3257.88 3351.85 3445.82 3494.50 3539.79 3633.76 3727.73 3821.70 3915.67 4009.64 4014.50 4044.50 4103.44 4134.50 4196.26 4287.60 4377.01 4434.50 4464.06 4544.50 4548.31 4587.45 4629.85 4711.00 4792.16 4873.31 4954.47 5035.62 5116.77 5197.93 5279.08 5360.24 5441.39 5522.55 5603.70 5644.34 5684.82 5765.50 5845.33 5923.93 6000.91 6075.89 6148.51 6218.41 6285.26 6348.73 6408.52 6464.31 6515.86 6562.90 Svs TVD ft 3025.44 3119.41 3213.38 3307.35 3401.32 3450.00 3495.29 3589.26 3683.23 3777.20 3871.17 3965.14 3970.00 4000.00 4058.94 4090.00 4151.76 4243.10 4332.51 4390.00 4419.56 4500.00 4503.81 4542.95 4585,35 4666.50 4747.66 4828.81 4909.97 4991.12 5072.27 5153.43 5234.58 5315.74 5396.89 5478.05 5559.20 5599.84 5640.32 5721.00 5800.83 5879.43 5956.41 6031.39 6104.01 6173.91 6240.76 6304.23 6364.02 6419.81 6471.36 6518.40 Date: 10/30/2006 Time: 11:09:16 Page: 3 Co-ordinate(NE) Reference: Well: Plan MPF-99, True North Vertical (TVD) Reference: 34.5KB+10GL44.5 Section (VS) Reference: Well (O.OON,O.OOE,187.81Azi) Survey Calculation Method: Minimum Curvature Db: Oracle VS N/S ft ft 737.41 -750.27 771.59 -783.95 805.76 -817.63 839.94 -851.32 874.12 -885.00 891.82 -902.45 908.30 -918.68 942.47 -952.36 976.65 -986.05 1010.83 -1019.73 1045.00 -1053.41 1079.18 -1087.09 1080.95 -1088.84 1091.86 -1099.59 1113.70 -1120.94 1125.54 -1132.37 1149.78 -1155.48 1187.37 -1190.61 1226.27 -1226.15 1252.46 -1249.65 1266.31 -1261.94 1305.37 -1296.14 1307.28 -1297.79 1327.12 -1314.89 1348.91 -1333.57 1390.61 -1369.33 1432.32 -1405.09 1474.02 -1440.85 1515.72 -1476.61 1557.43 -1512.37 1599.13 -1548.13 1640.84 -1583.89 1682.54 -1619.65 1724.24 -1655.41 1765.95 -1691.17 1807.65 -1726.93 1849.36 -1762.69 1870.24 -1780.60 1891.70 -1799.16 1938.42 -1840.55 1989.94 -1887.37 2046.01 -1939.40 2106.37 -1996.38 2170.70 -2058.04 2238.70 -2124.07 2310.05 -2194.16 2384.38 -2267.96 2461.34 -2345.11 2540.56 -2425.24 2621.65 -2507.95 2704.21 -2592.85 2787.84 -2679.52 E/W ft 43.50 37.56 31.62 25.68 19.74 16.67 13.80 7.87 1.93 -4.01 -9.95 -15.89 -16.20 -18.09 -23.19 -26.99 -36.88 -57.36 -84.53 -105.97 -118.27 -156.42 -158.40 -179.77 -203.91 -250.12 -296.33 -342.53 -388.74 -434.95 -481.16 -527.37 -573.57 -619.78 -665.99 -712.20 -758.40 DLS MapN deg/100ft ft 0.00 6034902.42 0.00 6034868.71 0.00 6034835.00 0.00 6034801.29 0.00 6034767.57 0.00 6034750.11 0.00 6034733.86 0.00 6034700.15 0.00 6034666.44 0.00 6034632.73 0.00 6034599.01 0.00 6034565.30 0.00 6034563.56 0.00 6034552:79 4.00 6034531.42 4.00 6034519.97 4.00 6034496.80 4.00 6034461.56 4.00 6034425.87 4.00 6034402.25 4.00 6034389.90 4.00 6034355.48 4.00 6034353.82 4.00 6034336.60 0.00 6034317.79 0.00 6034281.77 0.00 6034245.75 0.00 6034209.73 0.00 6034173.71 0.00 6034137.70 0.00 6034101.68 0.00 6034065.66 0.00 6034029.64 0.00 6033993.62 0.00 6033957.60 0.00 6033921.59 0.00 6033885.57 -781.54 0.00 6033867.53 -804.11 4.00 6033848.84 -846.22 4.00 6033807.22 -884.04 4.00 6033760.19 -917.38 4.00 6033707.98 -946.08 4.00 6033650.85 -970.00 4.00 6033589.06 -989.03 4.00 6033522.93 -1003.06 4.00 6033452.77 -1012.03 4.00 6033378.93 -1015.91 4.00 6033301.76 -1014.66 4.00 6033221.65 -1008.30 4.00 6033138.98 -996.85 4.00 6033054.15 -980.38 4.00 6032967.59 :YIapE 'Tool/Co e ft 542159.72 MWD+IFR 542153.97 MWD+IFR 542148.22 MWD+IFR S 542142.48 MWD+IFR S 542136.73 MWD+IFR 542133.75 TUZC 542130.98 MWD+IFR 542125.23 MWD+IFR 542119.49 MWD+IFR S 542113.74 MWD+IFR 542107.99 MWD+IFR S 542102.24 MWD+IFR S 542101.95 SBF1-NB 542100.11 Start Dir 4 / 0 542095.14 MWD+IFR S 542091.40 OA 542081.65 MWD+IFR S 542061.37 MWD+IFR 542034.40 MWD+IFR 542013.09 Deepest S s 542000.87 MWD+IFR 541962.92 13 3/8" 541960.94 MWD+IFR 541939.67 End Dir 7 541915.64 MWD+IFR 541869.64 MWD+IFR 541823.64 MWD+IFR 541777.64 MWD+IFR 541731.64 MWD+IFR 541685.64 MWD+IFR 541639.64 MWD+IFR S 541593.64 MWD+IFR 541547.64 MWD+IFR S 541501.64 MWD+IFR S 541455,64 MWD+IFR 541409,64 MWD+IFR S 541363.64 MWD+IFR S 541340.61 Start Dir 541318.15 MWD+IFI 541276.27 MWD+IFI 541238.73 MWD+IFI 541205.68 MWD+IFl 541177.31 MWD+IFI 541153.74 MWD+IFI 541135.10 MWD+IFI 541121.46 MWD+IFI 541112.91 MWD+IFI 541109.47 MWD+IFI 541111.18 MWD+IFI 541118.01 MWD+IFI 541129.93 MWD+IFI 541146.90 MWD+IFI nt to S err -Sun A Y BP Planning Report Company: BP AmoCO Date: 10!30(2006 'time: 11:09:16 Page: 4 Field: Mil ne Point Co-ordi nate( NE) Refer ence: Well: Plan MPF-99, True North Site: M Pt F Pad Vertical (TV D) Reference: 34. 5K8+10GL 44.5 Well: Pla n MPF-99 Section (V S) Reference: Well (O.OON,O.OOE,1 87.81Azi) W'ellpath: MP F-99 Survev Calculation Method: Minimum Curvature Dh: Oracle Survev MD Inc! Azim TVD Sys "CVD VS ~TIS E/W DLS MapN MapE "fool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 7598.70 66.46 164 .95 6604 .69 6560.19 2871.03 -2766. 39 -959.26 4.00 6032880.85 541168.50 End Dir 7600.00 66.46 164 .95 6605 .21 6560.71 2872.13 -2767. 54 -958.95 0.00 6032879.70 541168.81 MWD+IFR 7700.00 66.46 164 .95 6645 .15 6600.65 2956.61 -2856. 08 -935.16 0.00 6032791.31 541193.11 MWD+IFR 7800.00 66.46 164 .95 6685 .08 6640.58 3041.10 -2944. 61 -911.36 0.00 6032702.92 541217.41 MWD+IFR 7811.06 66.46 164 .95 6689 .50 6645.00 3050.44 -2954. 40 -908.72 0.00 6032693.14 541220.10 BHRZ 7898.70 66.46 164 .95 6724 .50 6680.00 3124.48 -3032. 00 -887.87 0.00 6032615.67 541241.39 MPF-100 1 7900.00 66.46 164 .95 6725 .02 6680.52 3125.58 -3033. 15 -887.56 0.00 6032614.53 541241.71 MWD+IFR 8000.00 66.46 164 .95 6764 .95 6720.45 3210.07 -3121. 69 -863.76 0.00 6032526.13 541266.01 MWD+IFR 8100.00 66.46 164 .95 6804 .89 6760.39 3294.55 -3210. 22 -839.96 0.00 6032437.74 541290.30 MWD+IFR 8200.00 66.46 164 .95 6844 .83 6800.33 3379.04 -3298. 76 -816.16 0.00 6032349.35 541314.60 MWD+IFR 8249.26 66.46 164 .95 6864 .50 6820.00 3420.66 -3342. 38 -804.43 0.00 6032305.81 541326.57 TKUD 8300.00 66.46 164 .95 6884 .76 6840.26 3463.52 -3387. 30 -792.36 0.00 6032260.96 541338.90 MWD+IFR 8400.00 66.46 164 .95 6924 .70 6880.20 3548.00 -3475. 83 -768.56 0.00 6032172.57 541363.20 MWD+IFR 8500.00 66.46 164 .95 6964 .63 6920.13 3632.49 -3564. 37 -744.76 0.00 6032084.18 541387.50 MWD+IFR 8574.79 66.46 164 .95 6994 .50 6950.00 3695.67 -3630. 58 -726.96 0.00 6032018.07 541405.67 TKUB 8600.00 66.46 164 .95 7004 .57 6960.07 3716.97 -3652. 91 -720.96 0.00 6031995.78 541411.80 MWD+IFR 8674.95 66.46 164 .95 7034 .50 6990.00 3780.29 -3719. 26 -703.12 0.00 6031929.54 541430.01 TKUA 8699.99 66.46 164 .95 7044 .50 7000.00 3801.45 -3741. 43 -697.17 0.00 6031907.40 541436.09 TKA3 8700.00 66.46 164 .95 7044 .50 7000.00 3801.46 -3741. 44 -697.16 0.00 6031907.39 541436.10 MWD+IFR 8750.07 66.46 164 .95 7064 .50 7020.00 3843.76 -3785. 77 -685.25 0.00 6031863.13 541448.26 TKA2 8800.00 66.46 164 .95 7084 .44 7039.94 3885.94 -3829. 98 -673.36 0.00 6031819.00 541460.39 MWD+IFR 8817.68 66.46 164 .95 7091 .50 7047.00 3900.88 -3845. 63 -669.16 0.00 6031803.37 541464.69 TKA1 8900.00 66.46 164 .95 7124 .38 7079.88 3970.43 -3918. 52 -649.56 0.00 6031730.61 541484.69 MWD+IFR 8962.91 66.46 164 .95 7149 .50 7105.00 4023.58 -3974. 22 -634.59 0.00 6031675.00 541499.98 MPF-100 9000.00 66.46 164 .95 7164 .31 7119.81 4054.91 -4007. 05 -625.76 0.00 6031642.22 541508.99 MWD+IFR 9100.00 66.46 164 .95 7204 .25 7159.75 4139.40 -4095. 59 -601.97 0.00 6031553.83 541533.29 MWD+IFR 9200.00 66.46 164 .95 7244 .18 7199.68 4223.88 -4184. 13 -578.17 0.00 6031465.43 541557.59 MWD+IFR - 9212.91 66.46 164 .95 7249 .34• 7204.84 4234.79 -4195. 56 -575.09 0.00 6031454.02 541560.73 7" nent 2ev2 3 tev 1 3 Wli.l-uh"knits AN"rl-COLLISION SETTINGS 1'uhlrnnr uel,ws suxvba'rHCx~Hnhf Nwnc •61-5 ~1r-W Mxlhwp liuun% l aulwk I.nlexwk Sl:n Inleryolalion Me1huJ:MD Inien~al: 50.00 Itl'Aln•w~~ Ilc~lh l-m Ikptl1 l .. ~ cr I'lun I~n~l Ilan nll'I'`w cGSU.JI In322.%2 filli5fi4.W W211197 7u°iuyv Ji]N Nti'W'IY.i%xW NA Depkh RJllge From: 33.$0 To: 9?12.91 1-alaUaon hleanvl: hUminwn llu~:elm~ +JSU 421291 I'lanual: All'f!rv \\p JU V._ AI\\U IRFMS \laxinmm Range: 1117.dJ RCkC~CI1Ce : flan: MPFA9 N~p 3.0 Pmrt 51~a.1n~. Isr0.5a n M.nbwl: I ray l rluxlcr N.~nh I mrt 51VIScC. L:IlipO.al ~ Cssing tt';1minE Mcnurl'. KuIc. IUxJ ~C W'I~I.I.I'A I II UI~:IAII 16O F~5`~~ From Colour To MD b°~I`00 15O ~~ 35 3800 H'% Kci: I):num: W.!KH~IIn.I iJ iUl1 ;~~~ 400() 33 U 4000 4250 c~.'.II,,.. un%.n «%%r sl lnl~l% 4250 4500 Ix]xl I,I,II n1Xl 3}311 4500 4750 125 4750 5000 ~ ~ 5000 5250 q 5250 5500 ~ 5500 5750 ~~ 5750 6000 n ' NI 1OO 6000 6250 M1III IAII I' III. Al I I< k ~ _ 625() - 6500 Alll I] M1II I-I ]l. hl l I<:k 1 1 ' ~' ~~k ^I 6~0~ ._- ..- - 6750 MII-1] lti~k 1 1.1 MI I -I]Al. lri J All I MI1 II. M I I< k ~ 675(] ~ 7000 Alll t IAlll til.M I H.k MII ii (M1III t{AI Al I IXI-+k ~ 75 \ ~ M1III i Atl1 i]I.MI It .k ~ M1III J I I M1II I J I I. M I It k \ MI I i IMI I J A A7 I I< k ~ ` , ~ M1II I J M1II I -1 1, hi I I< k 1.11 I t M1II 1 Ix AI I It k ~~. ~ M1III II Afl l-~ II M1I ~~r Kiik \ ~ ~A ~ M1III J All I ~i 1. M I k k ~ hlll All I<71. Af l It.k Alll ] AII I'i] M K k 0 , ~ ~~ . AI i. I I Riik Ll fl \O ~ MII x All I'A% l K..k M ~1 ---- MI'I--nI IMI'kJil 1. Ma1~~1 IXl.k ~ T M1III ( All 1 I. M111 H.k I I I I ~ ~ Ksl A71I \ AII I \ Ai AIII (All l-~ M 1 H.k 25 /-1 ` yy ~ All I ( I lil Ail I NI I{II hl ~n Itl.k 4G r K Alll All I-7NI.M I K.k ~^, /~ I ~ All l-:1 Ail'I-]i1. A1:~PrKnk I$ ~' ~ ~ All`r-'i lAil'I-]I.A I. AI:~/.~r K1il. (y ~ ~ All'I'-'i lAll'I-~'IAI'IfI I. Alaya kl.k L' ~ AfI'I'-'r lAll'k-'1:11'It_I. M:!1"r K1.k ' ~ All`r-'J lhll'1-7JI. MaI~~r H1.k ~ All'I'-i)IAII'I'-']I A1aP~r K1.k l/ 0 270 ~ `J 90 ~ MIT-1x fAil'1-7x1, Mnya ltuk All'I aIi1Ml'I-I1; I. AI~Xm Nuk f All'I-IilAll•I-1 il. Al:~pm Hi.k --- Ail'1-li lAll'I-ii,, Alan'r Ki:A - All'i ~1•I - nu'k ~nl Wx J,. `~.. ~ / ~ . 0 . ; ~~ ~~ ~ ~ ~ t ~k` f ~ '. _ j ; ~~ ~ 75 , r, 2 - ~" 120 6 1 ~ j n~ .~ i ~ i 100 ~~ Pre Plans Removed. See AC Scan for Plan s Parents Profile ~ No Errors 125 ' - 51:1 I IUN UC I All S - ~~i MI) In. An Ihl1 N ~ S I~;-W I)I..~ Il:i~e \'S.1 I~rpel 21 50 I WSO 11.1X1 111X1 iJ.SU 11.1 111 II,OU ILINI ILIN) IIJNI ~. 211.iU 11.1X1 V.1111 2ii.SU U.I N1 IL1NI ILUII OAIU ILINI 150 - 1 JJ3 III ~fNl 12U.IMI cU III UII 12U1XI 1 (Ni JJJ.ZS G12 i7 -7_IG 7.5< i,tll 12U.IX1 1?Y 11 ill ~U U INI Ii -17 15 l~ 2 . . xiJ.~U I~.INI 1211 IXI . %3].fi7 . . . . . -iY.11K fi7.fil 2.311 U,IXI 2Y.5n 160 G IGCfi.IU .11.011 1911.1X1 ] J2i] III 2111X1 14111X1 1619.15 31141.511 -2311.2 13t.1Y 2.G0 I121K~ 2UY.75 -IIW Y Sy -I%.IW II.IXI 11.1X1 IIIYI.M6 1 80 . J%J7.7G 35'5 232.2E J5%735 , -111J %Y 17`1.77 JIxI 71.W: 1127.12 O Y GI ~II11% iC.75 21?.2(r ~(rli.W -17%11.(.11 -7x LSi II IXI II IXI I%711.21 111 ]iy%,]11 (x~.JG I(rJ-YS (xN41.6Y -2](x_39 !1Cy,26 J.UI -ilG.l] 2%]I 11,3 L3 •_-~~' ~ Travelling ylinder Azimuth (TFO+AZI) [d g] vs Centre o Centre Sep rati II 7%I%711 (~(~q( I.I.yS 12 %'162 YI (x~i( 11.1 `i5 II 9212 YI (x~i( IM.YS on [SOft/in] (7 Jt0 71i1.5U ]3Y tl -NIi xl %%7 %7 O.INI II XI t12i.J% MI'I-IIN111Rei2 -iyli _' {WXY II.INI nlXl iUji.S% MI'k-1111112Rctl -114..56 ~]t IW 111X1 II UII J2.W.7`1 S err -Sun P Y Anticollision Report Company: BP Amoco Date: 10!30/2006 Time: 11:10:07 Page: 1 Field: Milne Point Reference Site: M Pt F Pad Co-ordinate(NE) Re ference: Well: Pla n MPF-99, True North Reference Well: PIanMPF-99 Vertical ( TVD) Refe rence: 34.5K6+ 10GL44.5 Reference WellpatlldPF-99 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Meth o~V1D Interval: 50.