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Home My WebLink About205-090By Grace Christianson at 1:32 pm, Aug 15, 2023 Abandoned 7/25/2023 JSB RBDMS JSB 081723 xGDSR-8/31/23 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.15 10:42:17 - 08'00' Taylor Wellman (2143)Drilling Manager 08/15/23 Monty M Myers _____________________________________________________________________________________ Created By: JNL 8/10/2023 SCHEMATIC Milne Point Unit Well: MPU F-89 Last Completed: 8/20/2005 PTD: 205-090 GENERAL WELL INFO API: 50-029-23268-00-00 Drilled, Cased & Completed by Doyon 14 - 8/20/2005 Perforate – 3/6/2015 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 113' 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 6,723’ 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surface 11,186’ 5-1/2” Liner 17 / L-80 IBT-M 4.892 11,072’ 11,528’ 3-1/2” Liner 9.2 / L-80 / IBT 2.992 11,015’ 11,795’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TC-II 3.958 Surface 11,022’ JEWELRY DETAIL No Depth Item 1 2,992’ 4-1/2” HES X-Nipple w/ MCX .656 Bean –Pulled 4/5/23 2 10,966’ 4-1/2” HES X-Nipple ID= 3.813” 3 10,986’ 7-5/8”x4.5”Baker S-3 Permanent Packer 4 11,010’ 4-1/2” HES XN-Nipple ID= 3.725” No Go 5 11,015’ 7-5/8” x 5.5” Baker Tie Back Sleeve 6 11,022’ WLEG 7 11,026’ 7-5/8” x 5.5” Baker ZXP Liner Packer 8 11,032’ 7-5/8” x 5.5” Baker HMC Liner Hanger 9 11,072’ 7-5/8” x 5.5” Baker Tie Back Sleeve 10 11,083’ 7-5/8” x 5.5” Baker ZXP Liner Packer 11 11,090’ 7-5/8” x 5.5” Baker HMC Liner Hanger 12 11,490’ Whipstock PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 11,471’ 11,511’ 7,111’ 7,149’ 40 3/6/2015 Closed Kup. B Sands 11,514’ 11,534’ 7,152’ 7,171’ 20 3/6/2015 Closed Kup. A3/A2 Sands 11,551’ 11,588’ 7,188’ 7,223’ 37 3/6/2015 Closed Kup. A1 Sands 11,592’ 11,603’ 7,227’ 7,238’ 11 12/22/2005 Closed Kup. A1 Sands 11,603’ 11,623’ 7,238’ 7,257’ 20 1/6/2006 Closed Kup. A1 Sands 11,623’ 11,643’ 7,257’ 7,277’ 20 1/1/2006 Closed TD =11,795’ (MD) / TD = 7,424’(TVD) 20” Orig. KB Elev.: 45.18’/ GL Elev.: 11.5’ 7” 3 5, 7 & 86 12 10.75” Howco ES Cementer @ 2,785 MD 10-3/4” 1 2 Whipstock set @ 11,490’ PBTD =11,490’(MD) / PBTD = 7,129’(TVD) 4 5-1/2” 3-1/2” 9, 10 & 11 TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” 5M FMC ZGen 5 w/ 11” x 4.5” FMC Tbg. Hng. w/ 4.5” TC-II & 4” CIW ‘H’ BPV Profile OPEN HOLE / CEMENT DETAIL 42" 260 sx of Arcticset (Approx.) 13-1/2" 658 sx ASL, 644 sx Class ‘G’ 9-7/8” 275 sx Class ‘G’ 6-3/4” 79 sx Class ‘G’ 4-3/4” 123 sx Class ‘G’ WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 60 to 68 deg. f/ 5,050’ to 9,800’ ACTIVITYDATE SUMMARY 7/6/2023 ***WELL S/I ON ARRIVAL*** DRIFTED w/ 20' x 2.70" DUMMY WHIPSTOCK TO 11,500' SLMRAN 24 ARM REED CALIPER, FROM 11,500' SLM TO 10,850' SLM GOOD DATA FROM REED RAN KJ, 4 1/2" BLB, 2.70" GAUGE RING S/D ON 3 1/2" LINER @ 11,015' MD ***CONTINUE 7/7/23*** 7/7/2023 ***CONTINUE FROM 7/6/23*** SET 4-1/2" PXN PLUG @ 11,010' MD LRS PERFORMED PASSING MIT-T TO 4,000 psi LRS PERFORMED PASSING MIT-IA TO 2,700 psi PULLED 4-1/2" PXN PLUG FROM 11,010' MD ***WELL S/I ON DEPARTURE*** 7/7/2023 Assist Slickline, MIT-T 4000 psi PASSED, MIT-IA 2700 psi PASSED 7/21/2023 ***WELL S/I ON ARRIVAL*** RAN SBHPS AS PER PROCEDURE. ***WSR CONTINUED ON 7-22-23*** 7/22/2023 ***WSR CONTINUED FROM 7-21-23*** ASSIST WELL SUPPORT IN INSTALLING COMPANION VALVE. R/D SLICKLINE EQUIPMENT. ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU MPF-89 Activity Date Ops Summary 7/22/2023 Spot both rig modules over MPF-89A and set down. Accept rig 00:00. Start MIRU checklists. Use 1500 psi well pressure for LTT on SV, MV good. Install MPD line. Remove tree cap, install BOPs. 7/23/2023 Continue with RU checklists. NU BOPE. Install integral / check valve on B5. Perform top drive inspection. Fluid pack rig. Install injector. Test Gas alarms. All pass. Initial BOPE 250 psi / 4000 psi. 7-1/16" 5K Annular, Blind/ Shear, 2.0" Pipe / Slip, 2-3/8" Pipe/ Slip, 2.0" Pipe / Slip. Test 1: IRV, Packoff, C7, C9, C10, C11 Pass. Test 2: Blind / Shear, R2, BL2, C15 Pass. Test 3: Annular (2.0") TIW#2, B1, B4 Pass. Test 4: Upper 2.0" Pipe / Slip, TIW#1, B2, B3 Pass. Test 5: Lower 2" Pipe / Slip, C5, C6,C8, TV2 Pass. Test 6: Choke A, Choke C Pass. Test 7: 2-3/8" Pipe / Slip, C1, C4, TV1 Pass. Test 8: C2, C3 Pass. Accumulator draw down test. Rig down test joint and test risers. Install drilling risers. Get RKB measurements. Make up drillers side PDL. Test MPD line, Drilling risers, and PDL to 4000 psi. Test tiger tank line to 4000 psi. Good test. Install floats in BHI cable head and test, good. M/U BHA #1, nozzle w/ DPS. M/U injector to well. Circ 10 bbls MeOH to end of CT. Wait on load of 9.8# mud to arrive from Deadhorse. Mud arrives, start offloading. Start RIH. 1500 psi on well. Log CCL from 10900' to 11500'. PU 40k start swap well to 9.6# mud. POOH when mud reaches nozzle. 7/24/2023 Finish Pooh. Tag up. Close swabs. Put well on MPD. Lay down MWD w/ nozzle. Make up BHA#2 Whipstock in PDL lubricator. Pressure deploy. Rih w/ BHA#2 Whipstock. Rate: 0.35 bpm in, 0.65 bpm out. Mud Weight: 9.66 ppg in, 9.69 ppg out Window ECD: 12.3 ppg. Log down for tie-in from 11150' to 11306.19 MD (formation) with -27.5 correction. Log CCL from 11000' to 11250'. Run to set depth while correlating CCL. Rih to set depth of 11501.2' Bottom (TOWS @ 11490' ). Close EDC. Orientated @ 0 ROHS orientation. Pressure up. Taking weight. 4200 psi shear. Stacked 4.5K down. Good set. Pooh. Rate: 1.41 bpm in, 1.03 bpm out. Circ pressure: 2850psi. Mud Weight: 9.66 ppg in, 9.69 ppg out Window ECD: 12.3 ppg. Tag up and space out. Trap 900 psi. Pressure un-deploy BHA#2 Whipstock setting tool. Make up BHA#3 with NSAK 0.4 AKO motor, Reamer (2.79" Go / 2.80" Tight Go) Window mill (2.81" Go / 2.80" Nogo). Pressure deploy. Break circulation. Choke B stopped holding. Closed C13, Isolate flow. Blow down choke line. Inspect choke. RIH BHA #3 - Window Mill keep 12.25# ECD at window. Tie-in depth from 11220' correct -25.5'. Close EDC, dry tag whipstock 11491' up wt 35k. Mill 2.8" window from 11490.9'. 1.8 / 1.75 bpm In / Out. 9.66 / 9.72 bpm. Window ECD 12.24 ppg w/ 634 psi WHP. Mill 2.8" window from 11494.4'. 1.78 / 1.78 bpm In / Out. 9.65 / 9.69 bpm. Window ECD 12.20 ppg w/ 610 psi WHP ~2 bbl/hr losses. Start adding black product to mud. 7/25/2023 Mill 2.8" window from 11498' Bottom of window. 1.78 / 1.78 bpm In / Out. 9.65 / 9.69 bpm. Window ECD 12.20 ppg w/ 610 psi WHP ~2 bbl/hr losses. Start rathole at 11500' MD to 11510'. Pump sweeps. Ream Window. Perform 3 Reaming passes at 1 fpm. All reaming passes down at 0 ROHS (As milled). Ream up at: As milled, +15, -15. Rate: 1.73 bpm in, 1.72 bpm out. PUW: 37K, SOW: 15K. Shut down pumps, dry drift window at 0 ROHS (As milled) Clean. Final sample 50% formation. Pooh. Mud Weight: 9.67 ppg in, 9.70 ppg out. Rate: 2.08 bpm in, 1.59 bpm out Window ECD 12.3 ppg. Tag up and space out. Pressure un-deploy BHA#3 Window Milling. Stand off to side. Install nozzle. Jet stack while swapping BHA. Pressure deploy BHA#4 Build BHA. RIH with 3.25 drilling BHA #4 Build. Rate: 0.40 bpm in, 0.71 bpm out. Circ pressure: 1779 psi. Mud Weight: 9.65 ppg in, 9.72 ppg out Window ECD:12.33 ppg. Log down for tie-in from 11,200' MD (formation) with -27' correction. Close EDC. Pass window no issues go to min rate. Tag 11510' PU to breakover + 2' go to 1.8 bpm. Ease down and start drilling 3.25" build. PU and swap to shore power, no issues. Drill 3.25" build from 11530'. 1.84 / 1.83 bpm In / Out. Mud Wt 9.65 / 9.70#. Window ECD 12.24# w/ 560 psi WHP. ROP 25 - 50 fph w/ 1.5 - 2.5k DWOB. BHA wiper at 11600' clean up/down. 11660' 5 bbls lo/hi vis. 100' wiper from 11695' clean up/down. Drill 3.25" build from 11695'. 1.78 / 1.78 bpm In / Out. Mud Wt 9.65 / 9.71#. Window ECD 12.29# w/ 560 psi WHP. ROP 40 - 70 fph w/ 1.5 - 2.5k DWOB. 150' wiper from 11850' clean up/down. Drill 3.25" build from 11850'. 1.78 / 1.72 bpm In / Out. Mud Wt 9.66 / 9.76#. Window ECD 12.29# w/ 520 psi WHP. ROP 60 - 70 fph w/ 1.5k DWOB. 11915' 5 bbls lo/hi vis. Drill to 11920' TD of build section. Wiper to window, clean. Jog below window and pull through. Jog above window, open EDC. POOH pump 2.3 bpm keep 12.2# at window. 7/25/2023Spud Date: Well Name: Field: County/State: MP F-89A Milne Point Hilcorp Energy Company Composite Report , Alaska 50-029-23268-01-00API #: Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205054 7/6/2023 YELLOW JACKET CBL KBU 22-06 50133205500000 205054 7/2/2023 YELLOW JACKET CBL/PERF KBU 33-06X 50133205290000 203183 6/14/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/29/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/13/2023 YELLOW JACKET PERF KU 12-17 50133205770000 208089 6/14/2023 YELLOW JACKET PERF MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey MPU E-23 50029225700000 195094 6/23/2023 YELLOW JACKET CUT MPU L-43 50029231900000 203224 6/27/2023 YELLOW JACKET PERF PAXTON 12 50133207100000 223014 6/28/2023 YELLOW JACKET PERF Please include current contact information if different from above. T37830 T37830 T37831 T37831 T37831 T37832 T37833 T37834 T37835 T37836 T37837 MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.11 14:54:56 -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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230601 0935 APPROVAL MPU F-89 (PTD 205-090) Flowback Extension Request Date:Thursday, June 1, 2023 9:38:00 AM From: Rixse, Melvin G (OGC) Sent: Thursday, June 1, 2023 9:36 AM To: Scott Pessetto <Scott.Pessetto@hilcorp.com> Cc: Tom Fouts <tfouts@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: 20230601 0935 APPROVAL MPU F-89 (PTD 205-090) Flowback Extension Request Scott, Hilcorp is approved for an additional 60 day flow back with agreed configuration from email 3-24- 2023. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Thursday, June 1, 2023 8:38 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: RE: MPU F-89 (PTD 205-090) Flowback Extension Request Mel, One correction. The flowback was rigged up 4/4/2023, but did not commence until 4/10/23 due to crew availability. Current plan is to shut-in MPU F-89 on 6/9/23. Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 From: Scott Pessetto Sent: Thursday, June 1, 2023 7:53 AM To: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: MPU F-89 (PTD 205-090) Flowback Extension Request Mel, Well MPU F-89 (PTD 205-090) is flowing back per the approval received on 3/24/2023. The flow back of MPU F-89 started on 4/4/2023 and will reach its 60-day clock on 6/2/23 6/9/23. Reservoir pressure prior to the flowback in MPU F-89 was estimated at 4,778 psi based on the fluid level and surface tubing pressure. The latest test on MPU F-89 was 1,200 BWPD at 100% water cut, tested on 5/23/2023. The test prior on 5/1/2023 was 1,500 BWPD at 100% water cut. The purpose of the MPU F-89 flowback is to reduce pressure in the block prior to planned CTD sidetrack occurring in August out of MPU F-89 wellbore. Hilcorp requests a 60-day extension on the MPU F-89 flowback to continue lowering the reservoir pressure. Before continuing the flowback, Hilcorp will shut-in MPU F-89 to obtain an updated reservoir pressure and inspect surface hardline. The updated MPU F-89 reservoir pressure will be communicated to the AOGCC. All prior conditions of approval will be kept in place for the MPU F-89 flowback extension. Thank you, Scott Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 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. 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230324 1618 APPROVAL Flowback MPU F-89 (PTD 205-090) Flowback Request Date:Friday, March 24, 2023 4:20:31 PM Attachments:MPF-89i SCHEMATIC 4-2-2015.pdf F-89i Flowback Diagram.pptx From: Rixse, Melvin G (OGC) Sent: Friday, March 24, 2023 4:18 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: FW: MPU F-89 (PTD 205-090) Flowback Request Taylor, Hilcorp is approved to flowback well PTD 205-090, MPU F-89 for 60 days as per the attached flowback diagram. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday, March 17, 2023 12:33 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU F-89 (PTD 205-090) Flowback Request Mel, The well MPU F-89 (PTD 205-090) is very similar to the situation on MPU F-10. Both are injectors that are being made ready for coil tubing sidetracks in the coming months. We would like to request to flow back MPU F-89 to production via the same setup and conditions as MPU F-10 (see below). These COA’s have been updated the schematic and the estimated open choke production values for F-89. 1. Piping shall be configured as in the attached schematic. 2. A header or pump with the capability to deliver water at a pressure 30% greater than SITP and at a rate of 30% greater than maximum estimated open choke production of ~1,000 barrels of liquid per day. 3. The ability to deliver a 1.5 well bore volume KWF of 1 ppg > BHP gradient to location within 6 hours. 4. 24/7 man watch on MPU F pad. If you would like any additional information, please let me know and it will be provided. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC – Ops Engineer: Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Created By: TDF 4/2/2015 SCHEMATIC Milne Point Unit Well: MPU F-89i Last Completed: 8/20/2005 PTD: 205-090 TD =11,795’ (MD) / TD = 7,424’(TVD) 20” Orig. KB Elev.: 33.7’/ DF Elev.: 33.68’ (Doyon 14) 7” 3 5, 7 & 86 10.75” Howco ES Cementer @ 2,785 MD 10-3/4” 1 2 PBTD =11,761’(MD) / PBTD = 7,391’(TVD) 4 Kuparuk Sands 5-1/2” 3-1/2” 9, 10 & 11 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20"Conductor 91.1 / H-40 / N/A N/A Surface 113' 10-3/4"Surface 45.5 / L-80 / BTC 9.950 Surface 6,723’ 7-5/8" Intermediate 29.7 / L-80 / BTC Mod 6.875 Surface 11,186’ 5-1/2”Liner 17 / L-80 IBT-M 4.892 11,072’ 11,528’ 3-1/2”Liner 9.2 / L-80 / IBT 2.992 11,015’ 11,795’ TUBING DETAIL 4-1/2"Tubing 12.6 / L-80 / TC-II 3.958 Surface 8,253’ JEWELRY DETAIL No Depth Item 1 2,992’ 4-1/2” HES X-Nipple w/ MCX .656 Bean Installed on 7/13/2013 2 10,966’ 4-1/2” HES X-Nipple ID= 3.813” 3 10,986’ 7-5/8”x4.5”Baker S-3 Permanent Packer 4 11,010’ 4-1/2” HES XN-Nipple ID= 3.725” No Go 5 11,015’ 7-5/8” x 5.5” Baker Tie Back Sleeve 6 11,022’ WLEG 7 11,026’ 7-5/8” x 5.5” Baker ZXP Liner Packer 8 11,032’ 7-5/8” x 5.5” Baker HMC Liner Hanger 9 11,072’ 7-5/8” x 5.5” Baker Tie Back Sleeve 10 11,083’ 7-5/8” x 5.5” Baker ZXP Liner Packer 11 11,090’ 7-5/8” x 5.5” Baker HMC Liner Hanger PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 11,471’11,511’7,111’7,149’40 3/6/2015 Open Kup. B Sands 11,514’11,534’7,152’7,171’20 3/6/2015 Open Kup. A3/A2 Sands 11,551’11,588’7,188’7,223’37 3/6/2015 Open Kup. A1 Sands 11,592’11,603’7,227’7,238’11 12/22/2005 Open Kup. A1 Sands 11,603’11,623’7,238’7,257’20 1/6/2006 Open Kup. A1 Sands 11,623’11,643’7,257’7,277’20 1/1/2006 Open OPEN HOLE / CEMENT DETAIL 20"260 sx of Arcticset (Approx.) in a 42” Hole 10-3/4" 658 sx ASL, 644 sx Class ‘G’ in a 13-3/8” Hole 7-5/8”275 sx Class ‘G’ in a 9-7/8” Hole 5.5”79 sx Class ‘G’ in a 6-3/4” Hole 3.5”123 sx Class ‘G’ in a 4-3/4” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 60 to 68 deg. f/ 5,050’ to 9,800’ Hole Angle through perforations = 13 deg. TREE & WELLHEAD Tree 4-1/16” 5M FMC Wellhead 11” 5M FMC ZGen 5 w/ 11” x 4.5” FMC Tbg. Hng. w/ 4.5” TC-II & 4” CIW ‘H’ BPV Profile GENERAL WELL INFO API: 50-029-23268-00-00 Drilled, Cased & Completed by Doyon 14 - 8/20/2005 Perforate – 3/6/2015 F-89 (Injector) From Injection Header To Production Header Above this line is temporary hardline Swab SSV (Actated) Master Wing Check Choke Wing Choke Master SSV (Actated) Swab Bleed and Pressure Gauge Bleed and Pressure Gauge Choke Check F-87/86 (Producer) Below this line is permanent piping and pressure trips Needle valves to bleed (on top of tree) Needle valves to bleed (on top of tree) JLC 4/10/2023 RBDMS JSB 041123 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-89 MILNE PT UNIT F-89 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 F-89 50-029-23268-00-00 205-090-0 W SPT 6651 2050900 1663 2349 2349 2349 2348 33 74 78 78 4YRTST P Brian Bixby 8/14/2022 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-89 Inspection Date: Tubing OA Packer Depth 327 3045 2987 2977IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220815141912 BBL Pumped:3.3 BBL Returned:3.4 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 14:40:44 -08'00' STATE OF ALASKA RECEIVED AL _.<A OIL AND GAS CONSERVATION COMM._.ION - REPORT OF SUNDRY WELL OPERATIONS APR 4 6 205 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U CCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver U Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 205-090 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 2 6.API Number: Anchorage,Alaska 99503 50-029-23268-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL00255091ADL0355017 MILNE PT UNIT KR F-89 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,795' feet Plugs measured N/A feet true vertical 7,424' feet Junk measured N/A feet 10,986', 11,026'& Effective Depth measured 11,761 feet Packer measured 11,083' feet 6,651',6,687'& true vertical 7,391 feet true vertical 6,740' feet Casing Length Size MD ND Burst Collapse Conductor 113' 20" 113' 113' Surface 6,723' 10-3/4" 6,723' 4,587' 5,210psi 2,480psi Intermediate 11,186' 7-5/8" 11,186' 6,836' 6,890psi 4,790psi Liner 456' 5-1/2" 11,528' 7,166' 8,430psi 7,500psi Liner 780' 3-1/2" 11,795' 7,424' 10,160psi 10,530psi 1 Perforation depth Measured depth See Attached Schematic SCANNED APR 2 4 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/TC-II 11,022(MD) 6,684(TVD) 7-5/8"x 4.5 S-3,7- 10,986/6,651 5/8 x 5.5 ZXP&7- 11,026/6,687 Packers and SSSV(type,measured and true vertical depth) 5/8x5.5 ZXP N/A 11,083/6,740 N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1,200 140 2495 Subsequent to operation: 0 0 1,113 140 1996 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 2 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Chris Kanyer Email ckanyer(�hilcoro.com Printed Name Chris Kanyer Title Operations Engineer Signature ,1 KZ, Phone 907-777-8377 Date 4/2/2015 Form 10-404 Revised 10/2012 7('' 4-I.Zf-/ S- Submit Qr'iginal Only 47/Ai/, ----- RBDMS..kr im - 6 2015 Milne Point Unit Well: MPU F-89i . -14 SCHEMATIC Last Completed: 8/20/2005 llilcorp Alaska,LLC PTD: 205-090 CASING DETAIL Orig.KB Elev.:33.7/DF Elev.:33.68'(Doyon 14) Size Type Wt/Grade/Conn Drift ID Top Btm 4 + 20" Conductor 91.1/H-40/N/A N/A Surface 113' ! 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 6,723' 1075' 7-5/8" Intermediate 29.7/L-80/BTC Mod 6.875 Surface 11,186' Homo ES 'nl r 5-1/2" Liner 17/L-80 IBT-M 4.892 11,072' 11,528' Cementer @ ei 5. 3-1/2" Liner 9.2/L-80/IBT 2.992 11,015' 11,795' 2,785 MD ,Z .; , TUBING DETAIL 1 !, 4-1/2" Tubing 12.6/L-80/TC-ll 3.958 Surface 8,253' 1 ' JEWELRY DETAIL ,r t 103/4".. No Depth Item 1 2,992' 4-1/2"HES X-Nipple w/MCX.656 Bean Installed on 7/13/2013 2 10,966' 4-1/2"HES X-Nipple ID=3.813" 3 . 10,986' 7-5/8"x4.5"Baker S-3 Permanent Packer 4 11,010' 4-1/2"HES XN-Nipple ID=3.725"No Go 5 11,015' 7-5/8"x 5.5"Baker Tie Back Sleeve 6 _ 11,022' WLEG 7 11,026' 7-5/8"x 5.5"Baker ZXP Liner Packer 8 11,032' 7-5/8"x 5.5"Baker HMC Liner Hanger 9 11,072' 7-5/8"x 5.5"Baker Tie Back Sleeve 10 11,083' 7-5/8"x 5.5"Baker ZXP Liner Packer 11 11,090' 7-5/8"x 5.5"Baker HMC Liner Hanger PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Kup.C Sands 11,471' 11,511' 7,111' _ 7,149' _ 40 3/6/2015 Open Kup.B Sands 11,514' 11,534' 7,152' 7,171' 20 3/6/2015 Open Kup.A3/A2 Sands 11,551' 11,588' 7,188' 7,223' 37 3/6/2015 Open Kup.Al Sands 11,592' 11,603' 7,227' 7,238' 11 12/22/2005 Open Kup.Al Sands 11,603' 11,623' 7,238' 7,257' 20 1/6/2006 Open Kup.Al Sands 11,623' 11,643' 7,257' 7,277' 20 1/1/2006 Open WELL INCLINATION DETAIL KOP @ 600' Max Hole Angle=60 to 68 deg.f/5,050'to 9,800' ::a2 ., Hole Angle through perforations=13 deg. r' ...m.. s•3 OPEN HOLE/CEMENT DETAIL ',• 20" 260 sx of Arcticset(Approx.)in a 42"Hole 4 fl 10-3/4" 658 sx ASL,644 sx Class'G'in a 13-3/8"Hole e 7-5/8" 275 sx Class'G'in a 9-7/8"Hole 5,7&8 5.5" 79 sx Class'G'in a 6-3/4"Hole '=� 3.5" 123 sx Class'G'in a 4-3/4"Hole 1:83 WV 9,10&11 TREE&WELLHEAD I. Tree 4-1/16"5M FMC 7 IV 11"5M FMC ZGen 5 w/il"x 4.5"FMC Tbg.Hng. Wellhead w/4.S"TC-II&4"CIW'H'BPV Profile GENERAL WELL INFO API:50-029-23268-00-00 Drilled,Cased&Completed by Doyon 14 -8/20/2005 Perforate-3/6/2015 5-1/2"4 F Kupauk Sands 3-1/ 2"41 TD=11,795'(M))/TD=7,424'(TVD) PBTD=11,761'(MD)/PBTD=7,391'(TVD) Created By:TDF 4/2/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPF-89 50-029-23268-00-00 205-090 3/5/2015 3/6/2015 Daily Operations: 3/4/15-Wednesday No operations to report. 3/5/15-Thursday Arrive at MPF-89 and spot-in equipment.Complete rig up and PT lubricator to 250psi low/1,500psi high.Complete hot check,arm and make-up gun#1. RIH to 11,650'. Correlate using SLB Jewelry Log dated 10/8/2005. Call geologist and confirm tie-in.Shoot Interval 11,568'-11,588'. POOH. Lay down equipment. 3/6/15-Friday Return to MPF-89. Rig Up. Pressure test lubricator to 2S0psi low/1,500psi high.Complete hot check,arm and make-up gun#2. RIH and correlate using SLB Jewelry Log dated 10/8/2005. Call Engineer to confirm tie-in.Shoot interval 11,551' -11,568'. POOH. Hot check,arm and make-up gun#3. RIH and correlate using SLB Jewelry Log dated 10/8/2005. Call engineer to confirm tie-in.Shoot Interval 11,514'-11,534'. POOH. Hot check,arm and make-up gun#4. RIH and correlate using SLB Jewelry Log dated 10/8/2005. Call Engineer to confirm tie-in.Shoot Interval 11,5491'-11,511'. POOH. Hot check,arm and make-up gun#5. RIH and correlate using SLB Jewelry Log dated 10/8/2005. Contact engineer to confirm tie-in.Shoot Interval 11,471'- 11,491'. POOH. Rig down.Tree cap on.Well Shut-In. RDMO. 3/7/15-Saturday No operations to report. 3/8/15-Sunday No operations to report. 3/9/15-Monday No operations to report. 3/10/15-Tuesday No operations to report. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. g~~ ~- Q 7 ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III RES N Color Items: Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGITAL DATA ~iskettes, No. ~„ ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: - /s/ Y Protect Proofing III II II II I I III I I III BY: Maria Date: ~ ~ 8 /s/ + TOTAL PAGES ' ~ ~ ~, Scanning Preparation ~ x 30 = ~ d ~ _ Q' (Count does not include cover sheet) BY: Maria Date: ~, ~,,,~ ~ O /s/ ~, Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: __.!! YES NO BY: Maria Dater ~7 d g /s/ ~/~/~ v I r r~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III a~~,~~~, iiumimumi BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII III ~~ 10/6/2005 Well History File Cover Page.doc by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 MOWED FEB '2" 201 Mr. Tom Maunder 0 Alaska Oil and Gas Conservation Commission 05— 0 7 333 West 7 Avenue oev 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 • • 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 02 N/A 8.5 10/62011 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 8/12011 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 8/12011 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 8/12011 MPF -33 2010620 50029226890000 23 Need top job 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 8/112011 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 N/A 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 7/312011 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 7/312011 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 1.2 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 -- ""' " i MPF-89 2050900 50029232680000 1.2 N/A 12 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/32011 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 _ 8/11/2011 3Q2011 Not Operable Injector Report * • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @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: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip 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 302011.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 MEMORANDUM TO: Jim Regg P.I. Supervisor ~~1 7~ZZ ~e0 FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-89 MILNE PT UNIT KR F-89 Src: Inspector NON-CONFIDENTIAL U Reviewed By: P.I. Suprv ;~~- Comm Well Name: MILNE PT UNIT KR F-89 Insp Num: mitJCr100726104939 Rel Insp Num: API Well Number: 50-029-23268-00-00 Permit Number: 205-090-0 Inspector Name: John Crisp Inspection Date: 7/24/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ F-s9, Type Inj. ~'~' TVD 6651 ~ IA o 2200 21so nao ' P.T.D 2050900/ TypeTest sPT ~ Test psi 1662 OA 260 470 460 460 Interval aYRTST p/F P Tubing 1700 1700 1700 1700 Notes: No problems witnessed. c~ (' h(, k t~ ;q,. Tuesday, July 27, 2010 Page 1 of ] STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q SURFACE Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ CASING Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ REPAIR 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to DriII Number: Name: Development ^ Exploratory ^ .., 205-0900 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-23268-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-355017 ~(~ ~ ~ H (b ~ MPF-89 10. Field/Pool(s): MILNE POINT FIELD / KUPARUK RIVER SANDS POOL 11. Present Well Condition Summary: Total Depth measured 11795 feet Plugs (measured) 11010' 2/7/10 feet true vertical 7423.99 feet Junk (measured) None feet Effective Depth measured 11761 feet Packer (measured) 10986 true vertical 7391 feet (true vertical) 6651 Casing Length Size MD TVD Burst Collapse Structural Conductor 88 20" 91.1# H-40 35 - 113 35 - 113 Surface 6888 10-3/4" 45.5# L-80 35 - 6723 35 - 4587 5210 2480 Intermediate 11151 7-5/8" 29.7# L-80 32 - 11186 32 - 6836 6890 4790 Production Liner 456 4-1/2" 12.6# L-80 11072 - 11528 6729 - 7166 8430 7500 Liner 780 3-1/2" 9.2# L-80 11015 - 11795 6677 - 7424 10160 10530 Perforation depth: Measured depth: 11592 - 11623 11623 - 11643 True Vertical depth: 7227.32 - 7257.22 7257.22 - 7276.54 = _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 ~ w _, 30 - 11022 30 - 6683 Packers and SSSV (type, measured and true vertical depth) ri 4-1/2" Baker SAB Hvdro-set Packer - ,~ +~10986 6651 ~~~~~ V ~D 12. Stimulation or cement squeeze summary: „ ~ N ~ ~ ~p10 Intervals treated (measured): - ~.~~~ -~- ~`a~d`~ti,':.~». ~:~ . rt~ ~~8S~t8 Q4~ fit ~~$ ~f1'1tS• ~~~T1ISSIOf1 Treatment descriptions including volumes used and final pressur e: t~rlc~tc~r;~g~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~~-~~ Contact Gary Preble ~8~.u ` Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 6/28/2010 r~nn iv-•rvv r~~zviavu ~icw~ ~ ~..w~~~V tlVlt ail ~~ f1I qI ~ ~ .,....~~~~. .~~~y„~w ..~~~~ ~ h ~ C n MPF-89 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/11/2010~New Technology. umo Brinker 3 pills of the platelets to seal a small surface '. Established LLR down the OA of 1.7 to 2.0 gpm using a triplex pump and neat diesel thru Brinkers electronic flowmeter. Brinker technicians calculated hole size in the surface casing and designed platelet mixtured based on that information. Surface casing hole appears to have plugged off using the platelets as indicated by no influx of fluid into the conductor. Receated attemots to pressure the OA up to 2000 PSI we unsuccessful. The shoe of the OA appears to be open. I """JOB COMPLETE*** FLUIDS PUMPED BBLS 9 GELLED DIESEL WITH J-452 AND J-601 9 Total Tree: ~ 1 /16" - 5M FMC ~/~ ~ ~ ~ ~~~ ~ Ori~B. elev. = 45.18' (Doyon-14 Wellhead: 11" 5M FMC Gen. 5 ~1/~ Orig. GL. elev.