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 34.50 to 9212.91 ft Scan Method: Trav Cylinder North Maximum Radius:1 117.84 ft Erro r Surface : Ellipse+Casing Survey Program fo r Definitive Wellpath Date: 9/26/2006 Validated: No Version: 1 Planned From To Survey Toolcode Tool N ame ft ft 34.50 9212.91 Planned: MPF-99 Wp 4.0 V22 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD' Diameter Hole'Size Name ft ff ' in in 4795.39 4544.50 13.375 17.500 13 3/8" 7898.70 6724.50 9.625 12.250 9 5/8" 9212.91 7249.34 7.000 8.500 7" Summary <-- --------- --------- Offset Wellpath -------- ------------> Reference Offsef- Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distanc e Area` Deviation Warning:. ft ft ft ft fE M Pt F Pad MPF-05 MPF-05 V5 2325.28 2200.00 435.96 36.81 399.15 Pass: Major Risk M Pt F Pad MPF-17 MPF-17 V17 2032.96 2000.00 367.07 38.94 328.13 Pass: Major Risk M Pt F Pad MPF-17 plan MPF-17 SST VO Pla 2031.89 2000.00 367.03 38.87 328.16 Pass: Major Risk M Pt F Pad MPF-17 Plan MPF-17A VO Plan: 2031.89 2000.00 367.03 38.91 328.11 Pass: Major Risk M Pt F Pad MPF-29 MPF-29 V1 1727.43 1650.00 388.35 25.03 363.33 Pass: Major Risk M Pt F Pad MPF-33 MPF-33 V1 2057.73 2000.00 318.06 32.87 285.19 Pass: Major Risk M Pt F Pad MPF-33 MPF-33A V3 2057.73 2000.00 318.06 32.87 285.19 Pass: Major Risk M Pt F Pad MPF-37 MPF-37 V1 493.35 500.00 330.94 7.96 322.98 Pass: Major Risk M Pt F Pad MPF-41 MPF-41 V3 1592.18 1600.00 130.94 26.06 104.88 Pass: Major Risk M Pt F Pad MPF-45 MPF-45 V3 396.55 400.00 270.92 5.96 264.95 Pass: Major Risk M Pt F Pad MPF-49 MPF-49 V7 1585.49 1600.00 37.74 25.82 11.93 Pass: Major Risk M Pt F Pad MPF-53 MPF-53 V1 495.65 500.00 211.59 8.02 203.56 Pass: Major Risk M Pt F Pad MPF-53OH MPF-53OH V1 495.53 500.00 210.46 7.51 202.95 Pass: Major Risk M Pt F Pad MPF-54 MPF-54 V3 262.38 250.00 238.02 4.13 233.89 Pass: Major Risk M Pt F Pad MPF-57 MPF-57 V8 1486.13 1500.00 105.52 23.41 82.12 Pass: Major Risk M Pt F Pad MPF-57 MPF-57A V10 1481.78 1500.00 105.20 23.17 82.04 Pass: Major Risk M Pt F Pad MPF-57 MPF-57APB1 V7 1481.78 1500.00 105.20 23.06 82.15 Pass: Major Risk M Pt F Pad MPF-58 MPF-58 V1 310.18 300.00 211.96 5.48 206.48 Pass: Major Risk M Pt F Pad MPF-61 MPF-61 V1 593.00 600.00 146.84 9.55 137.29 Pass: Major Risk M Pt F Pad MPF-62 MPF-62 V1 294.75 300.00 187.18 4.90 182.27 Pass: Major Risk M Pt F Pad MPF-65 MPF-65 V5 1291.92 1300.00 119.59 20.09 99.50 Pass: Major Risk M Pt F Pad MPF-66A MPF-66A V8 357.20 350.00 162.40 5.57 156.83 Pass: Major Risk M Pt F Pad MPF-66 MPF-66 V12 309.70 300.00 161.62 5.62 156.01 Pass: Major Risk M Pt F Pad MPF-66P61 MPF-66P81 V5 309.70 300.00 161.62 5.62 156.01 Pass: Major Risk M Pt F Pad MPF-69 MPF-69 V1 445.09 450.00 89.89 6.54 83.35 Pass: Major Risk M Pt F Pad MPF-70 MPF-70 V1 294.79 300.00 143.11 4.91 138.20 Pass: Major Risk M Pt F Pad MPF-73 MPF-73 V15 600.58 600.00 57.94 9.79 48.15 Pass: Major Risk M Pt F Pad MPF-73 MPF-73A V2 599.89 600.00 57.93 9.78 48.16 Pass: Major Risk M Pt F Pad MPF-73 MPF-73AP61 V23 599.89 600.00 57.93 9.51 48.42 Pass: Major Risk M Pt F Pad MPF-73 MPF-73AP62 V1 599.89 600.00 57.93 9.78 48.16 Pass: Major Risk M Pt F Pad MPF-74 MPF-74 V1 348.23 350.00 126.15 5.65 120.50 Pass: Major Risk M Pt F Pad MPF-77 MPF-77 V1 581.86 600.00 10.04 9.46 0.58 Pass: Major Risk M Pt F Pad MPF-78 MPF-78 V1 262.40 250.00 114.84 4.64 110.21 Pass: Major Risk M Pt F Pad MPF-96 Plan MPF-96 V4 Plan: M 8662.50 8400.00 34.61 121.04 -86.44 FAIL: Major Risk M Pt F Pad Plan MPF-01 F PAd TdNPF-01 Pad Test VO Pla 8955.60 8375.89 18.64 8669.41 -8650.77 FAIL: Major Risk M Pt L Pad MPL-03 MPL-03 V1 7500.52 7850.00 167.10 146.38 20.73 Pass: Major Risk M Pt L Pad MPL-13 MPL-13 V1 4500.00 6200.00 549.08 362.63 186.45 Pass: Major Risk M Pt L Pad MPL-33 MPL-33 V4 5111.26 6450.00 264.94 194.00 70.94 Pass: Major Risk M Pt L Pad MPL-38 Plan MPL-38 V1 Plan: M 9155.65 10468.31 29.57 161.79 -132.22 FAIL: Major Risk - -- _ __ Sondra D. Stewman as-snzsz 14 BP Exploration AK INC. "Mastercard Check" PO Box 196612 MB 7-5 Anchorage, AK 99519-6612 DATE ~ ~~ y~ PAY TO THE ~ $ (~y~ i ~('~ ORDER OF 6~~..//~~ ~/ First Nationa~"ank Alaska Anc-horage, AK 99501 MEMO OI ~~ ~: L 25 200060:99 146 2 2? L 56411• 0 L49 ~ • FELL NAV>[E /~~ ~' ~~. ~T®~ Zl~ - /-S,rn ®evelopment Service Exp~o~iatory Stratigraphic ~"est ~-t,,.~~ Non-Conventional W"ell Circle Appropriate Letter ;' paragraphs to be Inclaaded in Transmittal [.attar CHECK aDD-Otis TEX~I FOR :-APPROVAL LETTER V~'H.~T (OPTIOti S i APPLES ~iL'LTI LATERAL The permit is for a new weffbore segment of existing well (If last Rvo digits in AP[ number a Permit ti"o. .:CPC ~,`o. gip- _ - - re beRveen 60-69) Production should continue to be reported as a function of the ~~ri~inal .~P[ number stated above. PILOT' HOLE [n accordance with ~0 :-~.aC '~.00~(t), all records, data and logs acquired for the pilot hole mutt be clearly differentiated in both r well name ( PH) and API number (.~0- - - ) from records, data and log; acquired for well SPACh`G ' The permit is approved subject to full compliance with 20 AAC EXCEPTION ?~.0~~. Approval to perforate and produce infect is contingent upon issuance of a eonseryation order appro~ ing a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DR1` D[TCH AI! dr` ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' ;ample intervals from below the permafrost or from where samples are first caught and f 0' sample inters als through target zones. Please note the following special condition of this permit: ion-Conventional ;production or production testing of coat bed methane is not allowed well for iname of well) until after (Company tiame) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Com a~nv tiame) must contact the Commission to obtain advance approval of such water well testin Rev: l 2~. 06 C' iody'trar.~mittal check;ist t ^ ^ ~' ~_ c o- O ~ ~ ~ O N y 01 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N. ~ N N D ~ ~ ~ ~ ~ ~ ~ ~ ~ N O O ~ ~ ~ ~ ~ ~ N. ~ ~ ~ S Y ~ ~: N, _ w ca 2 a Q ~ N' ' ~ ° ~ ~~ ~ ~~ ; ~3 ~`c° ~ : ~ : -O. ~ ~ m •p ~ ~ ~ ~ U, ~ j. ~ ~ ~ N ~ o ~ c ~ Q a~ = .r.. Y m ~ N . O °, : c c c m ~~ 3 a N a c `,, a` >, ' W U o > > •~ a: c: m. ~, Li, ~ , °- ai ° a~ E m ~ O m ~ ~: ~ vi. ~ ~ •~ °, ~ ~ ~ f°, ~ ~~ ~~ w~ •~ °= ~ pp ~ ~~ - ~ ~ c ~ r m c O ~ ~ V t y ~ ~ ~ (6 L ~ O, ~ ~ O. ~ L• N M =~ Y ~ ~ ~ ~~ ~ ~ O 3~ U d ~ M' ~, p. ~: ~ ~ ~, N ~ N, ~ ~ ~ ~ N O ~ ~ C. ~ c. ~ y L 00 ~ ~ Z• ~ ~~ flr ~ ~ ~ ~~ U ~ ~~ ~ -~ ~ N: t6 -O. a' ~ N• ~~ ~ O• ~ Y 0.. '_ - ,,-- U O. ~ W ap U' U' ~ Z ~ ~ ~ U U: N ~ ~ ~ s ~ ~: d. w ~ o. c ~ ~~ •o: c, ai~ o~ ~ ' ~ a ~ ' U. ' a,•. ah c ' ~~ ~ m ° ~ o, M r i, ~ o ~, ~ 0 4 3 °~ a ~ ~ u.; o o m -~ ~ c = o w ~ O ~~ '~, 3 ~ ~ ~ N ~ ~ p: ~ ay ~ _ Y ~ ~, ~~ N. ~ N. N ~ O (Q N 9, N N t/l U O. N w O O• p, a Z Z c O. ~, N. , ~ Z, o N. ~ o, N' ~ ~~ N, O: ~ ~: ~ ~ 'C °~ o ~ ° ~ O aai Q °~ N, o ~ •~ O O. •o-_-- > ; a o ( E ~ ~ -_: v v O' a~ . a ~' O' 3: :; 3, N ' 3, N: a' ar > o, •N: ~ ~, c, n ~ ~, ' N; m >' o N, a> ~ ~ ai N N O, O. ~, o O, QI ~ c O• a; >f N N. U. O, a~ Q _ N. t; ~, ~ Q o E N ai o ? o o. o a~ c' °= c ° x n a' N m' o' C 3' _ 3' N O •o °• rn _ N d', ~, ~~ ~~ ~ ~ ~ U O: ~ ~ ~ ~ U. ~ ~7 ~ f6 ~ O N ~ ~ L, N E, ~ >~> ' ' ` ' cA ' ~ Z c a c ~ o. o ar c' c m, O m, 't ~: O rn m x o. d m. a, ` U N ~ a ~ ~ ~ .a E m Y ~ o ~ ~ Y~ C3 U m ~ Q Z, a: ~ ~ U Z ~ ~ ~ ~ p . m. g~ ~ ~~ ~ ~ 2. ~~ g~ ~~ O. •c, ~ ~ w ~ , , ~ 3 o-Q-oa ~ ; W Y Y ~ N w , i N~ N~ N, N~ N~ N~ qA N, N: N: N N N N N ~ . ~ N N, N, N, N, N, N, N, N, N, , N, G3 ~ Ul N ~ , N, N N N Q N~ t/D tl/ . N N N N ~ O N N, N~ N N N, N~ N~ N, N~ a N Q N N N N N~ N. N N N O N a a a , , , , , , , , , , , , , , , , , , , , , , , , , , , , T N ~ ~ ~ ~ ~ ~ ~ : ~ :~ ; , o. c.~, ~ : „ ~ : z ; 7. v { >' O ~ O ~, : O m M U C' a~, ~ ~ v ~ ~ a°i N. vN, N' , rn ~ ~, a ~, o. N' o. N. ~ n .1 ~ ~ c 7. ~ ~ y O. 'c. o: N. ~ T ~ c• .7, ~~ y. a m. 4 N, ~. ~ C. ~ ~ a' ~: 7, .°. Y Y 09 3. •~ o ~ f6 N ~ ~ , ° ~ N N, ~ ~. ~ o `~' a g 3; ~ ~ v ~ U c. L, ~ , , 'ia' ~ >' o < +~ ~' a' ~ ~ ~ ~ ~ ~' •°' ~ , rv E' m' •m' .Q' a°' O' . •~ ~ ' w N ~' Z ~ U ~~ ' N ° 3' ~ U' c' ~ L. o; C N' ~' ~ ~' 7' ¢ N' ; w N ar ~ O ( ~ o. ~ c. a o: o: c. a m. •a~: ~ ~ ~ c. m ~ m. o, o. rn m N a' ~; ~' ~ ~' c' ` ° a~ a i Q E, E; = a `' c; c ' E ' ~ ~ ~, o M ~' c c ' 3' N •>_ ~' ~' _, ~~ ° `~, °~~ ~ ~ ' c c: a> w; • rn °' noi' ~ ' N n c c o Y w ~ o o ~ w r ~ v ~ ~ o a. U, a ~ ~ c N o o' a o o. m ° c~ .~ ~ a ci ,Q. a~, o, ~ a. O n. 3, o. m ui > ~, ~. >; Y ~ .N Z i ¢ -O. ~ `° _ C. ~ p ~ C. .0., ' a. N• ~ Z f6. _: N fd a. ~ 3 ~ ~ N, (O N, ( ~ L O. Op O, ` ° N ~ •N ~ ~ ~ i a; _, , c c, ~ m ~ ~ t , s a ~ v,; ~ ~ a; ~ ~ ~ a a i i a, a m, , a °, a ° °~ i ' ' - a = ~ 3 m ~ ~ ~ _ °: _ -o , ~+, a. o °: ~~ ~ ~ ~, ~ M. m 3 i o m' >' ' w o ~ a a' ~ m a i a ; ~ ' ~ o o, a 7, ~ ~ a i o U o O o ~' '~ a' a' ~ a °?' fl: ~' ~ ° m. ~~, o c. ° o. o. c. ~ o' o. ' o' N: a, ' ~ m ~ m o ° d ~ ~~ a a ~~ ~: ~ a~ U. ~: °: ~~ $ c ~~ o, o a a ' Y~ a ~ ~ ~ r: °: o, rn °~ o ~~ . m ~, . '~ c' o, N~ ~ p2S t' 4 N: ~ ~. O ~ E N ~ ~~ ~ N Oa N, N~ O. ~: N. U, L N ~ ~ O O. R ~ ~ -, N f6 N• N ~ a ~: C. U O O ~ ~ _ N: a ~ y O N o a ~ U, 6 O. O. : : f6 C N• 3 °. N, f0 .N~ R . ., G , ~ I . N T : ~ N N ~ : _, C O: " 4 ~ ~ N al a a' ' C L O' N, Y = ~. _ : 7, . O• a a ' L O 7 ~.- U O U y. ~, j, a ~, LL d ~~ •Q, -: a' a. a, a~ a~ a ~ U~ m o~ L: t, .Q. .p L_: c°i~ c aai~ N. `~' ~~' a N. >~ a o .~ N :°.' ~ . .., N, L. : 3 ~: :a: o N ~ o o~ m~ L, ~ c c• c ~~ X ~. ~. ~: ~ ~ ~ 3 ca m m ~ .~, c m c~ ° E , ~ 3' ~ a~ m , o; ° m' m' u a~' ° , - _, °, ° a ~' f0' c ~ c: ~ a i N ° ~ ~ F- W (A m. µ- : . , . . c v U U O: O' O O. a~ c o N. ~~ ~ o U' U ~ . U N a' ~', O. v. m. o, o, - ' a m D1 a, m, °~ ~ °- ~ 'C, N. -_: , ?r: . ° ~~ ' °, ° °, a a ~ U• 0- m a~ °: ° a m, %: n ° a~: o ~ U > > 3 ~ O ° a~, w, w ~ ~ N m ai m ~i Y ~ ~i •~ ~ ~ ~, a '' ' ~ b 4 ~; ~, ~ ~ ~ 3: ~ o ' o; ~ ~; ~ ~; m; o °: a, ~ • O O L ' o: a ~ ~ ~ •~, a~i: ' o 0 U c a ~, ~, S , ~ , ~; tn, ~-; O, O, a; a; U ~, a, a, z U, cn, U, U, U, U, a, , m, m, U, -, ¢: -, o ~; N; ~; ~ a, o , cn, cn, U W a ~' ' O r N M V t0 (O I~ O m O r N M ~F t0 f0 1~ W O O r N M V ~O (O f~ O O o r N M~ t! 1 CO -- f~ 00 O r r r r r r r r r r N N N N N N N N N N M M M M M- M M M M M U F ° ° ° a c- C C N o N o w N i I o y N ~ U O 16 ~ p N l6 ~ IQ p ~ p ~ W w ~ r r ~ c ~ N r r ~ y o• a ° -I N N ~ d ~ c7 E O J O ~ E '' a D ~ ' o, v~ ~ O Q O U W a ' s a LL ~ rn w Q w a~ ~ Q~ a~ s • Well I-iistory 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 We!! History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 14 14:31:10 2007 Reel Header Service name .............LISTPE Date .....................07/03/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/03/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-99 API NUMBER: 500292333200 OPERATOR: BP Exploration Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-MAR-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004794046 MW0004794046 MW0004794046 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: J. HABERTHUR J. HABERTHUR J. HABERTHUR MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: MW0004794046 MW0004794046 MW0004794046 LOGGING ENGINEER: O. OBI 0. OBI S. LATZ OPERATOR WITNESS: E. VAUGHN E. VAUGHN J. HABERTHUR MWD RUN 7 JOB NUMBER: MW0004794046 LOGGING ENGINEER: S. LATZ OPERATOR WITNESS: J. HABERTHUR SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: l0E FNL: FSL: 2199 FEL: 2450 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 45.80 GROUND LEVEL: 11.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 16.000 20.000 106.0 2ND STRING 12.250 13.375 4892.0 3RD STRING 8.500 9.625 7954.0 PRODUCTION STRING 6.750 7.000 8670.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). ADDITIONALLY, MWD RUNS 2-4 INCLUDED PRESSURE WHILE DRILLING (PWD) AND MWD RUNS 2 & 4 INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP). AT-BIT GAMMA (ABG), UTILIZING SCINTILLATION DETECTORS, WAS ALSO RUN IN MWD RUN 4. CORING SROP DATA, AND MAD DATA OVER THE CORED INTERVAL (8786'MD-8865'MD) ACQUIRED WHILE RIH FOR MWD RUN 6, WERE MERGED WITH RUN 6 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL DATED 1/31/2007 FROM DOUG DORTCH (SAIC/BP) TO BUSTER BRYANT (SDS), QUOTING AUTHORIZATION FROM MICAELA WEEKS (BP GEOSCIENTIST) MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-7 REPRESENT WELL MPF-99 WITH API#: 50-029-23332-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9I06'MD/7144'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ABG = SMOOTHED GAMMA RAY COMBINED. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 69.5 RPX 100.0 RPM 100.0 RPD 100.0 FET 100.0 RPS 100.0 ROP 108.0 all bit runs merged. STOP DEPTH 9086.0 9093.0 9093.0 9093.0 9093.0 9093.0 9106.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 69.5 4902.0 MWD 2 4902.0 6110.0 MWD 3 6110.0 7958.0 MWD 4 7958.0 8670.0 MWD 5 8670.0 8786.0 MWD 6 8786.0 8872.0 MWD 7 8872.0 9106.