= 11.5' w/ 11" x 4.5" FMC Tbg. Hng. w/ Orig. DF. elev. = 33.68` (Doyon-14) 4.5" TC-II & 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 106' 10.75 Howco "ES Cementer" @ 2,785' 10.75", 45.5 ppf, L-80 BTC 6723' and surface casing KOP @ 600' Max. hole angle = 60 to 68 deg. f/ 5050' to 9,800` Hole angle through perfs. = 13 deg. 7-5/8" 29.7 ppf, L-80, Btc-Mod csg. ( Drift ID = 6.875", Cap. = 0.0459 bpf ) 5.5" 17.0 ppf, L-80, IBT-M ( Drift ID = 4.892" ,Cap. = 0.0232 bpf ) 4.5", 12.6#,L-80 TC-II tubing ( Drift ID = 3.958" ,Cap. _ .0152 bpf ) 3.5", 9.2#,L-80 IBT tubing ( Drift ID = 2.992" ,Cap. _ .0087 bpf ) Weatherford 7-5/8" float collar 11,102' Weatherford 7-5/8" casing shoe 11,186' Perforation Summary Ref log: SCMT-GR-CCL 10/8/05 Size SPF Interval (ND) 2.5" 6 11592` - 11603' 7227` - 7238' 2.5" 6 11603' - 11623' 7238' - 7257' 2.5" 6 11623' - 11643' 7257' - 7277' 4.5` HES X-Nipple (3.813") 2,992' NOTE: Surface casing leak found to be at 9.5'. -_ Well secured 2/7/10 with XXN plug set @ 11010` and 55 bbls diesel FP cap. ',~~~:. ~~ ~Y . - ~: 4. ~, - 4.5' HES X -Nipple (3.813") 10,966' 7-5/8"x 4.5" Baker S-3 Perm. Pkr.- 10,986' 4.5` HES XN -Nipple (3.725 No-Go") 11,010' WLEG 11,022` 7-5/8 x 5.5" Baker Tie Back Slv. 11,015' ~ 7-5/8 x 5.5" Baker ZXP liner Pkr. 11,026' ~ 7-5/8 x 5.5" Baker HMC liner Hng. 11,032' 5.5" x 3.5" X-Over @ 11,041 7-5/8 x 5.5" Baker Tie Back Slv. 11,072' 7-5/8 x 5.5" Baker ZXP liner Pkr. 11,083' 7-5/8 x 5.5" Baker HMC liner Hng. 11,090' Baker 5.5" Landing Collar 11,484' Baker 5.5" Float Collar 11,525' Baker 5.5" Casing shoe 11,528` OPERABLE: Injector MPF-89 (PTD# 2050900) Surface casing leak repaired post Brinke... Page 1 of,~~ Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Monday, June 28, 2010 10:11 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); AK, OPS MPU Fac O&M TL; AK, OPS MPU Field Ops TL; AK, OPS MPU OSM; AK, OPS MPU OSS; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; Cismoski, Doug A; Engel, Harry R Cc: Chebul, Josh M; AK, D&C Well Integrity Coordinator; Janowski, Carrie Subject: OPERABLE: Injector MPF-89 (PTD# 2050900) Surface casing leak repaired post Brinker platelet treatment All, Injector MPF-89 (PTD #2050900) was treated with Brinker platelets to mitigate the SC leak on 06/11/10. After the treatment, an MITOA was performed that showed no indication of a leak to atmosphere. The well has been reclassified as Operable and may be placed on injection for an AOGCC witnessed MITIA after the downhole plug is pulled. Please notify well integrity when the well has thermally stabilized so the state witnessed test can be scheduled. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Welt Integrity Engineer Sent: Sunday, January 24, 2010 3:22 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2 Cc: Chebul, Josh M; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: MPF-89 (PTD# 2050900) Possible Surface Casing Leak All, Milne Point injection well MPF-89 (PTD #2050900) has been reported to have the presence of diesel in the flutes with 0 psi on the OA indicating a possible surface casing leak. The well has been reclassified as Not Operable and will be shut-in and freeze protected as soon as safely possible. Diagnostic work will continue to confirm the source of the diesel. A TIO plot and wellbore schematic have been included for reference. The well has been added to the AOGCC Monthly Injection Report. 7/1/2010 RE: NOT OPERABLE: MPF-89 (PTD# 2050900) Confirmed Surface Casing Leak -Can... Page 1 of ~~ Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 14, 2010 6:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2 Cc: Chebul, Josh M; NSU, ADW Well Integrity Engineer Subject: RE: NOT OPERABLE: MPF-89 (PTD# 2050900) Confirmed Surface Casing Leak -Cancel UIC MITIA All, Milne Point injection well MPF-89 (PTD #2050900) has been confirmed to have a surface casing leak at approximately 9.5'. The well remains classified as Not Operable. An AOGCC witnessed MITIA for UIC compliance will not be conducted until integrity has been restored. The well will continue to be tracked on the Quarterly AOGCC Injection Report. Terri -Please cancel the AOGCC MITIA. Thank you, Anna ~Du6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, January 24, 2010 3:22 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2 Cc: Chebul, Josh M; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: MPF-89 (PTD# 2050900) Possible Surface Casing Leak All, Milne Point injection well MPF-89 (PTD #2050900) has been reported to have the presence of diesel in the flutes with 0 psi on the OA indicating a possible surface casing leak. The well has been reclassified as Not Operable and will be shut-in and freeze protected as soon as safely possible. Diagnostic work will continue to confirm the source of the diesel. A TIO plot and wellbore schematic have been included for reference. The well has been added to the AOGCC Monthly Injection Report. Please tet us know if there are any questions. 7/1/2010 • • SEAN PARNELL, GOVERNOR Josh Chebul Pad Engineer '=4 ~.-'~.:~i~~;, ~~ r`4r ,~ :,; ;: ~ ~ ~~' BP Exploration (Alaska), Inc. n `~~~ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk River Sands Pool, MPF-89 Sundry Number: 310-169 Dear Mr. Chebul: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Daniel T. Seamount, Jr. c ~ Chair DATED this ! day of June, 2010. Encl. Y • ~'C~ ALAS~L AND GAS CONS VAT ON COMMISSI~ RECEIVED .~° ~~ APPLICATION FOR SUNDRY APPROVALS JUN 0 2 2010 ~n nnr ~~ inn 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^~ p 8 Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ ^ h~- i rrw~Extension GEL SQUE Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: SURFACE CASING 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-0900 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23268-00-00 . 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: Spacing Exception Required? Yes ^ No ^ MPF-89 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-355017 MILNE POINT Field / KUPARUK RIVER SANDS Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11795 7423.99 11761 7391 1101 0' 2/7/10 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 88 20" 91.1# H-40 35 113 35 113 Surface 6688 10-3/4" 45.5# L-80 35 6723 35 4587 5210 2480 Intermediate 11151 7-5/8" 29.7# L-80 32 11186 32 6836 6890 4790 Liner 456 4-1/2" 12.6# L-80 11072 11528 6729 7166 8430 7500 Liner 780 3-112" 9.2# L-80 11015 11795 6677 7424 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11592 - 11623 7227.32 - 7257.22 4-1/2" 12.6# L-80 30 11022 11623 - 11643 7257.22 - 7276.54 Packers and SSSV Tvoe: 4-1/2" Baker SAB Hvdro-set Packer Packers and SSSV MD and TVD (ftl: 10986 6651 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ Q . GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Chebul Printed N Josh ebul Title pad Engineer Sign ure P Date 564-4673 6/1/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY di l tif f N C i i th t t ti it N v'v J I ~ 1 S n approva : y ons o o omm ss on so a a represen ve may w ness undry umb a er: g Integrity ^ BOP Test ^ Mechanical Integrity Test Q Location Clearance ^ Other: Subsequent Form Required: 10 - l (~ ` APPROVED BY /C~ ~ f~ Approved by: COMMISSIONER THE COMMISSION ~ / Date: i! ` v ~~~~5 ,~N ~ o ~~~ R I G I N A L ~ ~ .g.,o ~~ ~ ,~. ,~ Form 10-403 Revised 1/2010 Submit in D pl' a '~~(~ i • Alaska Wells Group Brinker Platelet Treatment Outline for MPF-89 General Requirements All operations are conducted under requirements listed in the Alaska Safety Handbook and the "Alaska Drilling and Well Operations Practice". Personnel safety and spill prevention are ALWAYS the primary ,/` considerations in well intervention operations. Key Responsibilities The Well Operations Supervisor is responsible to: • Designate the person(s) to update this procedure as necessary in order to incorporate new information, new technology, changes in BP policy, or modifications to the procedures based on field experience. • Ensure that this procedure is communicated to and understood by those employees performing work on wells. The Well Site Leader is responsible for: • Following this procedure. • Identifying and submitting changes to this procedure based on lessons learned from performing the work. Brinker Treatment Procedure 5.0 Background MPF-89 developed a surface casing leak 1/26/2010 identified during a failed MIT-OA. The leak was strapped at 9.5' depth. The well was immediately shut in. On 2/7/10, a TTP was set at 11,010' to secure the well. The MIT-T passed. On 3/19/10, the LLR in the OA was measured at three rates: 0.6 gpm @ 600 psi; 0.8 gpm at 700 psi; and 1.6 gpm at 800 psi. That information has been used to design the remediation treatment size. MPF-89 is a WAG injector drilled in 2005. This well does not have a sealed conductor, and the root cause of this leak is under investigation. Water injection rates had been near 1,500 bwpd at 3,100 psi WHP in recent history, injecting 50 degF Prince Creek source water. Gas injection rates (usually a water injector) had been near 1.7 mmcfd at 3500 psi historically, although the well's BHP has come up in recent history, making gas injection difficult to maintain. IAP for this well is maintained near zero psi, both on water and on gas injection. OAP for this well is maintained near zero psi, both on water and on gas injection. 