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 9106 4587.75 18074 69.5 9106 RPD MWD OHMM 0.08 2000 38.1008 17987 100 9093 RPM MWD OHMM 0.13 RPS MWD OHMM 0.26 RPX MWD OHMM 0.16 FET MWD HOUR 0.13 GR MWD API 21.02 ROP MWD FT/H 0.04 2000 20.5845 17987 100 9093 1691.28 8.34163 17987 100 9093 2000 8.96654 17987 100 9093 111.96 3.98131 17987 100 9093 193.34 83.5913 18034 69.5 9086 1557.32 113.025 17997 108 9106 First Reading For Entire File..........69.5 Last Reading For Entire File...........9106 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 69.5 4860.5 RPD 100.0 4852.5 RPM 100.0 4852.5 RPS 100.0 4852.5 RPX 100.0 4852.5 FET 100.0 4852.5 ROP 108.0 4902.0 LOG HEADER DATA DATE LOGGED: 17-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4902.0 TOP LOG INTERVAL (FT) 107.0 BOTTOM LOG INTERVAL (FT) 4902.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 34.8 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 16.000 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 90.0 MUD PH: 8.2 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3) 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.200 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.590 82.0 MUD FILTRATE AT MT: 2.100 65.0 MUD CAKE AT MT: 3.400 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 4902 2485.75 9666 69.5 4902 RPD MWDO10 OHMM 0.08 2000 24.5467 9506 100 4852.5 RPM MWDO10 OHMM 0.13 2000 16.0131 9506 100 4852.5 RPS MWDO10 OHMM 0.26 114.89 10.4252 9506 100 4852.5 RPX MWDO10 OHMM 0.66 61.6 7.90911 9506 100 4852.5 FET MWDO10 HOUR 0.13 11.79 0.997749 9506 100 4852.5 GR MWD010 API 21.02 115.68 64.9487 9583 69.5 4860.5 ROP MWDO10 FT/H 1.16 1557.32 149.804 9589 108 4902 First Reading For Entire File..........69.5 Last Reading For Entire File...........4902 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 4853.0 6066.5 FET 4853.0 6066.5 RPS 4853.0 6066.5 RPM 4853.0 6066.5 RPX 4853.0 6066.5 GR 4861.0 6074.5 ROP 4902.5 6110.0 LOG HEADER DATA DATE LOGGED: 21-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6110.0 TOP LOG INTERVAL (FT) 4902.0 BOTTOM LOG INTERVAL (FT) 6110.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.7 MAXIMUM ANGLE: 36.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 • DRILLER'S CASING DEPTH (FT) 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 48.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.800 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 96.8 MUD FILTRATE AT MT: 5.300 67.0 MUD CAKE AT MT: 2.200 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4853 6110 5481.5 2515 4853 6110 RPD MWD020 OHMM 0.68 2000 27.4569 2428 4853 6066.5 RPM MWD020 OHMM 0.65 1695.25 6.41327 2428 4853 6066.5 RPS MWD020 OHMM 0.74 1149.25 3.87651 2428 4853 6066.5 RPX MWD020 OHMM 0.82 2000 21.8458 24.28 4853 6066.5 FET MWD020 HOUR 0.24 84.29 4.26785 2428 4853 6066.5 GR MWD020 API 47.47 122.35 96.0371 2428 4861 6074.5 ROP MWD020 FT/H 0.64 675.53 104.821 2416 4902.5 6110 First Reading For Entire File..........4853 Last Reading For Entire File...........6110 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6067.0 7896.0 RPD 6067.0 7896.0 RPS 6067.0 7896.0 RPX 6067.0 7896.0 RPM 6067.0 7896.0 GR 6075.0 7904.0 ROP 6110.5 7958.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7958.0 TOP LOG INTERVAL (FT) 6110.0 BOTTOM LOG INTERVAL (FT) 7958.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.1 MAXIMUM ANGLE: 70.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD030 RPM MWD030 RPS MWD030 RPX MWD030 FET MWD030 GR MWD030 ROP MWD030 Name Service Unit DEPT FT RPD MWD030 OHMM RPM MWD030 OHMM RPS MWD030 OHMM RPX MWD030 OHMM FET MWD030 HOUR GR MWD030 API ROP MWD030 FT/H 300 6.0 • 1.600 68.0 .930 122.0 5.000 68.0 2.100 68.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 6067 7958 7012.5 3783 6067 7958 1.19 7.75 3.24387 3659 6067 7896 1.1 7.32 3.14762 3659 6067 7896 1.13 5.9 3.1269 3659 6067 7896 1.19 6.56 3.11905 3659 6067 7896 0.63 19.55 2.12018 3659 6067 7896 63.36 1 53.25 111.836 3659 6075 7904 0.64 2 04.28 57.9828 3696 6110.5 7958 First Reading For Entire File..........6067 Last Reading For Entire File...........7958 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 7896.5 8624.5 FET 7896.5 8624.5 RPX 7896.5 8624.5 RPM 7896.5 8624.5 RPS 7896.5 8624.5 GR 7904.5 8632.5 ROP 7958.5 8670.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 31-DEC-06 Insite 72.13 Memory 8670.0 7958.0 8670.0 66.0 68.8 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.500 7954.0 Polymer 10.00 48.0 9.2 350 4.9 1.500 67.0 .790 132.8 2.300 67.0 1.000 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7896.5 8670 8283.25 1548 7896.5 8670 RPD MWD040 OHMM 2.64 2000 157.241 1457 7896.5 8624.5 RPM MWD040 OHMM 2.37 2000 19.0765 1457 7896.5 8624.5 RPS MWD040 OHMM 2.17 1375.6 9.61535 1457 7896.5 8624.5 RPX MWD040 OHMM 1.19 1145.02 6.1341 1457 7896.5 8624.5 FET MWD040 HOUR 0.38 101.27 12.6638 1457 7896.5 8624.5 GR MWD040 API 36.44 193.34 118.174 14.57 7904.5 8632.5 ROP MWD040 FT/H 0.39 216.55 72.9442 1424 7958.5 8670 First Reading For Entire File..........7896.5 Last Reading For Entire File...........8670 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... ~ - - ~ ~ • Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8625.0 8772.5 RPX 8625.0 8772.5 FET 8625.0 8772.5 RPS 8625.0 8772.5 RPM 8625.0 8772.5 GR 8633.0 8765.5 ROP 8670.5 8786.0 LOG HEADER DATA DATE LOGGED: 06-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8786.0 TOP LOG INTERVAL (FT) 8670.0 BOTTOM LOG INTERVAL (FT) 8786.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.3 MAXIMUM ANGLE: 69.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8670.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 58.0 MUD PH: •0 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 153.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): • EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8625 8786 8705.5 323 8625 8786 RPD MWD050 OHMM 1.4 2000 452.482 296 8625 8772.5 RPM MWD050 OHMM 2.05 2000 516.081 296 8625 8772.5 RPS MWD050 OHMM 2.8 1691.28 20.1832 296 8625 8772.5 RPX MWD050 OHMM 0.16 32.57 9.02162 296 8625 8772.5 FET MWD050 HOUR 0.16 110.73 37.2627 296 8625 8772.5 GR MWD050 API 38.33 102 74.809 266 8633 8765.5 ROP MWD050 FT/H 0.78 134.13 62.1668 232 8670.5 8786 First Reading For Entire File..........8625 Last Reading For Entire File...........8786 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8766.0 8849.0 RPS 8773.0 8856.0 FET 8773.0 8856.0 RPX 8773.0 8856.0 RPM 8773.0 8856.0 RPD 8773.0 8856.0 ROP 8786.5 8872.0 LOG HEADER DATA DATE LOGGED: 10-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8872.0 TOP LOG INTERVAL (FT) 8786.0 BOTTOM LOG INTERVAL (FT) 8872.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.9 MAXIMUM ANGLE: 72.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8670.0 BOREHOLE CONDITIONS MUD TYPE: Diesel Mud Base MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 170.0 MUD PH: .0 MUD CHLORIDES (PPM): 170.0 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 1 04.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 • Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8766 8872 8819 213 8766 8872 RPD MWD060 OHMM 3.99 20.71 6.66383 167 8773 8856 RPM MWD060 OHMM 3.75 17.28 6.30982 167 8773 8856 RPS MWD060 OHMM 3.69 14.43 5.98317 167 8773 8856 RPX MWD060 OHMM 3.68 13.32 5.91838 167 8773 8856 FET MWD060 HOUR 33.38 111.96 68.095 167 8773 8856 GR MWD060 API 71.13 114.33 92.7106 167 8766 8849 ROP MWD060 FT/H 0.04 28.61 10.6423 172 8786.5 8872 First Reading For Entire File..........8766 Last Reading For Entire File...........8872 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 • i FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8849.5 9086.0 RPM 8856.5 9093.0 RPX 8856.5 9093.0 RPS 8856.5 9093.0 FET 8856.5 9093.0 RPD 8856.5 9093.0 ROP 8872.5 9106.0 LO G HEADER DATA DATE LOGGED: 13-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9106.0 TOP LOG INTERVAL (FT) 8872.0 BOTTOM LOG INTERVAL (FT) 9106.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 65.0 MAXIMUM ANGLE: 70.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8670.0 BOREHOLE CONDITIONS MUD TYPE: Diesel Mud Base MUD DENSITY (LB/G) 10.00 MUD VISCOSITY (S) 145.0 MUD PH: .0 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 129.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 • • Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8849.5 9106 8977.75 514 8849.5 9106 RPD MWD070 OHMM 4.43 76.1 19.6121 474 8856.5 9093 RPM MWD070 OHMM 4.06 68.54 19.6955 474 8856.5 9093 RPS MWD070 OHMM 3.82 72.55 19.2033 474 8856.5 9093 RPX MWD070 OHMM 3.45 74.75 19.0859 474 8856.5 9093 FET MWD070 HOUR 0.5 90.64 6.65485 474 8856.5 9093 GR MWD070 API 33.85 109.43 74.1261 474 8849.5 9086 ROP MWD070 FT/H 1.23 49.86 21.2855 4.68 8872.5 9106 First Reading For Entire File..........8849.5 Last Reading For Entire File...........9106 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/03/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................07/03/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF • Physical EOF End Of LIS File MPF99o04302007SSN.txt Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LiSLib $Revision: 4 $ Thu Aug 30 11:28:35 2007 Reel Header Service name .............LISTPE Date . ...................07/08/30 Ori9in ...................5T5 Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/08/30 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS writing Library. Scientific Technical Services scientific Technical services Physical EoF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPF-99 API NUMBER: 500292333200 OPERATOR: BP Exploration Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 30-AUG-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw0005043543 Mw0005043543 Mw0005043543 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: J. HABERTHUR J. HABERTHUR J. HABERTHUR MWD RUN 4 MWD RUN 8 MWD RUN 9 JOB NUMBER: Mw0005043543 Mw0005043543 Mw0005043543 LOGGING ENGINEER: 0. OBI J. BOBBITT J. BOBBITT OPERATOR WITNESS: E. VAUGHN G. BURLY G. BURLY SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: l0E FNL: FSL: 2199 FEL: 2450 FWL: Page 1 ~~ -1s~ # ~ s ~ro~( C~ MPF99O043020075SN.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 45.80 GROUND LEVEL: 11.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 4892.0 2ND STRING 8.750 9.625 7954.0 3RD STRING 6.750 7.625 8670.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 7 5/8" CASING SHOE (8670'MD/6988'TVD) IN THE MPF-99 PB1 WELLBORE. 4. MWD RUNS 1-4,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 2-4,9 INCLUDED PRESSURE WHILE DRILLING (PWD) AND MWD RUNS 2 & 4 INCLUDED GEOPILOT ROTARY-STEERABLE BHA (G P). MWD RUNS 8 & 9 INCLUDED AT-BIT INCLINATION. RUN 9 INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND GEOTAP FORMATION TESTER. CORING SROP DATA, AND MAD DGR & EWR4 DATA OVER THE CORED INTERVAL (8803'MD-9014'MD) ACQUIRED WHILE POOH AFTER MWD RUN 9, WERE MERGED WITH RUN 8 MWD DATA. MAD POROSITY DATA WERE MERGED WITH RUN 9 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 5. THERE ARE TWO UNEXPLAINED DATA GAPS IN THE RUN 9 MAD EWR DATA: 8813'-8823'MD AND 8926.5'-8935.5'MD. REAL-TIME DATA FOR SESP AND SEDP WERE MERGED WITH THE MAD DATA OVER THESE INTERVALS (ONLY SESP AND SEDP ARE PULSED UP REAL TIME). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPF-99 ON 3 MAY 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH ON 16 AUGUST 2007, QUOTING AUTHORIZATION FROM MIKIE WEEKS (BP GEOSCIENTIST). 7. MWD RUNS 1-4,8,9 REPRESENT WELL MPF-99 WITH API#: Page 2 ! M MPF99o04302007SSN.txt 50-029-23332-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9270'MD/7215'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING DENSITY SENSOR DEPTHS. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.75" BIT MUD WEIGHT: 10.1 PPG MUD SALINITY: 3000 PPM CHLORIDES FORMATION WATER SALINITY: 28,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPM FET RPD RPS RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 74.5 105.0 105.0 105.0 105.0 105.0 STOP DEPTH 9227.0 9234.0 9234.0 9234.0 9234.0 9234.0 Page 3 MPF99004302007SSN.txt ROP 113.0 9292.0 NPHI 8663.0 9198.5 NCNT 8663.0 9198.5 FCNT 8663.0 9198.5 PEF .8678.5 9214.0 DRHO 8678.5 9214.0 RHOB 8678.5 9214.