5.1 Job Planning 1. Confirm ability to circulate through the hole and obtain the liquid leak rate at 3 different pressure- rate combinations. The LLR's are used to estimate the hole size and design platelet size. Note that extensive cellar preparation is required to take diesel returns into the cellar -provide several weeks of time for the well integrity team to coordinate this activity. Done. 2. Provide Brinker with: a. "Platelet Deployment Candidate Data Sheet" (appendix 2) b. wellbore schematic c. wellhead schematic with the minimum clearances. Done. , 3. Develop a well specific procedure to address any additional well integrity or HSE concerns. • • 4. Write an Administrative MOC for new operating parameters on the well such as reduced OA MOASP, implementation of a LOASP and notes in JMS/DWF. The MOC shall be approved through Stage 3 by the time of the treatment. 5. Order an "operating pressure" sign to be placed on the wellhead: OA Treated with Brinker platelets Min OAP 25 psi, Max OAP 1000 psi Notify WIC at 659-5102 if fluid in cellar 5.2 Well Preparation 1. Have a "rhino-hide" cellar liner installed in the well cellar. 2. Ensure a heater is placed with a heater trunk directed towards the conductor flutes or sealed conductor for at least 3 days before job commencement. 3. Order a gelled diesel pill from Schlumberger (see "Gelled Diesel Mixing Recipe", above). Contact ConocoPhillips (Well Integrity Engineer, 659-7224) to see if they would be able to use gelled diesel in the event the job is cancelled or cannot be pumped for any other reason. ConocoPhillips uses gelled diesel for fill clean-outs and other well interventions. 4. Order the hardline rig up to the OA. 5. Install a Katch Kan and half drum in the rhino lined cellar for ease of managing fluid returns. 6. Have a triplex delivered to location. 7. Arrange for a vac truck to be on location during the treatment. 8. Confirm in the Waste Management Book (RedBook) and with the Environment Advisors how to manifest and dispose of expected fluid returns and un-used gelled diesel. 9. Confirm the job is in the CoW system and on the Operators work schedule. 10. Call the Operator and notify them of the upcoming work activities. 5.3 Day of Application 1. Verify the gelled diesel, 10 bbls neat diesel, a triplex, heater, vac truck and the hardline/injectiore manifold have been delivered to location. 2. Obtain a work permit and hold a PJSM. 3. Monitor and record all WHP's. 4. Rig up the injection manifold (figure 1 and photo 3) to triplex and the OA wellhead valve. 5. Perform a density and temperature reading of the gelled diesel and compare with the design ' parameters. 6. Using diesel, pressure test hardline, hoses and injection manifold to 2500 psi. Bleed the pressure to a bleed tank upon completion. 7. Establish circulation down the OA and into the half drum using neat diesel and repeat the liquid leak rate test to confirm leak is still present and validate the estimated hole size. Use the vac truck to remove returns from the half drum or Katch Kan. 8. Establish circulation down the OA and into the half drum using gelled diesel into the OA. Attempt to establish a circulation rate similar to the neat rate. Use the vac truck to remove returns from the half drum or Katch Kan. 9. Once circulation is re-established, stop circulating and bleed the injection manifold to 0 psi. Double block isolate the injection tee and confirm it is depressured. Remove the injection tee cap, deploy the Brinker platelets into the injection tee, positioned in the fluid flow path. Re-install the cap. 10. Open the injection manifold valves and re-establish circulation down the OA, transporting the platelets down the OA and to the leak site. 11. Once indications of a seal are noted, continue pressuring the OA to 2000 psi with diesel to fully set the platelets. 12. In the event of a partial seal, or no seal being achieved, the resultant leak size will be recalculated using current injection pressure and rate information and further platelet batches will be selected for deployment, following steps 8-11. i • 13. Bleed the OA pressure to approximately 200 psi to a bleed trailer. Vac out all remaining diesel returns in the half drum and Katch Kan. 14. Rig equipment off the well, remove the half drum and Katch Kan, ensure the cellar is left clean and request delivery of equipment and hardline to the next job. Move extra gelled diesel to the next location or arrange for transport to ConocoPhillips. 15. Install a tag on the OA valve stating the OA has been liquid packed. Verbally notify the Well Operator the OA has been liquid packed and will need careful monitoring during well restart. 16. Ensure the "operating pressure" sign is placed on the OA valve or wellhead and close out the permit. 17. Add the well to the Blue. Goo crew's work list and follow-up that the application has been completed. 18. Notify the Well Integrity team of the successful treatment and the well can be evaluated for re- classification as an "Operable" well. Appendix A: Platelet Injection manifold LO-TL7RQUE PLATELEr VALVES IMIECTI43N Pt31NT ~~"`-~-...~ WELLHEAD ~~"`"`~---~, VALVE PUMP lm PIPf SECTIaPI - - - ~- - WITH'. ULTRAStxNIC PRESSURE FLt}WMETER TRRMSDU£ER PRESSURE L(7C,GIIU~a GAUGE DUAL CHANNEL LOGGER WELLHEAD ,. - . Tree: 4 1/16" - 5M FMC Wellhead: 11" 5M FMC Gen. 5 w/ 11" x 4.5" FMC Tbg. Hng. w/ 4.5" TC-II & 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 106' MPU F-89i 10.75 Howco "ES Cementer" @ 2,785` 10.75", 45.5 ppf, L-80 BTC 6723' and surface casing 7-5/8" 29.7 ppf, L-80, Btc-Mod csg. ( Drift ID = 6.875", Cap. = 0.0459 bpf ) 5.5" 17.0 ppf, L-80, IBT-M ( Drift ID = 4.892" ,Cap. = 0.0232 bpf ) 4.5", 12.6#,L-80 TC-II tubing ( Drift ID = 3.958" ,Cap. _ .0152 bpf ) 3.5", 9.2#,L-80 IBT tubing ( Drift ID = 2.992" ,Cap. _ .0087 bpf ) Weatherford 7-5/8" float collar 11,102' Weatherford 7-5/8" casing shoe 11,186' Perforation Summary Ref log: SCMT-GR-CCL 10/8/05 Size SPF Interval (ND) 2.5" 2.5" 6 6 11592' - 11603' 11623' - 11643' 7227' - 7238' 7257' - 7277' Orig. KB~v. = 45.18' (Doyon-1 Orig. GL. elev.= 11.5' Orig. DF. elev. = 33.68` (Doyon-14) 4.5' HES X-Nipple (3.813" ) 4.5' HES X -Nipple (3.813" ) 7-5/8"x 4.5" Baker S-3 Perm. Pkr. 4.5' HES XN -Nipple (3.725 No-Go" ) WLEG 7-5/8 x 5.5" Baker Tie Back Slv. 1' 7-5/S x 5.5" Baker ZXP liner Pkr. ~ 7-5/8 x 5.5" Baker HMC liner Hng. 1 5.5" x 3.5" X-Over @ 11,041 7-5/8 x 5.5° Baker Tie Back Slv. ~ ~ 7-5/8 x 5.5" Baker ZXP liner Pkr. 1 7-5/8 x 5.5" Baker HMC liner Hng. Baker 5.5" Landing Collar Baker 5.5" Float Collar Baker 5.5" Casing shoe Baker 3.5" Landing Collar HES 3.5" Float Collar HES 3.5" Float Shoe 2,992' 10,966` 10,986' 1 I I I BP EXPLORATION (AK) ~ DATE REV. BY COMMENTS MILNE POINT UNIT 10/21/05 MDO Drilled and Cased by Doyon - 14 WELL F-89i API NO: 50-029-23268-00 04/25/08 ~cftfumber~r NO. 4673 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2538 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well .Inh 8 1 nn nocrrinfinn n~fe al r,.l... rn 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) 08/18/07 1 1 F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE '~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE ~ 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 L5-29 11963087 MEM TEMP SURVEY -'Q 04/04/08 1 1 S-26 12071843 SBHP SURVEY ~ 04/03/08 1 1 06-15 11962594 LDL 0 _ (0 04!09!08 1 1 W-30 12034892 PROD PROFILE J~fj_/~ /(,~~.(~ 04/11/08 1 1 L-221 11962592 USIT/CBL ~~ eL ~6~ _ ~ ( /(o/ 04/07/08 1 1 4-14AlS-37 11970818 CH EDIT PDC GR JEWELRY ~r_ ~ 03/24/08 1 18-326 11978442 MCNL - ~c (. 02/26/08 1 1 G-24A 11660525 MCNL dt 02/02/07 1 1 rLGHJG NVr\IVVYY L.CUUC FICV CIrI 61 ,IUIV IIVIA HIVU Fitt UFi IVI1V tl VIVt I:VYT tAGFi I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ,~~~~~~~ ApR ~ ~ 20~~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: { '" ,~~(9 • Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2838 ATTN: Beth Received by: "'"'f- ~~ STATE OF ALASKA ALASKA OtL AND GAS C~ISERVATION COMMISSI~I Mechanical lrt6egrily Tes# Emeil to:jim.regg~alaska.gov, ptaebe.txooks@ak~.gov, tom.mararder@alaslm.gov; doe.eogx-ptudhoe-be~afesl~.gov OPERATOR: BP Exploration (Alaska}, Inc. FIELD /UNIT /PAD: ACT! Milne Point! F-Pad DATE: 07!24!06 OPERATOR REP: Jett Rea AOGCC REP: John Crisp Packs Pretest Irlfiel 15 Min. 30 Min. WeA MPF-89 T I ~. W TVD 6,651' Ttbi 1,700 1,700 1,700 7,700 Interval I P.T.D. 2050900 T test P Test 1662.75 Casi 0 2,200 2,750 2,140 P/F P Notes: 3.7 hWs of diesel OA 260 470 460 460 Wep T I ". TVD TILT Interval P.T.D. T test Test Ce ~ P/F Notes: OA Well T I ". TVD T Interval P.T.D. T tes3 Test Ca ' P/F Notes: OA WeN T e I ~. TVD Tubi Interval P.T.D. T e test Test ~ Casi P/F Notes: OA WeN T I ~. TVD Ttdi Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Dril~g Waste M = Ampis MorKOring G =Gas P = Starxlard Pressure Test I = Industrial Wastewater R = IrRerrral RadioaUive Tracer Suvey N =Not Iryectmg A = TmgeraMe Nrorruy ~Y W =Water D = DiRcrerdial TenperaWe Test MIT Report Form BFL 17/27/07 ~,~'~a- INTERVAL Codes I = Indel Test 4 = Fora Year Cycle V = Recptked by Variance T =Test during Workover O = Other (describe in rwtes) MIT MPU MPF->~ 07-24-10.