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4.5 69.5 7625.0 7620.0 7634.0 7628.0 7645.0 7639.5 7662.0 7656.5 7703.0 7696.5 7744.0 7736.5 7815.5 7808.5 7844.5 7835.0 7871.5 7863.0 7903.0 7893.5 7913.5 7905.5 7937.0 7928.0 7939.0 7930.5 7943.0 7935.0 7947.5 7938.5 7954.5 7946.5 7957.0 7948.0 7959.5 7951.5 7961.0 7953.0 7963.5 7955.5 7988.5 7978.5 8001.0 7992.0 8024.0 8014.0 8031.0 8020.5 8040.0 8031.0 8069.0 8061.0 8110.0 8103.0 8129.0 8120.5 8136.0 8128.0 8155.0 8147.0 8193.0 8186.5 8201.5 8194.5 8215.0 8208.5 8247.0 8239.5 8264.0 8256.0 8269.0 8261.5 8282.0 8274.5 8285.0 8278.0 8296.0 8287.5 8306.0 8298.0 8310.5 8303.0 8321.5 8313.5 8324.0 8316.0 8334.0 8327.5 8352.0 8344.0 8366.0 8357.0 8379.0 8370.0 8392.0 8384.5 8396.5 8389.5 Page 4 8407.5 8416.5 8456.0 8460.0 8500.0 8514.0 8529.0 8542.0 8546.0 8565.5 8593.0 8597.5 8610.5 8612.5 8621.5 8635.5 8647.0 8648.0 8651.0 8654.5 8663.0 8671.0 8674.0 8677.0 8680.0 8687.5 8691.0 8693.5 8695.0 8699.5 8701.0 8706.0 8708.5 8711.5 8715.0 8719.5 8723.5 8735.5 8737.0 8744.5 8754.0 8793.0 8811.0 8815.5 8825.0 8831.0 8859.0 8864.0 8873.5 8876.0 8881.0 8884.0 8886.5 8892.5 8899.0 8905.5 8910.5 8914.0 8918.0 8931.5 8936.5 8953.5 8963.5 • 8398.5 8408.0 8447.5 8452.0 8489.0 8505.5 8521.5 8534.0 8537.5 8555.5 8584.5 8588.0 8599.5 8602.0 8611.5 8624.0 8635.0 8638.0 8640.0 8644.0 8650.5 8657.0 8659.0 8662.5 8666.0 8670.5 8672.5 8677.0 8679.0 8682.0 8684.0 8689.5 8691.0 8693.5 8698.5 8702.0 8705.5 8715.5 8718.0 8725.0 8734.0 8772.0 8787.0 8791.5 8801.0 8809.0 8835.5 8840.0 8849.5 8852.0 8856.0 8858.5 8861.5 8868.0 8875.5 8881.0 8886.5 8890.0 8895.0 8907.5 8912.0 8929.5 8939.5 MPF9900430200755N.txt Page 5 ~ ~ 8965.5 8967.0 8975.0 8989.0 8994.0 9003.0 9018.0 9020.5 9050.5 9055.0 9057.5 9062.5 9079.0 9082.5 9095.5 9098.5 9102.0 9106.5 9109.5 9114.0 9119.0 9123.5 9125.0 9129.0 $9292.0 8942.0 8944.5 8953.5 8966.0 8972.5 8980.5 8994.5 8998.5 9028.5 9032.0 9033.5 9039.0 9055.5 9059.5 9073.5 9075.5 9080.5 9086.5 9089.5 9093.0 9099.0 9103.0 9105.0 9107.5 9270.0 MPF99004302007SSN.txt MERGED PBU MWD MWD MWD MWD MWD MWD REMARKS DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 1 69.5 4902.0 2 4902.0 6110.0 3 6110.0 7958.0 4 7958.0 8670.0 8 8670.0 9014.0 9 9014.0 9270.0 MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 Page 6 • MPF990043020075SN.txt GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 74.5 9292 4683.25 18436 74.5 9292 FCNT MWD CNTS 166.91 540.18 312.627 1072 8663 9198.5 NCNT MWD CNTS 15854.8 25915.1 20976.6 1072 8663 9198.5 RHOB MWD G/CM 2.087 2.827 2.43307 1072 8678.5 9214 DRHO MWD G/CM -0.043 0.449 0.107917 1072 8678.5 9214 RPD MWD OHMM 0.08 2000 34.9617 18259 105 9234 RPM MWD OHMM 0.13 2000 14.3665 18217 105 9234 RPS MWD OHMM 0.26 1375.6 8.22325 18259 105 9234 RPX MWD OHMM 0.66 2000 8.93887 18217 105 9234 FET MWD HOUR 0.13 2706.81 22.4687 18259 105 9234 GR MWD API 21.02 193.34 84.4143 18306 74.5 9227 PEF MWD BARN 2.66 11.71 4.34441 1072 8678.5 9214 ROP MWD FT/H 0.12 1557.32 112.03 18359 113 9292 NPHI MWD PU-S 21.65 41.18 30.9995 1072 8663 9198.5 First Reading For Entire File..........74.5 Last Reading For Entire File...........9292 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 69.5 4860.5 RPD 100.0 4852.5 Page 7 • MPF99004302007SSN.txt RPX 100.0 4852.5 RPM 100.0 4852.5 FET 100.0 4852.5 RPS 100.0 4852.5 ROP 108.0 4902.0 LOG HEADER DATA DATE LOGGED: 17-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4902.0 TOP LOG INTERVAL (FT): 107.0 BOTTOM LOG INTERVAL (FT): 4902.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 34.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 16.000 DRILLER'S CASING DEPTH (FT): .O BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 90.0 MUD PH: $,2 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3): 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.200 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.590 82.0 MUD FILTRATE AT MT: 2.100 65.0 MUD CAKE AT MT: 3.400 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 8 MPF99o04302007SSN.txt Absent value .... ..................-999 Depth units. .. .. ..... Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 4902 2485.75 9666 69.5 4902 RPD MWDO10 OHMM 0.08 2000 24.5467 9506 100 4852.5 RPM MWDO10 OHMM 0.13 2000 16.0131 9506 100 4852.5 RPS MWDO10 OHMM 0.26 114.89 10.4252 9506 100 4852.5 RPX MWDO10 OHMM 0.66 61.6 7.90911 9506 100 4852.5 FET MWDO10 HOUR 0.13 11.79 0.997749 9506 100 4852.5 GR MWDO10 API 21.02 115.68 64.9487 9583 69.5 4860.5 ROP MWDO10 FT/H 1.16 1557.32 149.804 9589 108 4902 First Reading For Entire File..........69.5 Last Reading For Entire File...........4902 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File TyC~e ................LO Next Flle Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY Page 9 • MPF99004302007SSN.txt VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4853.0 6066.5 RPM 4853.0 6066.5 RPD 4853.0 6066.5 RPx 4853.0 6066.5 RPS 4853.0 6066.5 GR 4861.0 6074.5 ROP 4902.5 6110.0 LOG HEADER DATA DATE LOGGED: 21-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6110.0 TOP LOG INTERVAL (FT): 4902.0 BOTTOM LOG INTERVAL (FT): 6110.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.7 MAXIMUM ANGLE: 36.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 48.0 MUD PH: 9,3 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.800 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 96.8 MUD FILTRATE AT MT: 5.300 67.0 MUD CAKE AT MT: 2.200 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Page 10 • MPF99o043020075sN.txt Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4853 6110 5481.5 2515 4853 6110 RPD MWD020 OHMM 0.68 2000 27.4569 2428 4853 6066.5 RPM MWD020 OHMM 0.65 1695.25 6.41327 2428 4853 6066.5 RPS MWD020 OHMM 0.74 1149.25 3.87651 2428 4853 6066.5 RPX MWD020 OHMM 0.82 2000 21.8458 2428 4853 6066.5 FET MWD020 HOUR 0.24 84.29 4.26785 2428 4853 6066.5 GR MWD020 API 47.47 122.35 96.0371 2428 4861 6074.5 ROP MWD020 FT/H 0.64 675.53 104.821 2416 4902.5 6110 First Reading For Entire File..........4853 Last Reading For Entire File...........6110 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 Page 11 • DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPS RPX RPD FET RPM GR ROP LOG HEADER DATA .5000 MPF99o043020075SN.txt START DEPTH 6067.0 6067.0 6067.0 6067.0 6067.0 6075.0 6110.5 STOP DEPTH 7896.0 7896.0 7896.0 7896.0 7896.0 7904.0 7958.0 • DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7958.0 TOP LOG INTERVAL (FT): 6110.0 BOTTOM LOG INTERVAL (FT): 7958.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.1 MAXIMUM ANGLE: 70.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.600 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .930 122.0 MUD FILTRATE AT MT: 5.000 68.0 MUD CAKE AT MT: 2.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ..................0 Page 12 • MPF99o04302007SSN.txt Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RP5 MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MWD030 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6067 7958 7012.5 3783 6067 7958 RPD MwD030 OHMM 1.19 7.75 3.24387 3659 6067 7896 RPM MwD030 OHMM 1.1 7.32 3.14762 3659 6067 7896 RPS MWD030 OHMM 1.13 5.9 3.1269 3659 6067 7896 RPX MWD030 OHMM 1.19 6.56 3.11905 3659 6067 7896 FET MWD030 HOUR 0.63 19.55 2.12018 3659 6067 7896 GR MWD030 API 63.36 153.25 111.836 3659 6075 7904 ROP MWD030 FT/H 0.64 204.28 57.9828 3696 6110.5 7958 First Reading For Entire File..........6067 Last Reading For Entire File...........7958 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: Page 13 • MPF99o04302007SSN.txt RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7896.5 8624.5 RPX 7896.5 8624.5 FET 7896.5 8624.5 RPM 7896.5 8624.5 RPD 7896.5 8624.5 GR 7904.5 8632.5 ROP 7958.5 8670.0 LOG HEADER DATA DATE LOGGED: 31-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8670.0 TOP LOG INTERVAL (FT): 7958.0 BOTTOM LOG INTERVAL (FT): 8670.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.0 MAXIMUM ANGLE: 68.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 097054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 48.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.500 67.0 MUD AT MAX CIRCULATING TERMPERATURE: .790 132.8 MUD FILTRATE AT MT: 2.300 67.0 MUD CAKE AT MT: 1.000 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 14 • • MPF99004302007SSN.txt Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MwD040 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7896.5 8670 8283.25 1548 7896.5 8670 RPD MWD040 OHMM 2.64 2000 157.241 1457 7896.5 8624.5 RPM MWD040 OHMM 2.37 2000 19.0765 1457 7896.5 8624.5 RPS MWD040 OHMM 2.17 1375.6 9.61535 1457 7896.5 8624.5 RPX MWD040 OHMM 1.19 1145.02 6.1341 1457 7896.5 8624.5 FET MWD040 HOUR 0.38 101.27 12.6638 1457 7896.5 8624.5 GR MWD040 API 36.44 193.34 118.174 1457 7904.5 8632.5 ROP MWD040 FT/H 0.39 216.55 72.9442 1424 7958.5 8670 First Reading For Entire File..........7896.5 Last Reading For Entire File...........8670 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... ......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Page 15 • MPF9900430200755N.txt comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8625.0 8956.0 RPS 8625.0 8956.0 RPD 8625.0 8956.0 RPM 8625.0 8956.0 RPX 8625.0 8956.0 GR 8633.0 8949.5 ROP 8670.5 9014.0 LOG HEADER DATA DATE LOGGED: 22-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9014.0 TOP LOG INTERVAL (FT): 8670.0 BOTTOM LOG INTERVAL (FT): 9014.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.0 MAXIMUM ANGLE: 67.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8670.0 . BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 110.0 MUD PH: .O MUD CHLORIDES (PPM): 7000 FLUID LOSS (C3): 10.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 122.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 16 • MPF99o0430200755N.txt REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MwD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8625 9014 8819.5 779 8625 9014 RPD MWD080 OHMM 0.95 2000 131.665 663 8625 8956 RPM MwD080 OHMM 0.18 2000 70.9926 623 8625 8956 RPS MWD080 OHMM 3.67 1331.09 21.6616 663 8625 8956 RPX MWD080 OHMM 3.7 737.61 19.0721 623 8625 8956 FET MwD080 HOUR 17.72 2706.81 492.482 663 8625 8956 GR MWD080 API 39.2 113.63 80.7763 634 8633 8949.5 ROP MWD080 FT/H 0.12 261.12 37.145 688 8670.5 9014 First Reading For Entire File..........8625 Last Reading For Entire File...........9014 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/30 Maximum Physical Record..65535 Page 17 • • MPF99004302007SSN.txt File Type. ............LO Previous File Name.......ST5LI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 8650.5 9177.0 NCNT 8650.5 9177.0 NPHI 8650.5 9177.0 DRHO 8664.5 9192.0 PEF 8664.5 9192.0 RHOB 8664.5 9192.0 GR 8950.0 9205.0 RPD 8956.5 9212.0 FET 8956.5 9212.0 RPS 8956.5 9212.0 RPX 8956.5 9212.0 RPM 8956.5 9212.0 ROP 9014.5 9270.0 LOG HEADER DATA DATE LOGGED: 30-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9270.0 TOP LOG INTERVAL (FT): 9014.0 BOTTOM LOG INTERVAL (FT): 9270.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.0 MAXIMUM ANGLE: 69.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 CTN COMP THERMAL NEUTRON 1188950301626404 EWR4 Electromag Resis. 4 90518 ALD Azimuthal Litho-Dens 10859715 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8670.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S): 138.0 MUD PH: .O MUD CHLORIDES (PPM): 2500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O Page 18 MUD AT MAX CIRCULATING MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MPF99o04302007SSN.txt TERMPERATURE: .000 108.0 .000 .0 .000 .0 Data Format specification Record Data Record Type... .........0 Data specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD090 CNTS 4 1 68 4 2 NCNT MWD090 CNTS 4 1 68 8 3 RHOB MWD090 G/CM 4 1 68 12 4 DRHO MWD090 G/CM 4 1 68 16 5 RPD MwD090 OHMM 4 1 68 20 6 RPM MwD090 OHMM 4 1 68 24 7 RPS MwD090 OHMM 4 1 68 28 8 RPX MwD090 OHMM 4 1 68 32 9 FET MWD090 HOUR 4 1 68 36 10 GR MwD090 API 4 1 68 40 11 PEF MWD090 BARN 4 1 68 44 12 ROP MwD090 FT/H 4 1 68 48 13 NPHI MwD090 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8650.5 9270 8960.25 1240 8650.5 9270 FCNT MWD090 CNTS 166.91 540.18 312.884 1054 8650.5 9177 NCNT MwD090 CNTS 15854.8 25915.1 20984.4 1054 8650.5 9177 RHOB MwD090 G/CM 2.087 2.827 2.43309 1056 8664.5 9192 DRHO MWD090 G/CM -0.043 0.449 0.109458 1056 8664.5 9192 RPD MWD090 OHMM 3.17 39.67 7.76871 512 8956.5 9212 RPM MwD090 OHMM 3.01 39.12 7.6109 512 8956.5 9212 RPS MWD090 OHMM 2.66 39.65 6.94432 512 8956.5 9212 RPX MWD090 OHMM 2.49 35.32 6.65318 512 8956.5 9212 FET MwD090 HOUR 1.02 43.71 9.21783 512 8956.5 9212 GR MwD090 API 40.29 138.55 105.58 511 8950 9205 PEF MwD090 BARN 2.66 11.98 4.37705 1056 8664.5 9192 ROP MWD090 FT/H 10.77 165.08 44.0873 512 9014.5 9270 NPHI MwD090 PU-S 21.65 41.18 31.0062 1054 8650.5 9177 Page 19 MPF99o04302007SSN.txt First Reading For Entire File..........8650.5 Last Reading For Entire File...........9270 File Trailer Service name... .......STSLiB.007 Service Sub Level Name... version Number. ........1.0.0 gate of Generation.......07/08/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................07/08/30 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN ~omments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................07/08/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File Scientific Technical Services scientific Technical services Page 20 • • MPF99P61o01132007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Fri Aug 31 14:31:31 2007 Reel Header Service name... ........LISTPE Date. ...................07/08/31 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name ............. LISTPE Date . ................... 07/08/31 Origin ................... STS Tape Name. .... ........ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: scientific Technical services scientific Technical services mpf-99pb1 500292333270 BP Exploration Alaska, Inc. Sperry Drilling Services 31-AUG-07 MWD. RUN 1 MWD RUN 2 MWD RUN 3 MW0004794046 MW0004794046 MW0004794046 S. LATZ 5. LATZ S. LATZ J. HABERTHUR J. HABERTHUR J. HABERTHUR MWD RUN 4 MWD RUN 5 MWD RUN 6 MW0004794046 MW0004794046 MW0004794046 O. OBI O. OBI 5. LATZ E. VAUGHN E. VAUGHN J. HABERTHUR MWD RUN 7 Mw0004794046 S. LATZ J. HABERTHUR 6 Page 1 ~ b ~o' 1 ~Co ~ t5'Llb~o writing Library. • TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF99P61o0113200755N.txt 13N l0E 2199 2450 45.80 11.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1sT STRING 12.250 13.375 4892.0 2ND STRING 8.500 9.625 7954.0 3RD STRING 6.750 7.625 8670.0 4TH STRING REMARKS: C~ 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). ADDITIONALLY, MWD RUNS 2-4 INCLUDED PRESSURE WHILE DRILLING (PWD) AND MWD RUNS 2 & 4 INCLUDED GEOPILOT ROTARY-STEERABLE BHA (GP). AT-BIT GAMMA (ABG), UTILIZING SCINTILLATION DETECTORS, WAS ALSO RUN IN MWD RUN 4. CORING SROP DATA, AND MAD DATA OVER THE CORED INTERVAL (8786'MD-8865'MD) ACQUIRED WHILE RIH FOR MWD RUN 6, WERE MERGED WITH RUN 6 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 4. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPF-99 ON 3 MAY 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH ON 16 AUGUST 2007, QUOTING AUTHORIZATION FROM MIKIE WEEKS (BP GEOSCIENTIST). 5. MWD RUNS 1-7 REPRESENT WELL MPF-99 PB1 WITH API#: 50-029-23332-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9106'MD/7144'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM Page 2 • MPF99P61001132007SSN.txt SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SABG = SMOOTHED GAMMA RAY AT BIT. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 74.5 9095.5 RPS 105.0 9102.5 FET 105.0 9102.5 RPD 105.0 9102.5 RPx 105.0 9102.5 RPM 105.0 9102.5 ROP 113.0 9115.5 ABGC 7944.0 8674.5 BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4.5 69.5 7625.0 7620.0 7634.0 7628.0 7645.0 7639.5 7662.0 7656.5 7703.0 7696.5 7744.0 7736.5 7815.5 7808.5 7844.5 7835.0 7871.5 7863.0 7903.0 7893.5 7913.5 7905.5 7937.0 7928.0 7939.0 7930.5 7943.0 7935.0 7947.5 7938.5 7954.5 7946.5 7957.0 7948.0 7959.5 7951.5 7961.0 7953.0 7963.5 7955.5 7988.5 7978.5 8001.0 7992.0 8024.0 8014.0 Page 3 MPF99PB1o01132007SSN.txt 8031.0 8020.5 8040.0 8031.0 8069.0 8061.0 8110.0 8103.0 8129.0 8120.5 8136.0 8128.0 8155.0 8147.0 8193.0 8186.5 8201.5 8194.5 8215.0 8208.5 8247.0 8239.5 8264.0 8256.0 8269.0 8261.5 8282.0 8274.5 8285.0 8278.0 8296.0 8287.5 8305.5 8298.0 8310.5 8303.0 8321.5 8313.5 8324.0 8316.0 8334.0 8327.5 8352.0 8344.0 8366.0 8357.0 8379.0 8370.0 8392.0 8384.5 8396.5 8389.5 8407.0 8398.5 8416.5 8408.0 8456.0 8447.5 8460.0 8452.0 8500.0 8489.0 8514.0 8505.5 8529.0 8521.5 8542.0 8534.0 8546.0 8537.5 8565.5 8555.5 8593.5 8584.5 8597.5 8588.0 8610.5 8599.5 8612.5 8602.0 8621.0 8611.5 8635.5 8624.0 8647.0 8635.0 8648.0 8638.0 8651.0 8640.0 8654.5 8644.0 8663.0 8654.5 8671.0 8662.0 8680.0 8670.0 9115.5 9106.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 69.5 4902.0 MwD 2 4902.0 6110.0 MwD 3 6110.0 7958.0 MwD 4 7958.0 8670.0 MwD 5 8670.0 8786.0 MwD 6 8786.0 8872.0 wD 7 8872.0 9106.0 $ Page 4 MPF99P61o011320075sN.txt REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 ABGC MWD API 4 1 68 32 9 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 74.5 9115.5 4595 18083 74.5 9115.5 RPD MWD OHMM 0.08 2000 37.5222 17996 105 9102.5 RPM MWD OHMM 0.13 2000 20.0943 17996 105 9102.5 RPS MWD OHMM 0.26 1691.28 8.27342 17996 105 9102.5 RPX MWD OHMM 0.16 2000 8.9006 17996 105 9102.5 FET MWD HOUR 0.13 111.96 3.96645 17996 105 9102.5 GR MWD API 21.02 193.34 83.6322 18043 74.5 9095.5 ROP MwD FT/H 0.04 1557.32 112.982 18006 113 9115.5 ABGC MWD API 36.31 186.72 118.709 1462 7944 8674.5 First Reading For Entire File..........74.5 Last Reading For Entire File...........9115.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Page 5 C~ MPF99PB1o01132007ssN.txt Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 1 .5000 VENDOR TOOL CODE START DEPTH GR 69.5 FET 100.0 RPM 100.0 RPS 100.0 RPX 100.0 RPD 100.0 OP 108.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 4860.5 4852.5 4852.5 4852.5 4852.5 4852.5 4902.0 17-DEC-06 Insite 7z.13 Memory 4902.0 107.0 4902.0 .0 34.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 16.000 DRILLER'S CASING DEPTH (FT); 107.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 90.0 MUD PH: 8.2 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3): 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.200 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.590 82.0 MUD FILTRATE AT MT: 2.100 65.0 MUD CAKE AT MT: 3.400 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: Page 6 ~~ HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): MPF99PB1o01132007SSN.txt REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 U Name Service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 4902 2485.75 9666 69.5 4902 RPD MWDO10 OHMM 0.08 2000 24.5467 9506 100 4852.5 RPM MWDO10 OHMM 0.13 2000 16.0131 9506 100 4852.5 RPS MWDO10 OHMM 0.26 114.89 10.4252 9506 100 4852.5 RPX MWDO10 OHMM 0.66 61.6 7.90911 9506 100 4852.5 FET MWD010 HOUR 0.13 11.79 0.997749 9506 100 4852.5 GR MWDO10 API 21.02 115.68 64.9487 9583 69.5 4860.5 ROP MWDO10 FT/H 1.16 1557.32 149.804 9589 108 4902 First Reading For Entire File..........69.5 Last Reading For Entire File...........4902 File Trailer Service name... .......STSL2B.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLI6.003 Page 7 MPF99PB1O0113200755N.txt Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER; 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 4853.0 6066.5 FET 4853.0 6066.5 RPS 4853.0 6066.5 RPM 4853.0 6066.5 RPX 4853.0 6066.5 GR 4861.0 6074.5 ROP 4902.5 6110.0 LOG HEADER DATA DATE LOGGED: 21-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6110.0 TOP LOG INTERVAL (FT): 4902.0 BOTTOM LOG INTERVAL (FT): 6110.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.7 MAXIMUM ANGLE: 36.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (5): 48.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.800 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 96.8 MUD FILTRATE AT MT: 5.300 67.0 MUD CAKE AT MT: 2.200 67.0 Page 8 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MPF99PB1o01132007SSN.txt Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4853 6110 5481.5 2515 4853 6110 RPD MWD020 OHMM 0.68 2000 27.4569 2428 4853 6066.5 RPM MWD020 OHMM 0.65 1695.25 6.41327 2428 4853 6066.5 RPS MWD020 OHMM 0.74 1149.25 3.87651 2428 4853 6066.5 RPX MWD020 OHMM 0.82 2000 21.8458 2428 4853 6066.5 FET MwD020 HOUR 0.24 84.29 4.26785 2428 4853 6066.5 GR MWD020 API 47.47 122.35 96.0371 2428 4861 6074.5 ROP MWD020 FT/H 0.64 675.53 104.821 2416 4902.5 6110 First Reading For Entire File..........4853 Last Reading For Entire File...........6110 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type ................L0 Next F~pe Name...........STSLIB.004 Physical EOF Page 9 MPF99P61o01132007SSN.txt File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER U FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6067.0 7896.0 RPM 6067.0 7896.0 RPx 6067.0 7896.0 RPD 6067.0 7896.0 RPS 6067.0 7896.0 GR 6075.0 7904.0 ROP 6110.5 7958.0 LOG HEADER DATA DATE LOGGED: 24-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7958.0 TOP LOG INTERVAL (FT): 6110.0 BOTTOM LOG INTERVAL (FT): 7958.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.1 MAXIMUM ANGLE: 70.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 4892.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.600 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .930 122.0 Page 10 • MPF99PB1o01132007SSN.txt MUD FILTRATE AT MT: 5.000 68.0 MUD CAKE AT MT: 2.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6067 7958 7012.5 3783 6067 7958 RPD MwD030 OHMM 1.19 7.75 3.24387 3659 6067 7896 RPM MwD030 OHMM 1.1 7.32 3.14762 3659 6067 7896 RPS MWD030 OHMM 1.13 5.9 3.1269 3659 6067 7896 RPX MWD030 OHMM 1.19 6.56 3.11905 3659 6067 7896 FET MwD030 HOUR 0.63 19.55 2.12018 3659 6067 7896 GR MwD030 API 63.36 153.25 111.836 3659 6075 7904 ROP MWD030 FT/H 0.64 204.28 57.9828 3696 6110.5 7958 First Reading For Entire File..........6067 Last Reading For Entire File...........7958 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.005 Page 11 • • MPF99PB1o01132007ssN.txt Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS 7896.5 RPM 7896.5 FET 7896.5 RPD 7896.5 RPx 7896.5 GR 7904.5 ABGC 7936.0 ROP 7958.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 ABG 5 STOP DEPTH 8624.5 8624.5 8624.5 8624.5 8624.5 8632.5 8665.0 8670.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 AT-BIT GAMMA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: header data for each bit run in separate files. 4 .5000 31-DEC-06 Insite 72.13 Memory 8670.0 7958.0 8670.0 66.0 68.8 TOOL NUMBER 097054 10505932 222954 8.500 7954.0 Polymer 10.00 48.0 9.2 Page 12 • • MPF99P61001132007SSN.txt MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.500 67.0 MUD AT MAX CIRCULATING TERMPERATURE: .790 132.8 MUD FILTRATE AT MT: 2.300 67.0 MUD CAKE AT MT: 1.000 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MwD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 ABGC MwD040 API 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7896.5 8670 8283.25 1548 7896.5 8670 RPD MwD040 OHMM 2.64 2000 157.241 1457 7896.5 8624.5 RPM MwD040 OHMM 2.37 2000 19.0765 1457 7896.5 8624.5 RPS MWD040 OHMM 2.17 1375.6 9.61535 1457 7896.5 8624.5 RPX MWD040 OHMM 1.19 1145.02 6.1341 1457 7896.5 8624.5 FET MwD040 HOUR 0.38 101.27 12.6638 1457 7896.5 8624.5 GR MWD040 API 36.44 193.34 118.174 1457 7904.5 8632.5 ROP MwD040 FT/H 0.39 216.55 72.9442 1424 7958.5 8670 ABGC MWD040 API 36.31 186.72 118.484 1459 7936 8665 First Reading For Entire File..........7896.5 Last Reading For Entire File...........8670 File Trailer service name .............sTSLI6.005 Page 13 • MPF99PB1o01132007SSN.txt Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLi6.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS 8625.0 FET 8625.0 RPX 8625.0 RPD 8625.0 RPM 8625.0 GR 8633.0 $oP 8670.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: • header data for each bit run in separate files. 5 .5000 STOP DEPTH 8772.5 8772.5 8772.5 8772.5 8772.5 8765.5 8786.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6 06-7AN-07 Insite 72.13 Memory 8786.0 8670.0 8786.0 63.3 69.8 TOOL NUMBER 178505 90518 6.750 8670.0 Page 14 • MPF99PB1o01132007SSN.txt BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 58.0 MUD PH: ,0 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): ,Q RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 153.