>ds DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2050900 Well Name/No. MILNE PT UNIT KR F-89 Operator BP EXPLORATION (ALASKA) INC MD 11795 TVD 7424 Completion Date 12/23/2005 Completion Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Log s Run: MWD, GR, GYRO, IFR/CASANDRA, RES, ABI, NEU, DEN, SCMT, C Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No D Asc Directional Survey (&~ D Asc ED C Li 13323 f Directional Survey l ti C t E s ,. emen va ua on ',wog Cement Evaluation 5 Col 1 ~', ED ,~ D Lis 13332 / Induction/Resistivity (_L~atj Cement Evaluation 5 Blu 1 C Pdf 13892 Rat f P et ti 1 5 e o ra en on - ~D C Pdf 13892 Induction/Resistivity 1-5 Cement Evaluation 5 Col 1 ~D C Lis 13892 Induction/Resistivity Temperature 5 Blu 1 Well Gores/Samples Information: Current Status 1WINJ API No. 50-029-23268-00-00 U I C..... Y J Directional Survey Yes l (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 0 11795 Open 9!26/2005 IIFR 0 11795 Open 9/26/2005 MWD 10950 11680 Case 10/19/2005 LDWG edit of SCMT 80ct 2005 10950 11680 Case 10/19/2005 Cement Bond Log SCMT- - GR-CCL 08 Oct 2005 61 1.1718 Open 10/26/2005 GR EWR4 PWD ROP GP 11023 11523 Case 11/21/2005 Ultrasonic Imaging Log i with Gamma Ray 17-Aug- 2005 106 11795 Case 5/10/2006 ROP DGR EWR 30-Ju1- 2005 106 7424 Case 5/10!2006 DGR EWR 30-Jui-2005 11040 11690 Case 6/23/2006 SCMT-CB, GR, CCL 24- Noc-2005 61 11733 Open 5I10l2006 GR, ROP, FET 11369 11685 Case 6/11/2007 Mem Temp Surv, LEE CCL, GR, Pres 8-Mar-2007 Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2050900 Well Name/No. MILNE PT UNIT KR F-89 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23268-00-00 MD 11795 TVD 7424 Completion Date 12/23/2005 Completion Status 1WINJ Current Status 1WINJ UIC Y ADDITIONAL INFORM~ION Well Cored? Y Daily History Received? fa~ N Chips Received? Y / N Formation Tops ~`"N Analysis ~F-W~ Received? Comments: Compliance Reviewed By: __ ___ ____-_ _ _ -- --- - - - - - - Date: ~_~_~_ ~( -_ Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1Me.11 InL~ ~f - ~ r, ~ 6 ~,a , ~+_ x,11 ~., :J. ~,~ F~,,~ i~ 1.017 n:.., y _,, ~'~ = qe ~,~~tY1CY!l~Ot~~:r~ ,9 ._-. -... .. 4 ,,., flpcrrin4inn N0.4290 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Harp wt color co os/o7ro7 L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29!07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-08A 11686747 LDL 05/20/07 1 G-05 11773110 LDL 05!13107 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08!07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03109/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08107 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE 05/22/07 1 04-10 11594498 LDL 05/19107 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05119107 1 C-28A N/A LDL 05109107 1 M-07 11630476 LDL 05/07/07 1 P7-14 11745214 INJECTION PROFILE 04130/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 ~ 1 PLtASt AGKNUWLtUGt KtGt1Y 1 t3Y 51laNINti AMU Kt I UKNIIVIi VIVt GVYT CAI.H 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~-'=C__-c~ '~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .,-- Received by: -___ J ~~ ~~~ Schtumberger {~~~~ ~ 3 2sss -~ 1 ~ Alaska Data 8 Consulting Services ~^ ~ 2525 Gambelt Street, Suite 400 ,;,'~`~p~~+~ ~~{~ 1,;~y$ V~i~• ~,,IT;(iIISSiCi? ay~4. Anchorage, AK 99503-2838 aPCi~G~g • ~(~ ATTN: Beth ~ 1.•~' Wall .lnh $ Inn I~acrrinfinn nafc NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ai r•..i,.. rn 06/20/06 07-18 9153238 LDL 01/31/03 C-04A 10649975 SBHP SURVEY 06/26/03 1 N-11C 10980595 PRODUCTION PROFILE 08/09/05 1 MPF-89 11084328 SCMT 11/24/05 1 D-10 10913021 MULTI-FINGER CALIPER 06/02/05 1 NGI-09 11212860 USIT 05!23/06 1 MPH-09 11211412 USIT 05/28!06 1 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12/15/05 Prints sent earlier 1 MPS-90 11162721 CH EDIT PDC-GR OF USIT 11/27/05 Prints sent earlier 1 AGI-07A 11212865 CH EDIT PDC-GR OF USIT 05!28/06 1 1 15-20C 11075906 MCNL X08/12/05 1 1 18-30 11209593 MCNL 03/25/06 1 1 Petrotechnical Data Center LR2-1 /~ 900 E. Benson Blvd. 1/`/1 Anchorage, Alaska 99508 HlasKa uara w uonswnng services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ • ~a ~ 3~9 a aas -oq a WELL LOG TRANSMITTAL To: State of Alaska April 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-89, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPF-89: LAS Data & Digital Log Images: 50-029-23268-00 s J ~s/o ~ L'..~- t 3 4sq ~ eo5=09b 1 CD Rom MEMORANDUM To: Jim Regg P.I. Supervisor ~~~1( ~ ~~~~~`' FROM: John Spaulding Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 28, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F-89 MILNE PT UNIT KR F-89 Src: Inspector NON-CONFIDENTIAL Reviewed By: i-',,, P.I. Suprv ..J ~~-- Comm Well Name: MILNE PT UNIT KR F-89 Insp Num: mitJS060227120656 Rel Insp Num API Well Number Permit Number: 50-029-23268-00-00 205-090-0 Inspector Name: John Spaulding Inspection Date: 2/15/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j F-89 ;Type Inj. ~ ~' ~ TVD ~ 66sI ~ IA , o j zooo ~ I96o I I96o p T ~ 2oso9oo 'TypeTest I SPT 'I Test psi i I662.~s ~ OA ~ o ~ o j o o ! j Interval ~T~ P/F P Tubing ~ 2a9o ~ 2sto ~ za9s ~ za9s Notes Tuesday, February 28, 2006 Page i of 1 4 ~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COM SIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG t~ECEIVED FEB 2 1 X00 ~~~~~Q!~ ~~s~~4~rt~t~on 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/23/2005 12. Permit to Drill Number 205-090 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 07/30/2005 13. API Number 50-029-23268-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/17/2005 14. Well Name and Number: M PF-89i 2162 FSL, 2889 FEL SEC. 06, T13N, R10E, UM Top of Productive Horizon: 4100' FSL, 4646' FEL, SEC. 32, T14N, R10E, UM g. KB Elevation (ft): 45.18 15. Field /Pool(s): Milne Point Unit / Kuparuk River Sands Total Depth: 4147' FSL, 4622' FEL, SEC. 32, T14N, R10E, UM 9. Plug Back Depth (MD+TVD) 11761 + 7391 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541673 y- 6035613 Zone- ASP4 10. Total Depth (MD+TVD) 11795 + 7424 Ft 16. Property Designation: ADL 355017 TPI: x- 545126 _ y- 6042850 Zone- ASP4 Total Depth: x- 545149 Y- 6042898 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: ----------------- --- -~------- -------------------- 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: MWD , GR ,GYRO , IFR/CASANDRA , RES , ABI , NEU ,DEN , SCMT , CCL 2. ASING, LINER AND CEMENTING RECORD CASING ETTINC3 EPTH MD ETTING EPni ND .:HOLE MOUNT- SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE -CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 6723' 35' 4587' 13-1/2" 58 sx ASL, 644 sx Class 'G' 7-5/8" 29.7# L-80 32' 11186' 32' 6836' 9-7/8" 75 sx Class 'G' 4-1/2" 12.6# L-80 11072 11528' 6729' 7166' 6-3/4" 9 sx Class 'G' 3-1/2" 9.2# L-80 11015' 11795' 6677' 7424' 4-3/4" 123 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. Tusln~ RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 4-1/2", 12.6#, L-80 11022' 10986' MD TVD MD TVD 11592' - 11603' 7227 - 7238' 11623' - 11643' 7257' - 7277' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 104 Bbls of Diesel 26. PRODUCTION TEST Date First Production: February 7, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ ~~- F~8 2 3 X006 Form 10-407 Revised 12/2003 ~ ~~ ~ ~ ~ ~~ I s--D ON REVERSE SIDE .. L 4. 18. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". KLGM 11230` 6878' None TKUD 11356' 6999' TKUA 11544' 7181' TKUA3 11550' 7187 TKUA2 11563' 7199' TKUA1 11590' 7225' TMLV 11656' 7289' 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr Title Technical Assistant DateQ~,Vz~''hj MPF-89i 205-090 Prepared ey Name/Number.• Sondra Stewman, 564-4750 Well Number Permit No. ! A royal No. Drilling Engineer: David Johnson, 564-4171 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. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ECE~v~a JAN 3 0 200 Alaska Oil & Gas Cons. Corrxnjssif~rt 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC25.105 zoAACZS.,,o ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/23/2005 ~ 12. Permit to Drill Number 205-090 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 07/30/2005 13. API Number 50-029-23268-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/17/2005 ' 14. Well Name and Number: MPF-89i 2162 FSL, 2889 FEL SEC. 06, T13N, R10E, UM Top of Productive Horizon: 4100' FSL, 4646' FEL, SEC. 32, T14N, R10E, UM 8. KB Elevation (tt): 45.18 15. Field /Pool(s): Milne Point Unit / Kuparuk River Sands Total Depth: 4147' FSL, 4622' FEL, SEC. 32, T14N, R10E, UM 9. Plug Back Depth (MD+TVD) 11761 + 7391 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541673 y- 6035613 Zone- ASP4 10. Total Depth (MD+ND) 11795 + 7424 Ft 16. Property Designation: ADL 355017 TPI: x- 545126 y- 6042850 Zone- ASP4 Total Depth: x- 545149 y- 6042898 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: ---- ------------- -------------------- --------~------ h f h f Thi f P t 20 k 18. Directional Survey ®Yes ^ No , i offs ore 19. Water dept N/A MSL ness o erma ros . c 1800' (Approx.) 