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8625 8786 8705.5 323 8625 8786 RPD MwD050 OHMM 1.4 2000 452.482 296 8625 8772.5 RPM MwD050 OHMM 2.05 2000 516.081 296 8625 8772.5 RPS MWD050 OHMM 2.8 1691.28 20.1832 296 8625 8772.5 RPX MWD050 OHMM 0.16 32.57 9.02162 296 8625 8772.5 FET MWD050 HOUR 0.16 110.73 37.2627 296 8625 8772.5 GR MWD050 API 38.33 102 74.809 266 8633 8765.5 ROP MWD050 FT/H 0.78 134.13 62.1668 232 8670.5 8786 First Reading For Entire File..........8625 Last Reading For Entire File...........8786 Page 15 • MPF99P61001132007SSN.txt File Trailer Service name... .......STSLIB.006 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.... .07/08/31 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLI6.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8766.0 8849.0 RPS 8773.0 8856.0 RPM 8773.0 8856.0 FET 8773.0 8856.0 RPx 8773.0 8856.0 RPD 8773.0 8856.0 ROP 8786.5 8872.0 LOG HEADER DATA DATE LOGGED: 10-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8872.0 TOP LOG INTERVAL (FT): 8786.0 BOTTOM LOG INTERVAL (FT): 8872.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.9 MAXIMUM ANGLE: 72.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA Page 16 MPF99PB1001132007SSN.txt OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8670.0 BOREHOLE CONDITIONS MUD TYPE: Diesel MUd Base MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 170.0 MUD PH: ,0 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): ,0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MwD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MwD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8766 8872 8819 213 8766 8872 RPD MWD060 OHMM 3.99 20.71 6.66383 167 8773 8856 RPM MWD060 OHMM 3.75 17.28 6.30982 167 8773 8856 RPS MWD060 OHMM 3.69 14.43 5.98317 167 8773 8856 RPX MWD060 OHMM 3.68 13.32 5.91838 167 8773 8856 FET MWD060 HOUR 33.38 111.96 68.095 167 8773 8856 GR MWD060 API 71.13 114.33 92.7106 167 8766 8849 ROP MWD060 FT/H 0.04 28.61 10.6423 172 8786.5 8872 Page 17 MPF99P61o01132007SSN.txt First Reading For Entire File..........8766 Last Reading For Entire File...........8872 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY 5000 VENDOR TOOL CODE START DEPTH GR 8849.5 FET 8856.5 RPS 8856.5 RPM 8856.5 RPD 8856.5 RPX 8856.5 ROP 8872.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9086.0 9093.0 9093.0 9093.0 9093.0 9093.0 9106.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 Page 18 header data for each bit run in separate files. 7 13-7AN-07 Insite 72.13 Memory 9106.0 8872.0 9106.0 65.0 70.6 TOOL NUMBER 232602 228502 • MPF99PB1o011320075SN.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 8670.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Diesel Mud Base 10.00 145.0 .0 1700 .0 .000 .0 .000 129.0 .000 .0 .000 .0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MwD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8849.5 9106 8977.75 514 8849.5 9106 RPD MWD070 OHMM 4.43 76.1 19.6121 474 8856.5 9093 RPM MWD070 OHMM 4.06 68.54 19.6955 474 8856.5 9093 RPS MWD070 OHMM 3.82 72.55 19.2033 474 8856.5 9093 RPX MWD070 OHMM 3.45 74.75 19.0859 474 8856.5 9093 FET MWD070 HOUR 0.5 90.64 6.65485 474 8856.5 9093 GR MWD070 API 33.85 109.43 74.1261 474 8849.5 9086 Page 19 ' ~ • MPF99PB1001132007SSN.txt RoP Mw~070 FT/H 1.23 49.86 21.2855 468 First Reading For Entire File..........8849.5 Last Reading For Entire File...........9106 File Trailer Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 gate of Generation.......07/08/31 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LISTPE gate .....................07/08/31 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................07/08/31 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File 8872.5 9106 scientific Technical services Scientific Technical services Page 20 MPF-99i Core Chip Descriptions.xls Core Chi Descri tions 8804' MD to 9014' MD Well: MPF-99i API # 50-029-23332-00 GeologisUs: Reusing ( Zarntlt L~cation: Milne Point Dat2; Apri~ 24- 29, 2007 Cement= % Pore Soace Occuoied 5b~i~D AUG 1 9 2009 Depth Lithology Color Grainsize Roundness Porosity Cement Description MD Lith ~ ~' ~ ~ ~ ° > ~ ~ m " `~ ~ ~` % Type Constituents Shows Core t Med-drk gry argillaceous sltsl; tr md gm qtzllthc 8804 Slst med-drk gry grns;sli micaceous, massive; well indurated Not done due to MOBM 8805 Sh dk gry-brn x Slty, sub-fissle, carbonaceous, tr mica 8806 Slts metl-drk brn-gry x x Qtzose, argillaceous, wl v-f intedaminated shale 8B07 Predom. Sltst. Qtzose, argill, mirco-mica (tr) w/ v-fn Sltslsh med-tlrk brn-gry x x (1-2 mm} interlam tlk gry shale (mud rip-ups?) 8808 Sh v dk grylblk X x sub-fissle, carbonaceous, tr micro-mica specks Predom. Sltst: (65%) Qizose, argill, mirco-mica (tr); 8809 Interlam, wl v-fn (1-2 mm) interlam tlk gry shale (mutl rip-ups?) Sltslsh metl gryldrk brn-gry x x 35% Pretlom. Sltst: (70%) Qtzose, argill, trace pyrite; w! v 8810 Interlam. v-fn (0.3 -1.5 mm) interlam dk gry carbonaceous Sltslsh med gry/drk bm-gry x x shale, 30% Interlam. 50%/50% interlamaminated Siltslone/Shale as 8811 Slts/sh med gryltlrk bm-gry x x above; Laminations 1.0 to 10 mm Interlam. 40% / 64% interlamaminatetl SiltstonelShale as 88~ 2 Sltslsh med gry/drk brn•gry x x above; Shale fissile, carbonaceous, black 8813 Shale tlk gry / blk x Blocky habit, carbonaceous, no sili, tr pyrite 8814 Shale med to dk gry x Massive, blocky habit 8815 Shale med to tlk gry x As above 5816 Interlam. It-md gry sltl 65% I 35% interlamaminated SiltstonelShale as Slts/sh dk gry-blk sh x x above; Tr VFG ss in slt; wispylundul. Lams 8817 Interlam. It•md gry sIU Sltslsh dk gry-blk sh x x Interlamaminatetl Siltstone/Shale as above... 881 S Interlam. It-md gry sIU Intedamaminatetl Siltstone (95°!0): qtrose, ir micro- Sltsfsh dk gry-blk sh x x pryite I Shale {5%) wispy clay chips/lams. Page 1 of 12 • LJ z~~ -~5 C~ MPF•99i Core Chip Descriptions.xls Depth Lithology Colar Greinsize Roundness Porosity Cement Description MD Lith ~ ~' ~ ~ ° ~ ` °' m` N " ` ` °/, Type Constituents 011 ShOWS sa1 s Interlam. Slislsh It-md gry sIU dk gry-blk sh x x 98% Siltstone as above, minor very fine lamination oi clay (shale) < 0.5 mm, tr pyrite, carbon. 8820 Interlam. Sltslsh md gry slt/ dk gry-blk sh x x 50150% siltstone/shale; very drk gray to blk shale, micro-micaceous, very carbonaceous $$21 Interlam. SSlsh mtl gry sIU dk gry-bik sh X x X Predom. Sandstone; clrlgissy Qtr, VFG, v-w srtd, w/ tr silt, heavy oil-stain???; occ.whispy shale laminations (0.5 tp 2.Omm) 8822 SS (100°k) drk brwn X X x x X x Qtz: cir/trnsl, v-w srtd, good p& p, heavy sm 8823 SS (95%) drk brwn X X x x X x SS as above, w/ minor wispy (discont.) shale lamin. (0.5 -10 mm) 8824 Interlam. SS/sh md gry sIU tlk gry-blk sh x X X X X X x SS (60%): clrlglssy Qtz; FNF gr, v-w srtd, w/ tr silt, heavy oil-stain???; occ. shale lam/ rip-up clasts (1.0 - 5.0 mm) 8825 SS (100%) drk bnvn X X x x X x Qtz: clr mod consol, vw srtd, good p& p, heavy stn 8826 SS (100%) drk brwn X X x x X x SS as above, uniform srtg antl texture as above, massive appearance 8827 SS drk bnvn X X x x X x SS, similar 1o above, w! occ wispy disc shale laminations 8828 SS (100%) drk brwn X X x x X x SS as above, uniform srtg and texture as above, massive appearance 8829 SS (100°k) drk bnvn X X x x X x SS: predominantly quartz, good p&p, excl srtg 8830 SS (99+°h) drk brwn X X x x X x SS as above 8831 SS (100%) drk brwn X X x x X x Quartz SS: massive appearance„ w uniform texture, srtg antl grain size as notetl; vg por 8832 SS drk brwn X X x x X x Quartz SS: massive appearence„ w uniform te~nure, srtg and grain size as noted; v-g por 8833 SS drk brwn X X x x X x Quartz SS: as above, homogeneous... ~or~ ~ ~_ ~ ~ ~ r , ~ . , ~ ,.~,~ , ~,. ~. ~ . „ . . ~~ 8834 SS med-dk bm 25 silica W. consol, qtr ss, w srtd, sli slty, massive 8835 SS med-dk brn 20 silica Massive, wl consol, w srttl, vf-f gmd qtz ss 8836 SS med-dk brn 25 silica Massive, wl consol, w srtd, vf-f gmd qtz ss 8837 SS med-dk bm 20 silica Massive, wl consoi, w srtd, vf-f grnd qtz ss 8838 SS med-dk brn 25 silica Massive, wl consol, w srtd, vf-f grnd qtz ss 8839 SS med-dk bm 20 silica Massive, wl consol, w srttl, vf-f grnd qtz ss \J • Page 2 of 12 8840 Depth MD 8841 8842 8843 8844 saa5 aeas 8847 8848 8849 8850 8851 8852 8853 8854 8855 sa5s 8857 8858 8859 8860 MPF-99i Core Chip Qescriptions.xls SS med-dk brn 25 silica Massive, wl consol, w srtd, vf•f grnd qtz ss Lithology Color Grainsize Roundness Poro siry Cement Description Lith ~',$ ~" ~ U U ' ~ ~ N C ro Ip N ~'a N~ '~ % Type , Constituents Oil ShOwS SS md•dk brn 20 silica Massive, wl consol, w srid, vf-f grnd qtz ss SS md•dk brn 25 silica Massive, wl consol, w srtd, vf-f grnd qtr ss SS md-dk brn 25 silica Dom massive, wl consol, w srid vf-f grnd qtz ss, w/ tr qtr og; w/ thin lam md grnd ss wl incr silica cmnt SS mtl-tlk bm ~;; 4s 20 silica Massive, w consol, w srtd, vf•t grnd qtr ss, w/ increasing micaceous content, tr pyr cmnt, tr pyr nodules Sh/SIsUSS It-dk brn / gry ~_~ 30 silica/pyr Laminated shales, siltstones, ss SIsUSS mtl-tlk brn {~ 25 silica, cly Massive, no bedding visible, decrease visible porosity, decrease mica conteni Sh/SIsUSS It-dk brn/ gy ~; ; ~- ~~` ~ 25 silica, tr pyr Laminated shales, silstones, ss. Rip•ups visible is some shale betls; One laminae of f-as qtz I ang mica/ ir drk gry chrt? Dom SS md-dk brn ! gry ~~ 20 silic 1 cly/pyr Massive (no visible lam) ss w/ tr metl qtz/chrt gms w/ micro-pyr lam and dr gry shl lam/bedding Dom SS mtl-dk brn/gry 20 silica/cly Massive ss to micro-lam of sh/sltst, some np-ups visible. Slty Sh mtl gry WI indurated, micaceous, tr carb, tr ss notls. Slty Sh mtl gry W indurated wl incr slt and micaceous material, tr md bm, vi-f grn ss laminations Slty Sh md brn Incr sH content Sh md gry W indurated shale w/ incr freq thin med brn ss lam. Sh md gry W indurated, micaceous, carb w! It-md brn, f-mtl grntl ss lam Sh md-drk gry Sh as above I tr pyr w/ thin clr-md brn qk ss lam Sh md-drk gry 5h as above / tr pyr w/ thin clr-md brn qtz ss lam Sh1SS md brn / gry Thinly lam shlss ShISS mtl bm ! gry Thinly lam sh (incr micaceous content)!ss ShlSS It-md brn/gry Thinly lam sh (incr micaceous content)/ss Dom Sh md-dk gry Dom massive, sh, sli slity, reduced micaceous content. Tr smi ss lam Page 3 of 12 ~ 8861 Depth MD aas2 8863 assa ass5 8866 8867 8868 sass 8870 8871 8872 8873 8874 8875 8876 8877 8878 8879 8880 saal ssa2 8883 8884 MPF-99i Core Chip Descriptions.xls ShISS md-tlk bm/gry r ~~ Interbedded thin ss I more massive md-dk gry sh Lithology Color cnsl Grainsize Roundness P oros ity Cement Description Lith % ~ ~' ~ ~ U V > i m ~ C m ~ '~ ~ `~ ~ ~ ~` °/, Type Constituents 011 ShOWS ShlSS md-tlk brnlgry Interbedded thin ss / more massive mtl-tlk gry sh Sh/SS mtl-dk bm/gry .~ ~ Interbedded fhin ss / more massive mtl-dk gry sh Sh med gry Very dense, massive, micaceous shale w/ try pyr notlules. Sh med gry Sh as above wl thin f grntl med brwn ss lam Sh med gry Micaceous sh; waxy bedding planes in part, mica ( pyr lam, f•md ss bunow fill Sh med-drk gry Sli siltyl sli micaceous, massive SS md-drk bm Vf, qfz ss w/ tr v thin shale/mica laminations Sh metl gry Massive, sli silty, tr pyr, w/ tr v thin vf ss lamination Slst md-tlrk brn Arenaceous, argillaceous, tr pyr ShISIsUSS md brnlgry Interbedtletl shlss/slst SS1ShlSlst md brn/gry ~~ ~ ss w s a e a si tstone ammaiions. yr~te am an burrow fill in shale. Sh md gry Dom shale w! pyr antl mica lam; thin metl brwn ss laminations. SS/Slst metl bnvn <~ ~ V micaceous sltst grading to ss w/ vt-f ss, micaceous, tr qtz og SS mtl-tlrk brn W srtd, w indurated ss w/ no visible bedding, motl qtz og SS md-drk brn Massive ss, no visible bedding, mod qtz og SS mtl-drk brn See above SS mtl-drk brn See above SS md-drk brn See above SS md-drk bm See above Sh/SS mtl-tlk brnlgry Thin lam of md-drk bm sh/ss Slst mtl -tlrk brn Slightly arenaceous slst; no apparent bedding SS md bm Well indurated, well sorted, qtz ss, w/ incr qtr og antl tr pyd pyr-filled burrow SS md brn Well indurated, well sorted, qtz ss, w/ qtz og. Page 4 of t2 \J ~ 8885 8886 Depth MD aes; 8888 8889 8890 8891 8892 8893 8894 -re 4 8894 8895 8895 8896 aas~ eass aass asao 8901 8902 asas MPF-99i Core Chip Descriptions.xls 5h/SS md-tlrk bm/gry ' ~ V micaceous, w indurated sh wl med brn vf-f grnd ss lam Sh/SS It-tlrk gry/med brn Very thinly interbedded shlss wf occas pyr Lithology Color cnsl Greinsize Roundness P orosNy Cement Description Lith % ~ ~' ~ ~ ~ ° > m °~' m` " " c ~ % T e Yp Constituents Oil ShOwS ShISS/Slst med-drk brn-gry §' „` Very thinly interbedded shale (treq mica/pyrite lam in shale~, sltst (arenaceous, sli micaceous) and ss(med brwn, dom vf) SS md-drk brn WI consol, w srtd, qiz ss, w/ freq qtr og, no visible bedding planes SIsUSS md•drk bnvn ~ Interbedtled slstsUss, both v thin and more massive bedding obseroed. SS md-drk bnvn Massive, w consol, w srtd, vf-f gmd qtz ss, w! qtz og SS med-drk brwn Massive, w consol, w srtd, vf•f gmtl qtz ss, w! qiz og SSISh med-drk brn/gry s ~~~ Massive, w consol, w srtd, vf-f grnd qtz ss, wl qiz og wl thin shale lam visible SIsUSS md-drk bm `~ Micaceous si~tstone interbedded w/ vf-f gmtl ss SS md brn Vf, silty ss, freq sitl notlules, appears fairly tight SS md-tlrk brwn ` QTZ: w consol, v-w srtd, massive/no bedding, good por, heavy oil stn SS md-tlrk brwn QTZ: w consol, excl srtg, massivelno bedding, good por, SS mtl•drk bnvn QTZ SS as above, mod - heavy oil stain SS mtl-drk bnvn QTZ SS as above; motl - heavy oil stain SS md-drk brwn QTZ SS as above, mod - heavy oil stain SS md-drk brwn QTZ SS as above, motl - heavy oil stain SS md-drk brwn QTZ SS as above, motl - heavy oil stain SS md-drk brwn QTZ: w consol, v-w srttl, massivelno bedding, good por, heavy oil stn SS md-drk bnvn QTZ: w consol, v-w srtd, massivelno bedding, good por, heavy oil stn SS mtl-drk brwn QTZ: w consol, vw srtd, massive/no bedding, good por, heavy oil stn SS md-drk brwn QTZ: w consoi, v-w srttl, massive/no bedding, good por, heavy oil stn Page 5 of 12 i . MPF-99i Core Chip Descriptions.xls 8904 Depth MD 8905 8906 8907 8908 8909 8910 8911 8912 8913 8914 8915 8916 8917 8918 8919 8920 8921 8922 ~l~°ir ,r,,~ ~ 8923 SS, Otzose, w srtd, vf-f grnd, some qtz og, no visible bedding excpt for occ wispy, discont shale SS mtl-drk brwn laminations Lithology Color cnsl Grainsize Roundness Poro sity Cement Description Lith % ~ N~ E ° ' m °7 m N N C ` % T vn~ Constituents Oil Shows SS, Qtzose, w srtd, uf-f grnd, some qtr og, no visible betltling excpt for occ wispy, discont shale SS md•tlrk bnvn ~ laminations SS md-tlrk bnvn Quartz SS, massive , good p& p heavy oil stain SS md-drk bnvn Quartz SS, massive , good p& p heavy oil stain ~ SS: w srttl, vf-f grntl ss, some qtr og, v-f wispy SS md-drk brwn '~ clay/shale laminations SS md-tlrk brwn Quartz SS, massive , good p& p heavy oil stain SS md-tlrk brwn Quartz SS, massive , good p& p heavy oil stain ° Predominantly SS w! minor clay/shale lamin. Mod oil SS md-drk brwn ° ~ stn Predominantly SS wl minor clay/shale lamin. Mod oil SS mtl-tlrk brwn stn Predominantly SS w/ minor claylshale lamin. Mod oil SS md-tlrk brwn ~ iz stn ~~ Predominantly SS wl minor claylshale lamin. Motl oil SS mtl-tlrk brwn „ `. 4,: stn SS md-drk brwn Quartr SS, massive , gootl p& p heavy oil stain SS mtl-tlrk brwn "~ Quartz SS, massive , gootl p& p heavy oil stain SS/Sh (~50/50) clr/glssy Qtz; FNF gr, v-w srtd, w/ tr silt, motl to heavy oil-stain; shale lamin and sider Interlam SSlSh md-tlrk brwn ir sitlr cmnt lenses SS/Sh (~50l50) clr(glssy Qtr; FNF gr, v-w sRd, w/ tr silt, mod 1o heavy oil-stain; shale lamin and sider Interlam SSlSh md•drk brwn tr sidr emnt lenses SS/Sh (-50/50) clrlglssy Qtz; FNF gr, v-w srtd, w( tr silt, mod to heavy oil-stain; shale lamin and sitler Interlam SS/Sh md-drk bnvn tr sidr emnt lenses SS/Sh (~50/5D) cldglssy Qtz; FNF gr, v-w srtd, w/ tr silt, mod to heavy oil-stain; shale lamin and sider Interlam SS/Sh md-tlrk bnvn tr sidr emnt lenses SS md-drk bnvn Quartz SS, massive , good p& p heavy oil stain Interlam SS/Sh md-drk bnvn SS WI 10% Sh laminations, as above s ~ Page 6 of 12 MPF-99i Core Chip Descriptions.xls 5924 Ca~e °~ _ ~., ~ ~ ~ ~_ . e : ~~ ~ ~ 8924 Interlam SslSlsts h 30:30:40); ss: v-f gmtl, w SSlSIsUSh med-drk brwnlgry srttl, qtz og. Slst sli arenaceous. Depth Lithology Color cnsl Grainsize Roundness P oros ity Cement Description MD Lith o~ ~in~S"E ~ > ~ ~ ro uroi in c '~ % Type Constituents 011 ShOwS 8925 SS/ShlSlst mtl-tlrk brnlgry ~ Interlam SS/Sh/Slst (60:20:20) Thin wispy It gry sh lam (5%) in fairly massive ss wl 8926 visible lam due to change in grain size. SS v S5 med-drk brn micaceous along some lam, freq qtr og. 892~ Massive ss no vis~bie bedding) w/ 5% ihin It gry sh SS med-drk brn ~ lam 8928 Sity Sh drk brn-gry Thin (<5%) ss lam (vtgrn) in slty sh 8929 SSlShJSlst It gry / med-drk bm x Lt gry sh laminations/ med brn ss! med bm slst 8830 SS md•drk brn No visible betldingllaminatlons, tr qtz og 8831 a SS a/a w! thin v micaceous, fissile md-drk gry, sli SS md-drk bm z silty, shale lam $$32 a wl decrease mica content in shale SS md-drk brn laminations. 8833 ~ i Increasing frequency and ihicker silty shale to siltst Dom SS md•drk brn ~ ~ ~~ ~_ lam. 8834 " ' ~< Dom ss wl incr qiz og and It•metl gry very micaceous Dom SS mtl-drk brn (incr from above) shale laminations 8835 ~ Dom ss wl incr qtz og and It-med gry very micaceous Dom SS md-drk brn (incr from above) shale laminations 8836 SS mtl-drk bm ~ SS w! thin med gry sh lam, slight decr mica content 8837 SS w/ increasing frequency, thickness of gry sh SS/Sh mtl-drk brnlgry laminations 8838 SS/Sh md-drk brn/gry SS tlom w/ incr amount shale laminations 8839 Drk gry, sli silty, micaceous shale w/ med-drk gry Sh drk gry sltst. Shale, drk gry, slightly silty, thicker lam than above, aaao w! vf, It brn ss, incr cementation, laminations in shale. ShISS md-tlrk bm/gry Med bm ss 50% Shale, drk gry, slightly silty, thicker lam than above, 8841 w! vf, It bm ss, incr cementation, laminations in shale. ShISS md-drk bm/gry Med brn ss 50% 8842 Decrease thickness and frequency o shale SS med-drk brn laminations, partings wl wany luster • ~ Page 7 of 12 MPF-99i Core Chip Descriptions,xls 8843 Medium gry sh/ waxy luster on bedding planes; v Sh mtl gry thin, vf gmd ss lam 8844 As above w visible micro fracture cutting 3 ss lam; Dam Sh md gry ss lam v thin. Depth Lithology Color cnsl Grainsize Roundness P oros ity Cement Description MD Lith % ~ N'S E ~ > m ~°' ro ui°, ~+ ~ '~ % Type Constituents 011 ShOWS 8845 med gray shale to sitst w/ ihin antl freq tlistorted ss ShlSltst mtl gry laminations; 8846 Sltst md gry 8847 Sltst md gry Dom silstone wl v thin ss laminations 8848 Dom shale, sli silty; very thin ss laminations both Sh drk gry stained and more tightly cemented antl unstainetl 6849 Silty shale as above w/ increasing number and Sh metl-drk gry thickness of ss laminations antl lenses 8850 Silty shale as above w/ number and thickness of ss Sh med•drk gry laminations antl lenses as above 8851 Silty shale as above w/ decreasing amount of ss Sh med-drk gry laminations and lenses 8852 As above silty shale to siltstone, continued Silty Sh/Sist md-drk gry decreasing amount of ss s a ove s a e si ty s a e w increasing ss 8853 Silty ShlSlst md-drk gry lamination thickness 8854 Silty Sh/Slst md•drk gry As above shalelsilty shale Core 6 ~ . ~ ,. . ., . 8954 `~ " Vf•f gmtl, silty qtr ss w/ thin metl gry shale Dom SS mtl-tlrk bm laminations ~; Silty, micaceous shale wl thin med brn vi ss 8955 ~° Ienses/IaminaNons and tight, unstained ss Dom Sh md gry laminations and burrow fill 5956 Dark gry, silty, micaceous sh w! vf-f grnd brn ss and Sh/SS md brn/drk gry unstained tlghi ss 8957 Dark gry, silty, micaceous sh w/ vf-f grnd brn ss; NO ShISS md brnldrk gry visible unstained, tlghter ss in chip 8958 ShISS md brn/drk gry Dark gry, silty, micaceous sh wl vf-f grnd brn ss 8959 Good visible porosiry in ss; occas med grn qtz; SS md-drk brn interlam wl drk gry silry, micaceous shale 8960 SS mtl-drk brn SS as above wl decrease in % sh laminations ~ ~ Page 8 of 12 MPF-99i Core Chip Descriptions.xls 8961 ' Increasing % of shale / siltstone laminations in med SSIShlSlst med -drk brnlgry brn, good visible parosity ss Increasing % of shale / siltstone laminations in med 8962 brn, good visible porosity ss. Shale: drk gry w/ waxy SSlSh/Slst med -drk brn/gry luster along some bedding p~anes Depth Lithology Color cnsl Grainsize Ro~naness aoms~~y Cement Description MD Lith % ~N~'~E ~ > ~ ~ ~ N N C w % Type Constituents 011 ShOwS 8963 Sh md-drk gry fi~ Shale w/ very few ss laminationsllenses 8964 g` ~ Dom metl brn vf-f gmtl ss w/ good visible porosity wl SS md -drk bm K; med -drk gry, micaceous shale 8965 ~' ~ Interlaminated shale antl - gmd ss wl gootl visible ShISS md-drk brn/gry ~ porosity 8966 =~ Med - drk brwn, vf-f gmtl, tr med gm, w srtd, w SS md-tlrk brn ~ consolidated, occas qtz og, excellent visible porosity 8967 SS md-tlrk brn ~ SS as above 8968 SS md•drk bm ~: SS as above 8969 S5 md•drk brn SS as above 8970 SS/Sh md-drk bmlgry u~ Interbedtled micaceous ss and sh 8971 SS/Sh md-tlrk bmlgry ~" Interbedded micaceous ss antl sh $972 nte e e micaceous ss an s; increasing Sh/SS mtl-tlrk bm/gry amounts shale; some visible good porosity ss $973 nter e e micaceous ss an s; increasiog Sh/SS mtl-tlrk bm/gry amounts shale; some visible gootl porosity ss Interbedded micaceous ss antl sh; increasing 8974 ~~ amounts shale; some visible excellent porosity ssl SS15h md-drk bm/gry q some very tight 8975 Sltst md-drk brn Slgithly arenaceous slststone 8976 Interlaminated siltstone and ss; some sands good SIsUSS metl-tlk brn visible porositylsome poor visible porosity 8977 Interlaminated ss !sh (70130); ss ranges from oil- SS/Sh md-drk brn/gry stained and gootl visible porosity to unstainetl, tight 8978 Dom ss w/ good visible porosity; -10% shale SS md-drk brn laminations $979 Interlam micaceous sltsUsslsh; ss sli to very silty and SlstlSSlSh med-tlrk bm/gry micaceous; ss overall good visibie porosity 89aQ Micaceous ss / shale taminations. S overall wl SS med-tlrk brn good visible porosity ~ CJ Page 9 of 12 MPF-99i Care Chip Descriptions.xls $981 Decrease amount of shale lam; ss good visible SS md-drk brn porosity $9a2 Inlerlaminated ss to sltst antl shale; a I very SS1SIty Sh med-drk brnlgry micaceous Depth Lithology Color cnsl Grainsize poundness P orosit y Cement Description MD Lith % ~ " ~ ~ ~ ° ' ` °1 m N ~' ~ "~ % Type Constituents 011 ShOwS 8983 Micaceous and carbonaceous shalelsltst w/ ss Sh/Sltst md brn/gry bedding with good visible porosity 8984 Do~ ss w! good visible porosity; very thin dark gry sh SS md-drk brn laminations COre 7 Dorn vf•f grnd, tr med grn, w srid ss w/ qtz og and 8984 good visible porosity. Very rare and thin med gray SS med-drk brn sha~e laminations ~ Darn gry silty, micaceous shale w/ vf-f ss laminations 8985 ~ q / lenses. Some laminations wispy. SS visible Sh/SS/Slst md-dk bm/ gry ~` ' porosity good io poor. Dom md bm, micaceous ss w/ qtz og and good to 8986 poot visible porosity. Unstained ss laminations and Dom S5 md bm burrow fill 6987 Dom Sh drk gry Dr(t gry, tlense, non-tissii, sil micaceous, sii silty. Med • drk gry sh w! It-mtl brn ss laminations and 898$ `~ lenses wl good to poor visible porosity. Micro ShISS med-drk brn/gry ~ fracture visible cutting some ss laminations ~ ` Dam SS w/ med-drk gry siltsone antl silty shale ~~; bedsAaminations. SS/ Sh interface freq wispy, ~ bedding slip faces visible. SS visible porosity ranges 8989 Dom 5S mtl-drk brn ' „ fran good to poor 8990 r~ Dom SS, well sortd, micaceous, qtr og, no visible Dom SS md-drk brn bedding wl tr drk gry silty shale laminations 8991 Dan ss wl good visible porosity w/lhin shale (It-md Dom SS md-drk bnvn gry) laminations Irxrease in unsiained / tight ss laminations wl poor 8992 visible porosity. Thin and infrequent shale Dom SS md•drk brxn laminations SS w/ good to moderated porosity, thin/infrequent 8993 tight ss laminations; think / infrequent shale Dom SS md•tlrk brw~ laminations ~ • Page 10 of 12 MPF-99i Core Chip Descriptions.xls ¢~~ ~{ Interlaminated ss (massive, good visible porosity) w! 8994 = ss (It brown to dear, poor visible porosity) " ~ laminations and lenses and thin It-tlrk gry shale SSlSh md-drk brn/gry laminations 8995 Sh/SS md-drk bm/gry Increase shale and unstained ss Depth Lithology Color cnsl Grainsize Roundness P orosiry Cement Description MD Lith % ~"~~~ 0 ' m ~ ftl N N ~ ` ~ /a Type Constituents Oil Shows 8996 ShISS/Slst md-tlrk brnlgry ~ Sh(SS( w/ Slst 8997 Sh w/ thinner ss laminationsllenses w/ some thicker Sh md-tlrk gry ~,~ ss (good visible porosity) laminations 8998 ~ Dom ss w/ good visible porsotiy antl few unstained SS med-drk brn k lensesllaminations. Few shale laminations 8999 `~ No visible bedding /laminations, excellent visible Dom SS md-drk brn ~ porosity. 