21. Logs Run: MWD , GR ,GYRO , IFR/CASANDRA , RE5 , ABI , NEU ,DEN , SCMT , CCL 2. ASING, LINER AND EMENTING ECORD .:CASING NCi EPTH MD ETTIN(3 EPTH TVD F'IOt.E MOUNT SIZE. WT: PER FT. - ; GRADE OP TTOM OP TTOM ..SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 113' 35' 113' 42" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 6723' 35' 4587' 13-1/2" 58 sx ASL, 644 sx Class 'G' 7-5/8" 29.7# L-80 32' 11186' 32' 6836' 9-7/8" 75 sx Class 'G' 4-1/2" 12.6# L-80 11072 11528' 6729' 7166' 6-3/4" 9 sx Class 'G' 3-1/2" 9.2# L-80 11015' 11795' 6677' 7424' 4-3/4" 123 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and, " ' 24. Tusm~ RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 4-112", 12.6#, L-80 11022' 10986' MD TVD MD TVD 11592' - 11603' 7227 - 7238' 11623' - 11643' 7257 - 7277 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED Freeze Protected with 104 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PER{OD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ;~ °4 . __ . ~~~ .1~1~ ~ ,~ ~~(j~ , , None ) ' V~ Form 10-407 Revised 12/2003 ~ t ~ ~ N~l1~D ON REVERSE SIDE ~ `j L 'vn r~ 2~. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". KLGM 11230' 6878' None TKUD 11356' 6999' TKUA 11544' 7181' TKUA3 11550' 7187' TKUA2 11563' 7199' TKUA1 11590' 7225' TMLV 11656' 7289' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post Rig Summary Report and aLeak-Off Test Summary. 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. rr ~~ Signed Son tewma Title Technical Assistant Date ~ ~ ~~`l.~/ ~/ MPF-891 205-090 Prepared By Name/Number. Sondra Stewman, 564-4750 Welt Number Permit No. ! A royal NO. Drilling Engineer: David Johnson, 564-4171 INSTRUCTIONS GeNeaA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only We (head 161" 5M FM~n. 5 M P U F-89 i w/ 11 " x 4.5" FMC Tbg. Hng. w/ 4.5" TC-II & 4" CIW "H" BPV profile 20" 91.1 ppf, H-40 106' 10.75 Howco "ES Cementer" @ 2,785' 10.75", 45.5 ppf, L-80 BTC 6723' and surface casing KOP @ 600' Max. hole angle = 60 to 68 deg. fl 5050' to 9,800` Hole angle through perfs. = 13 deg. 7-5/8" 29.7 ppf, L-80, Btc-Mod csg. ( Drift ID = 6.875", Cap. = 0:0459 bpf ) 5.5" 17.0 ppf, L-80, IBT-M ( Drift ID = 4.892" ,Cap. = 0.0232 bpf ) 4.5", 12.6#,L-80 TC-II tubing ( Drift ID = 3.958" ,Cap. _ .0152 bpf ) 3.5", 9.2#,L-80 IBT tubing ( Drift ID = 2.992" ,Cap. _ .0087 bpf } Weatherford 7-5/8" float collar 11,102` Weatherford 7-5/8" casing shoe 11,186' B. elev. = 45.18' (Doyon-1 GL. elev.= 11.5' Orig. DF. elev. = 33.68` (Doyon-14) 4.5' HES X-Nipple (3.813") 2,992` 4.5' HES X -Nipple (3.813") 10,966` 7-5/8"x 4.5" Baker S-3 Perm. Pkr. 10,986' 4.5` HES XN -Nipple (3.725 No-Go") 11,010' WLEG 11,022' 7-5/8 x 5.5" Baker Tie Back Slv. 11,015' 7-5/8 x 5.5" Baker ZXP liner Pkr. 11,026' 7-5/8 x 5.5" Baker HMC liner Hng. 11,032' 5.5" x 3.5" X-Over @ 11,041 7-5/8 x 5.5" Baker Tie Back Slv. 11,072' ~ 7-5/6 x 5.5" Baker ZXP liner Pkr. 11,083' 7-5/8 x 5.5" Baker HMC liner Hng. 11,090' Perforation Summary Ref log: SCMT-GR-CCL 10/8/05 Size SPF Interval (TVD) 2.5" 2.5" 6 6 11592' - 11603' 11623` - 11643' 7227' - 7238' 7257` - 7277' Baker 5.5" Landing Collar 11,484' Baker 5.5" Float Collar 11,525' Baker 5.5" Casing shoe 11,528' Baker 3.5" Landing Collar 11,730' HES 3.5" Float Collar 11,761' HES 3.5" Float Shoe 11,795' DATE EV. BY COMMENTS MILNE POINT UNIT 10/21/05 MDO Drilled and Cased by Doyon - 14 WELL F-89i API NO: 50-029-23268-00 BP EXPLORATION BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Wel{ Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start 7!23/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: Date From - To I Hours I Task ~ Code ~I NPT ~ Phase 7/29!2005 12:00 - 13:00 1.00 MOB P PRE 13:00 - 15:00 2.00 RIGU P PRE 15:00 - 19:00 4.00 DRILL P SURF 119:00 - 00:00 5.00 DRILL P SURF 7/30/2005 ~ 00:00 - 00:30 0.50 DRILL P SURF 100:30 - 03:00 2.50 DRILL P SURF 03:00 - 06:30 3.50 DRILL P SURF 06:30 - 07:00 0.50 DRILL P SURF 07:00 - 07:30 0.50 DRILL P SURF 07:30 - 08:00 0.50 DRILL P SURF 08:00 - 08:30 0.50 DRILL P ` SURF 08:30 - 09:00 0.50 DRILL P I SURF ~ 09:00 - 00:00 15.00 DRILL P SURF 7/31/2005 00:00 - 04:00 4.00 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 11:30 7.00 DRILL P SURF 11:30 - 12:00 0.50 DRILL P SURF 12:00 - 14:00 2.00 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 00:00 9.50 DRILL P SURF 8/1/2005 ~ 00:00 - 06:30 6.501 DRILL P i SURF 06:30 - 08:30 2.00 DRILL P SURF 08:30 - 11:00 2.50 DRILL P SURF 11:00 - 12:00 1.00 DRILL P SURF 12:00 - 13:30 1.50 DRILL P SURF 13:30 - 15:30 2.00 DRILL P SURF 15:30 - 00:00 8.50 DRILL P SURF 8/2/2005 100:00 - 22:00 I 22.001 DRILL I P I I SURF 22:00 - 00:00 2.00 CASE P SURF 00:00 - 02:00 2.00 CASE P SURF 02:00 - 04:00 2.00 CASE P SURF 04:00 - 05:30 1.50 CASE P SURF 05:30 - 09:00 3.50 CASE P SURF 09:00 - 14:00 5.00 CASE P SURF 14:00 - 16:00 2.00 CASE P SURF 16:00 - 16:30 0.50 CASE P 'SURF 16:30 - 18:30 2.00 CASE P SURF 18:30 - 00:00 5.50 CASE P SURF 8/4/2005 ~ 00:00 - 03:00 ~ 3.00 ~ CASE ~ P ~ ~ SURF 03:00 - 03:30 I 0.50 i CASE I P I SURF Description of Operations PJSM, Move rig over MPF-89, spot and shim same PJSM, Skid rig floor,hook up lines air;water,steam,mud PJSM, Nipple up riser,{oad pipe shed with 5" pipe, strap same, perform derrick inspection PJSM, P/U 66 Stds 198 jts of 5" drill pipe, stand in derrick PJSM, Service top drive PJSM, Finish P/U 66 Stds 198 jts of 5" drill pipe, stand in derrick PJSM, Picking up HWDP and BHA standing in derrick PJSM, Rig up Sperry Sun Gyro unit Pre-Spud meeting with crews Drilling 112 to 254' PJSM, Poh to change BHA PJSM, RIH to 254' Drilling 254' to 1418' with 450 gpm 1800 psi, 60 rpms, run gyros every 100 ft to 710', AST 6.55, ART 2.31 Drilling 1418' to 1737 with 475 gpm 1800 psi, 60 rpms, Trying Reaming out 6 degree dog leg , no change, change shaker screens Drilling 1737' to 2391' with 500 gpm, 1800 psi, 60 rpms Circ. one bottoms up with 500 gpm 1700 psi, 80 rpms Pump out to HWDP with full drilling rate, no problems Rih, wash last stand to bottom, no problems Drilling 2391' to 3522' with 550 gpm, 2250 psi, 80 rpms, AST 6.86, ART 4.73, TO 8k, P!U 128K, S!O 103, RT 115K PJSM, Drilling 3522' to 4462' with 550 gpm, 2500 psi PJSM, Circ, two bottoms up with 550 gpm 2400 psi, 100 rpms PJSM, Pump out to HWDP with full drilling rate PJSM, Stand back BHA PJSM, Change bits, change out motor bend to i .15 degrees, surface test MWD tool PJSM, RIH, wash last stand to bottom PJSM, Drilling 4462' to 5125' with 600 gpm, 2600 psi, 100 rpms, Ast 3.13, Art 1.69, Tq 10K, P/u 165K, S/o 110k, R/t 135K Directional Drill from 5125' to 6735' - TD i3 1/2" Hole - WOB 30-RPM100-TOon11K-off 9K-GPM 612-PPon2860- off 2680 - PU 170 - SO 1 i 5 -ROT 140 CBU3X-GPM600-PP2600-RPM 100-T09K CBU -GPM 612 - PP 2500 -RPM 100 Pump out from 6735' to 4000' -Pump at drlg rate RIH from 4000' to 6735' -Precautionary wash to bottom CBU 3 X -GPM 625 - PP 2550 -RPM 100 -Spot G-seal pill Pump out from 6735' to HWT @ 707' Stand back HWT /Jars - LD 8" BHA -MWD -Stab -Flush motor -Break bit - LD motor Clear rig floor PJSM - Moblize casg tools - RU casg equipment PJSM - PU /Run 10 3/4" 45.5 # L-80 BTC casing to 3424' - Break circulation every 25 joints ran Con't run 10 3/4" casg from 3424' to 6685' -Circulate last joint in hole - PU / MU landing joint -Land casg @ 6723' -Break circulation every 25 joints ran - LD Franks fill up tool - MU Dowell Cementing head -cementing Printed: 8/22/2005 11:20:11 AM BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Well Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: Date I From - To li Hours ! Task ~ Code NPT I Phase ~ Description of Operations 8/4/2005 03:00 - 03:30 0.50 CASE P ~ SURF ~ lines 03:30 - 07:00 3.50 CASE P I SURF Break circulation -Circulate 2 casg volumes -Stage up pump from 3 BPM to 7.5 BPM - PP 400 07:00 - 08:30 1.50 1 CEMT P ~ SURF Give to Dowell Schlumberger Pump 10 bbls water Test lines 3500 psi ~ Pump 20 bbls CW-100 Pump 50 bbls Mud Push mixed at 10.1 ppg Drop btm plug last 5 bbls of Mud Push Mix /pump 188 bbls 237 sxs "Arctic set light" Yield 4.44 cf/sx i 0.7 ppg ~ Mix /Pump 92 bbls 443 sxs "G" Yield 1.17 cf/sx 15.8 ppg Drop top plug Kick out with 30 bbls water Give to rig 08:30 - 11:00 2.50 ~ CASE P SURF Displace with 340 bbls 9.1 ppg mud - 50 bbls water - 219 bbls 9.1 ppg mud -Bump plug with 1500 psi 300 over pumping pressure -Bleed off pressure -Check floats -Floats holding 11:00 - 11:30 0.50 CASE P SURF Pressure up to 2700 psi open H-ES cementer -Circulate / Condition mud for 2nd stage cement job -Recovered 10 bbls cement at surface 11:30 - 14:00 2.50 CEMT P SURF Give to Dowell Schlumberger Pump 20 bbls CW-100 Pump 50 bbls Mud Push mixed at 10.1 ppg Mix and pump 363 bbls 459 sxs "Arctic set tight" Yield 4.44 cf/sx 10.7 ppg Mix and pump 42 bbls 202 sxs "G" Yield 1.17 cf/sx 15.8 ppg I Drop closing plug Kick out with 30 bbls water thru tub Give to rig 14:00 - 15:00 1.00 CASE P SURF Displace with 9.1 ppg mud 239 bbls -Bump plug with 1380 psi with indication of sleeve closing -Bleed off pressure -check sleeve to ensure closure -Sleeve closed - 260 bbls cement i back to surfave 15:00 - 