9000 ,f: No visible bedding /laminations, excellent visible Dom SS md-drk brn porosity. 9001 Intedaminated ss (dom gootl visible porosity), shale, SS/ShlSlst mtl-drk brnlgry siltstone. Slump and fill features visible. 9002 Slst mtl-tlrk brn Slightly arenaceous slst; no apparent bedtling 9003 Shale w/ ss laminations w/ good to poor visible ShISS mtl-tlrk brnlgry porosity 9004 a e w ss aminations w goo o poor visi e ShISS mtl-drk bmlgry ~~ porosity 9005 Slst md-tlrk bm Sltst wl ss and shale laminations 9006 `" Med-drk brn ss w! unstainetl ss laminations/lenses SS mtl brn and med gry shale laminations Med-drk brn ss w/ unstained ss lami~ationsllenses 9007 and decrease in number of ined gry shale SS md•drk bm y~ laminabons 9008 Slst metl-drk brn Slightly arenaceous slst 9009 Thin shale laminations in interbedded stained and SS md-drk bm unstained ss / lenses 9010 Micaceous shale interbeddetl wl stained and ShISS md-drk bm/gry unstained ss 9011 Shl51sUSS md-drkbrn/gry Interbedded shale/sitstone/ss 9012 ShlSIsUSS md•drkbrn/gry Interbeddetl shalelsilstone/ss 9013 Sh/SIsUSS md-drkbrn/gry Interbedded shale/silsione/ss ~~ ~ Page 11 of 12 MPF-99i Core Chip Descriptions.xls 9014~ SS ~med-drk brn ss lamination wl thin shalelslstnl unstainetl ss i • Page 12 of 12 MPF-99 C1 ~ t?~ _ 1 Alaska State Chip Sample Descriptions 8786' MD to 8831' MD Cut 45' Recovered 45'7" 101% recovery W@~~: MPF-99 API # 50-029-23332-00 Geologistls: Weeks I Zarndt Location: Date: 11912007 ,~ ~~ ~ ,;:,r ~ ~ .~u :.~;ing lui~J ~;ir, ~~F.1~n-goid ~i~ (C; ~SG~iIC~ Depth Samp Lithology Color Grainsize oundnes Porosity Cement Description MD Qual Lith ° "' ~ E ° ' m °' m ~' ~' ~` % Type Constituents 011 ShOWS 8786 G md bm - md Dom med drk gry blocky sh (mod sft) wl micro lam of vis stain: It ambr on ss lam only; ShISItsUSS tlrk gry md gry and md brn slst and md brn vf ss fnt yllw in ss lam only 8787 F Shale md gry Blcky, mod hard shale wl minor silt, some mica None 8788 F Blky md gry shale w! micro lam of It bm slst, and lam vis stain: It amber to none on ss clear to Ilt brn- and interbedded dear to It bm vf-md grnd qtr ss wl tr lamlbeds; fluor: none to v fnt dl ShlSIsUSS mtl gry glauc (drk grn) silica cmnt; rounded ss-filled burrow yllw ~ vis stain: none to fnt ambr on ss 8789 G ~ Md brn-gry micaceous slst wldr to It brn vf-f ss lam lam; fluor: none to evn dl gld on SlstsUSS mtl brn-gry w! tr bl-grn glauc; pyritic lam; drk gry sh lam ss med bm vf-f grnd v silty, argillaceous ss, tr pyr ~ods; vis stain: none to fnt ambr in ss; $790 G S5 med brn `~~ ~ 30 silica, clay md gry sltst I silty sh lam. fluor: evn v tll gld on ss 8791 G ~ °i ~ Md-drk gry slty to sli arenaceous, micaceous, tr carb, Shale md-drk gry V ~ tr pyr nodules shale, some fissility observed None ~,~ i ~ It-md bm, v slty, v arg ss. Contact wl dk gy, slty vis stain: none to fnt ambr in ss; 8792 G SS15h It brn-drk gy N~~ ~' ti~ 35 silica, cly shale v abrupt fluor: evn v tll gld on ss vis stain: none to nt am r in ss; 8793 F Slst md brn Dom md gry arg slst w! ss lam fluor: evn v dl gld on ss tain an uor on : nt am r 8794 F Shale dk gry Dom dk gry, slty shale wl lam of slst and vf ss dl yllwlgld ~ Very micaceous, tlk gry slty shale w! slst antl vf ss tain an uor on : nt am r 8795 F Shale dk gry ~~~ ~ lam dl yllwlgld e gry, micaceous, argi aceous s st inter e e w tain an uor on : nt am r 8796 F Slst md gry vf, slty, arg ss dl yllwlgld 8797 F SlstISSISh ~~~ It bm to dk gry ~, 30 silica, dy Interbedded slsUshalelss Stain and fluor on ss only 8798 G Interbetltletl as above. VF ss and pyrite filletl SS vis stain: fnt ambr w! tll yllw SIstISSISh It brn to dk gry ~~~ 3C1 silica, cly burrows obseerved fluor 8799 G ~~~~~~ Interbedded as above. VF ss and pyrite filled SS vis stain: fnt ambr wl dl yllw SIsUSS1Sh It bm to dk gry 30 silica, cly burrows obseerved fluor . ~ Dom micaceous slst wl drk gry shale and thicker Vis stain on ss: ambr Fluor: 8800 G SIstISSISh It brn to dk gry ~ ~~ 30 silica, cly laminae of vf ss. even dl gld 8801 G '~ ~~~~ Vis stain: ambr. Fluor: evn It Shale dk gry Dk gry, sl slry shale, wl v thin slsU ss lam yllw .r ~ ec N • d ~ Page 1 of 7 ~-~ ~. c~ 6 ~ 1 ~~ MPF-99 C1 Alaska State Chip Sample Descri 8786' MD to 8831' MD Cut 45' Recovered 45'7" 101% recove ell: MPF-99 API # 50-029-23332-00 Geoloqistls: Weeks ! Zarndt Depth Samp Lithology Color Grainsize oundnes Porosiry Gement Description MD Qual Lith U ~l j " £ U > ` m N C m u~l N ~ `~ o /o Type Constituents 011 ShOWs 8802 G SS vis stain: ambr. Fluor: It yllv~ Shale md-drk gry ~, j Dk gry, slty shale I incr thickness of slsUss lam in some lam; dull gold in others 8803 F ~ Dom drk gry shale wl thin ss lam. Difficult to Cannot be tlone due to coating of Shale dk gry describe without breaking as is coated wl wring fluid coring fluid Not possible to 8804 describe without Not possible to describe without breaking; coated wl Cannot be done due to coating of breaking coring fluid coring fluitl ~ Dom med brn-gry arenaceous slst wl lam of drk gry SS: vis stain= It bm; fluor: evn dl 8805 F Slst md gry , ~ sh yilw ;i ~ : vis stain= t m; uor: evn 8806 G ShalelSlst md gry Dom med brn-gry slsi, burrow fills, drk gry sh yllw : vis stain= t rn; uor: evn 8807 G ShalelSlsUSS It brn-dk gry ~ Interbedded shalelslsUss, burrows, thin lamina yllw 8808 F Dom drk gry shale. Difficult to describe wlout Cannot be done due to coating of Shale dk gry ~ ~~~ breaking as coatetl wl coring fluid coring fluid Difficult to tlescribe wlout breaking, covered in tlrilling Diff due to coring fluid; cut edge 8809 F Slst It brn u ~ fluid, cut edge hints at slst Fluor: even It yellow Vis oil stain on ss: fnt amb~r; 8810 G ShISIsUSS It bm-dk gry Interbedded ! interlam shalelslsUss Fluor: v fnt gld Dom gy, sli silty shale wl thin sltstonelss lam. Occas SS: vis stain none to It ambr, 8811 G Sh md-drk gry pyr cmntd ss Fluor. even It yllw Dom shale; waxy betlding planes observed. Shale Vs Stn: SS: fnt ambr; Fluor: SS: 8812 F ShalelSlsUSS It brn-dk gry , interbedded wl slst and vf ss. evn fnt yllw ~ Dom shale; waxy bedding planes observed. Shale Vs Stn: SS: fnt ambr, Fluor. SS: 8813 G ShalelSlsUSS It brn-dk gry ~ ; interbedded wl slst and vf ss. evn fnt yliw 8814 G Silty Sh med-drk gry Silty shale w! pyrite notlules and tr micaeous maierial mo stain, no fluor A~ Alternating laminae (up to 1 cm thick) of shlsitst w No vis oil stain, fl in slt lam=evn 8815 G Slstst I Sh It brn I drk gry poss tr v f sand grains brt yllw ~ ~ Page 2 of 7 MPf=-99 C1 Alaska State Chip Sample Descriptions 8786' MD to 8831' MD Cut 45' Recovered 45'7" 101% recovery Well: MPF-99 API # 50-029-23332•00 Geologistls: Weeks 1 Zarndt Location: Date: 1/912007 Mir~~ra1-o~ a.rs~~ rorir~~ 8u~d ~'~ has f~f~at rl :a ~;~~v°: c~~lc~ flu~~~;~c~rc~ Depth Samp Lithology Color Grainsize oundnes Porosity Cement Description MD Qual Lith ~ '~ ' ~ ~ " ' m °1 `m ~' `" ~` % Type Constituents 011 ShOWS Interbedded drk gry slty, sli carb shale; It-md bm gry 8816 G ~~. arenaceous, sli carb, sli pyritic slst; clr - It-md bm, SS: fnt ambr to none: Fluor: SIsUShISS It bm -drk gry ;--' 3g silica, cly slty 1 arg, v sli pyritic, vf-md ss. none to even dl gld : nt am r to none: uor: 8817 G Shale md-drk gry ~; Dom md-drk gry, v sli slty shale, tr vf, slty ss lam none to even dl gld Dom md-drk gry, sli silty shale wl interbedded sltst nt am r to none: uor: 8818 G Shale md-dric gry and vf ss. none to even dl gld ~~~ nt am r to none: uor: 8819 F ShalelSlstlSS It brn-dk gry Md-drk gry slightly silty shale wl sli incr sltst I ss lam none to even dl gld nt am r to none: uor: 8820 F SSISIsUSh It brn-tlk gry 35 silica, cly Interbedded sslslsUsh w! ss dom. none to even dl gld =: Dom It gry argillac, micaceous sltst wl lam of vf-f, 8821 G slty, arg ss. Contact wl drk gry shale (w! thin sltst SlstlSh It-dk gry antl pyritic ss lam) Md-dk gry slty, arenaceous shale w/ lam of siltylarg, $$22 F ~s~° It brn vf-f gmtl ss. Freq sltst lam wl carb material. Tr Vis fnt ambr stain in ss; fluor. ss Silty Sh md-drk gry pyr nod in sh none to dl gltl 8823 G ~~~~~ Md-drk gry slty shale clr-It bm slst, vflf grnd, siltylarg Fnt ambr stn on ss; ss fluor: none Shale md-drk gry ss lam. Occas pyr notls ( burrow-fill to dl gld 8824 G md-tlrk gry to ~' ~ silica, cly, Silty shale wl thick, siltylarg, vf-f grnd ss lam; occas Us fnt ambr stain in ss; fluor: ss Silty Sh 1 SS It bm 35 pyr pyr cmntd ss lam none to tll gld Shale, sli silty, tr carb, tr pyr wl It bm siltylarg, vf ss Vis fnt ambr stain in ss; fluor. ss 8825 G Shale md-drk gry lam and sltstn lam (It gry to fnt brn) none t~ tll gld ~ Md gry shale, tr carb, ir pyr wl clr to It brn, siltylarg, 8826 G j ~, silica, cly, vf ss lam (freq pyr cmnt defining some lam) and dr to Vis fnt ambr stain in some ss; ShalelSS It brn-mtl gry I ~~'~ 35 pyr v It bm/gry slst lam fluor. ss none to dl gld 8827 G ~~ Dom blky, hartl shale wl tr slt; decr frequency It brn Shale md-drk gry vf, sltylarg ss lam; freq pyr notls none $$Z$ G md brn-drk Dom blky, brn-gry-dk gry shl wl freq pyr nods; incr py minimal staining in ss lams; v fnt Shale gry cementation in vf, sltylarg ss lams dl gld fluor '" Dom blky md-drk gry shale w/ incr pyr cmnt-filled 8829 G burr~ws antl pyr cmnltl lam. Waxy fissility observed. Sft carb lam above waxy fissle break. V micaceous, ShalelSlst md-drk gry ~ar ~~ sli carb slitst None ~ ~ Page 3 of 7 MPF~99 C1 Alaska State Chip Sample De~criptions 8786' MD to 8831' MD Cut 45' ell: MPF-99 IAPI # I 50-029-23332-00 IGeoloqistls; Weeks 1 Zarndt Depth Samp Lithology Color Grainsize oundnes Porosity Gement Description MD Qual Lith ° " > ~ ~ U p > ~ N C ~o ~p ~' ~ ~' 'O L ~ %o Type Constituents 011 ShOWS 8830 G Shale md-drk gry '"~ ~~ Dom blky brn md-drk gry shale, sl slty wl vf-f grnd, sli slty, v wl cmntd wl pyr ss lam. vis stain in ss: none to fnt ambr. Fluor in ss none to tll fnt gld 8831 F Shale mtl-tlrk gry `~; ;; Dom blky brn md-drk gry shale, sl silty wl decr frequency vf, slty ss lam but incr pyr cmnt in lam present None visible Entl of core #1 ~ ~ Paye 4 of 7 MPF-99 C1 Alaska State Chip Sample Descri to 8831' MD Cut 45' Recovered 45'7" 101% reco~ 50-029-23332-00 Geologistls: Weeks I Zarndt on: Depth Samp Lithology Color Grainsize oundnes Porosity Cement Description MD Qual Lith ° ~' ' ~ ~ ~ U ' ~ ~ ~ m m " ~ `~ a L ~ % Type Constituents 011 ShOWS i • Page 5 of 7 MPF-99 C2 I Alaska State Chip Sample Descriptions I Cut 35' Recovered 5' 14% ~ Well: MPF-99 ~API # 50-029-23332-00 ~Geologistls: Weeks I Zarndt ~ January 10, 2007 Depth Samp Color Grainsize oundnes Porasity iq,~ :`; ~, ' Gement ° --kk Description MD Qual Lith ~ "' ~ ~ ° ' o~ °' m N `~ ~` ~ % Type Constituents Oil ShOwS Med gray, sli silty shale wI tr pyr notls, tr carb material; waxy bedding lams observed on some 8831 G betlding planes; clear lo It brwn vf grntl, silty ss lams SS: some tight unstained lams, I grades io md brn-gry slst. Pyr cmntd in part, pyr- some fnt amber lams. Fluor: Shale metl gry filled burrow observed. none to v fnt dl gltl. Metl-drk gry slst to v silty shale. Increased pyrite 8832 G nodules. Sample very induratetl. Cannot break to determine laminations insitle. Waxy lamination ShalelSlst metl-drk gry observed at outer betlding surface None Drk gry slty, pyritic shale w! abundant waxy 8834 G laminations along betlding planes. Frequent partings Shale drk gry along these waxy laminations. None Very tlense, drk gry pyritic, silty shale wl infrequent, 8835 G Shale drk gry thin vf It brn ss lams None Very tlense, silty shale wl waxy lam apparent on 8836 G Shael dr gry outside of chip. Some ss lams apparent None i ~ Page G of 7 MPF-99 C3 Alaska State Chip Sample Descriptions Cut; 8872' MD to 8876' MD Cut 4' Recovered 3" 6% recovery Well: MPF-99 API # 50-029•23332-00 Geologistls: Weeks 1 Zarndt Location: Date: 1/12/2Q07 Depth Samp Color Grainsize oundnes Porosiry ~ Cement ~u ` Description MD Qual Lith ~ " ' ~ E U U ' i N C ~a ~p " ` " 'O ~ ~ % Type Constituents 011 ShOws 8872 G SS md brwn 'y ~' Moderately friable, medium brown, vf-f grained, well sorted, quartz ss Visible metl brown oil stain wl fnt yllw to brt yllow fluor 0 ~ ~J Page 7 of 7