17:00 2.00 CASE P SURF Flush Divertor system - LD landing joint - ND Divertor system - LD casg equipment -Clear rig floor of all casg tools / equipment 17:00 - 18:00 1.00 CASE P SURF Install FMC M / M Well head system -Test seal to 1000 psi for 10 mins -Test good 18:00 - 23:30 5.50 CASE P SURF NU BOP's - RU to test BOP's 23:30 - 00:00 0.50 CASE P SURF Test BOP's -Annular 250 low - 2500 high - 5 mins each test - Top VBR rams -Leak between mud cross and top rams - tighten up bolts 8/5/2005 00:00 - 01:30 1.50 CASE P SURF Con't Testing Annular 250 low - 2500 High - 5 mins each test - Top VBR rams - 250 low - 4000 high - 5 mins each test 01:30 - 05:30 4.00 ~ CASE N RREP SURF Testing BOP's -Tighten up bolts on drilling spool and blind rams flange -Test top VBR rams -Flange leaking - Con't tightening up bolts on flange -Attempt to test -Flange leaking - , ~ Con't to tighten flange 05:30 - 08:30 3.00 CASE P SURF Test BOP's -VBR rams -Choke manifold - HCR Choke /Kill - Manual Choke !Kill - Upper i Lower IBOP -Floor saftey valves -Blind rams - 250 low - 4000 high - 5 mins each test -Preform Accumulator test -All test good - WSL witnessed testing Printed: 8/22/2005 11:20:11 AM BP EXPLORATION Operations Summary Report Page 3 of 9 Legal Well Name: MPF-89 Common Well Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPL ETE Start: 7123!2005 End: Contractor Name: DOYON DRILLI NG INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: Date I From - To d Hours ~ Task i I Code ~ ~ NPT Phase j Description of Operations -- - - -1 - - - _ _ _ 8/5/2005 ~ 05:30 - 08:30 3.00 CASE P SURF operations -Jeff Jones with AOGCC wavied witness of BOP ~ test 08:30 - 09:00 0.501 CASE P SURF RD test joint !equipment -Pull test test plug -Install wear ring - Close annulus valves 1 09:00 - 10:00 1.00' CASE N RREP SURF Repair top drive 10:00 - 11:30 1.50 CASE P SURF PJSM -Cut drlg line -Rig service 11:30 - 12:00 0.50 CASE P SURF Moblize BHA - RU Bales /Elevators 12:00 - 13:30 1.50 CASE P SURF MU BHA -Bit -HWT - CJO handling equipment 13:30 - 15:30 2.001 CASE P SURF RIH with 4" DP 1 X 1 15:30 - 16:30 1.001 DRILL P SURF Wash from 2730 to 2785 -Drill H-ES Cementer -Wash from i 278T to 2920' 16:30 - 18:30 2.00 CASE P SURF Contiriue PU 4" DP / RiH to 4968' -Fill every 25 stands 18:30 - 20:00 1.50 CASE P SURF C/O handling equipment from 4" to 5" - Con't RIH with 5" DP ~ from 4968' to 6557' 20:00 - 21:00 1.00 CASE P SURF RU testing equipment -Test 103/4" casg to 2000 psi -Record 1 21:00 - 22:30 1.501 DRILL P I SURF on chart 30 mins - RD testing equipment -Test good ~ Con't wash from 6557 to Landing collar @ 6634' - DriA Landing 22:30 - 00:00 I 1.501 DRILL I P I I SURF 8/6/2005 00:00 - 01:00 1.00 CASE P SURF 01:00 - 01:30 0.50 CASE P SURF 01:30 - 03:30 2.00 GASE P SURF 03:30 -04:30 1.00 CASE P SURF 04:30 - 07:30 3.00 CASE P SURF 07:30 -09:30 2.00 CASE P SURF 09:30 - 10:30 1.00 CASE P SURF 10:30 - 11:00 0.50 CASE P SURF 11:00 - 13:30 2.50 DRILL P SURF 13:30 - 14:30 i.00 CASE P SURF 14:30 - 15:00 0.50 EVAL P SURF 15:00-00:00 { 9.00{ DRILL ~P { ~INT1 8/7/2005 100:00 - 19:00 I 19.001 DRILL I P I I INT1 19:00 - 21:30 2.50 DRILL P INT1 21:30 - 23:34 2.00 DRILL P I INT1 23:30 - 00:00 0.50 DRILL { P I INTi 8/8/2005 00:00 - 01:00 1.00 DRILL P I INT1 01:00 - 03:30 2.50 DRILL P INT1 collar -Drill cement to Float collar ~ 6679' -Drill cement to 6700' CBU -GPM 435 - PP 1200 -RPM i 00 - TQ 9 -Pump dry job - Blow down Top drive POH from 6700' to 4" DP @4468' Change from 5" to 4" Handling tools Con't POH from 4468' to HWT @ 518' POH with BHA -Stand back HWT -Jars MU BHA - Up load MWD -Surface test MWD @ GPM 453 - 800 psi RIH with 4" DP to 4400' Change from 4" to 5" Handling tools -Fill pipe -GPM 450 - 1950 psi Con't RIH W / 5" DP to 6700' Drill from 6700' to 6723' -Clean out rat hole from 6723' to 6735' - Drill 20' new hole from 6735' to 6755' -RPM 50 - TO 10 to 12 -GPM 400 - PP 2980 Pump spacer -Displace to LSND 9 ppg mud RU testing equipment -Preform FIT - MD 6723 - TVD 4588 - MUD weight 9 ppg -Surface pressure 716 = EMW 12 ppg - RD testing equipment Directional Drill from 6755' to 7260' - WOB 10 to 20 -RPM 160 -TOon8-off7-GPM620-PPon3480-off 3450-PU 153- S0112-ROT133-ECD-9.69 Directional Drill from 7260' to 8991' - WOB 12 to 15 -RPM 160 - TO on 10 -off 8 -GPM 550 - PP on 3370 -off 3360 - PU 165 - SO 125 -ROT 145 -ECD 10.5 CBU3X-GPM600-PP3920-RPM 120-T08-IECD 10.5- FECD 10.2 Pump out from 899'1' to 6700' -Pump out ~ drlg rate 550 GPM PP 3310 CBU .5X-GPM 600-RPM85-PP3540 CBU 1 X -GPM 600 - 3500 psi -RPM 85 - TO 7 -Shakers clean POH from 6700 to 4" dp -Change handling tools from 5" to 4" - Stand back 18 stands 4" DP ' Printed: 8/22/2005 11:20:17 AM BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: MPF-89 Common Well Name: MPF-89 Event Name: DRILL+C Contractor Name: DOYON Rig Name: DOYON Date ~ From - To Hours ~ OMPLE DRILLIN 14 Task TE G INC. Code ~~ NPT Start Rig Rig Phase Spud Date: 7/30/2005 : 7/23!2005 End: Release: 8/21/2005 Number: Description of Operations 8(8!2005 03:30 - 06:30 3.00 DRILL P INT1 Change handling tools from 4" to 5" - PU 60 jts 5" DP 1 x 1 from pipe shed - Con't RIH to 6700' -With stands from Mast 06:30 - 08:00 1.50 DRILL P INTi Cut dr{g line -Rig service 08:00 - 09:00 1.00 DRILL P INT1 Gon't RIH from 6700' to 8991' -Precautionary wash last stand to bottom 09:00 - 00:00 15.00 DRILL P INT1 Directional Drill from 8991' to 10365' - WOB 10 to 12 -RPM 160-TO on 14-off9-GPM600-PPon3470-off 3460-PU 200 - SO 138 -ROT 168 - EGD - 10.3 8/9/2005 00:00 - 09:30 9.50 DRILL P INT1 Directional Drill from 10365' to 11195' - T.D. 9 7/8" hole - WOB 10 to t2-RPM 160-TO on 15-ofPM600-PP on 3720-off 3770 - PU 217 - S0 157 -ROT 178 -ECD 10.67 09:30 - 12:30 3.00 CASE P {NTi CBU 3 X -GPM 600 - PP 3600 -RPM 160 - TO 13 -Flow check -Well static 12:30 - 15:00 2.50 CASE P INTi Pump out from 11195 to 8900' -Pump at drlg rate 550 - PP 3150 15:00 - 15:30 0.50 CASE P INT1 RIH from 8900' to 11195' 15:30 - 18:30 3.00 CASE P INT1 CBU 3 X -GPM 590 - PP 3600 -RPM 150 - TO 13 18:30 - 23:00 4:50 CASE P INT1 Fump out from 11195' to 6700' -GPM 550 - PP 3150 23:00 - 00:00 1.00 CASE P INT1 CBU 2 X -GPM 575 - PP 2830 -RPM 85 - TQ 5 -ECD 1.0.19 8!10!2005 00:00 - 00:30 0.50 CASE P INT1 CBU -GPM 575 - PP 2800 00:30 - 02:30 2.00 CASE P INTi Flow check -Well static - POH from 6700' to 4543' - LD 15 joints 5" DP from 4543' to 2688' - 02:30 - 03:00 0.50 CASE P INTi Change handling equipment from 5" to 4" 03:00 - 03:30 0.50 CASE P INT1 POH with 4" from 2688' to 715' ~ BHA 03:30 -04:00 0.50 CASE P INTi Change handling equipment from 4" to 5" 04:00 - 07:00 3.00 CASE P INTi LD HWT - 9 7/8" BHA 07:00 - 07:30 0.50 CASE P INTi Pull wear ring -Install test plug 07:30 - 09:00 1.50 CASE P INTi Change top VBR to 7 5/8" casg rams -Test Door seals to 1500 psi -Test good 09:00 - 10:30 1.50 CASE P INT1 RU casg tools 10:30 - 16:30 6.00 CASE P INT1 PU !Run Float equipment -Check tloats -Floats good - PU / Run 7 5!8" 29# L-80 BTC-M casg to 4008' Break circulation - Con't RIH to 6723' 16:30 - 17:30 1.00 CASE P INT1 Circ casg volume 1 X - 7 bpm @ 590 psi - PU 200 - SO i45 17:30 - 21:30 4.00 CASE P INT1 Con't RIH with 7 5/8" casg to 7721' -Break circulation 3.5 bpm Q 350 - Con't RIH to 9789' - Con't RIH to 11151' -Pick up mandral hanger and landing joint -Break circulation and land fluted hanger in well head profile -Reciprocate casing string .,~-~ and circulate one casg volume -Stage up pumps from 3.5 bpm to 7 BPM (~ 520 psi -Float Collar At 11,102' -Float Shoe At 11,186' 21:30 - 23:30 2.00 CASE P INT1 Reciprocate 7 518" casing string and circulate one casg volume 510 bbls -Stage up pumps from 3.5 bpm to 7 bpm - PP 550 23:30 - 00:00 0.50 CASE P INTi Lay down Franks fill tool -Make up Dowell cementing head 1 lines 8/11/2005 00:00 - 00:30 0.50 CASE P INTi Circulate for cement job -BPM 7 - PP 520 - PU 285 - SO 170 - , PJSM (Cementing} 00:30 - 01:30 1.00 CEMT P INT1 Give to Dowell Schlumberger Pump 5 bbls water - 3.5 bpm 400 psi Test lines to 3500 psi 20 bbls CW-100 - 5.4 bpm 600 psi 30 bbls Mud Push mixed at 10.6 ppg - 5 bpm 520 psi , Drop bottom plug Printed: 8/22/2005 11:20:7 7 AM • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Welj Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/2312005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: Date ~ From - To I Hours I Task Code j NPT ' Phase ~ Description of Operations S/11/2005 ~ 00:30 - 01:30 ~ 1.00 ~ CEMT P ~ INTi Mix and pump 58 bbls 275 sxs Class "G" Yield 1.17 cf/sx mixed 01:30 - 03:00 I 1.501 CASE i P I I INT1 03:00 - 04:00 ~ 1.001 CASE I P INTi 04:00 - 05:00 I 1.001 CASE I P I I INTi 05:00 - 07:30 I 2.501 CASE ; P I i INT1 07:30 - 09:00 1.50 CASE P ~ INT1 09:00 - 09:30 0.50 CASE P INT1 09:30 - 15:00 5.50 CASE P ~ INT1 15:00 - 16:00 1.00 CASE P INTi 16:00 - 19:00 3.00 CASE P INTi 19:00 - 19:30 0.501 CASE P ! ~ INTi 19:30 -00:00 4.50' CASE P ~ INT1 00:00 - 0.001 CASE P I I INTi 8!12/2005 100:00 - 02:00 I 2.001 CASE I P I I INTi 02:00 - 04:00 2.00 CASE P INTi 04:00 - 05:30 1.50 CASE P INTi 05:30 - 06:30 1.00 CASE P INT1 06:30 - 08:00 I 1.50 {DRILL I P I I {NT1 08:00 - 10:30 2.50 CASE P INT1 10:30 - 12:00 1.50 CASE P INTi 12:00 - 12:30 0.50 CASE P INT1 12:30 - 13:30 ` 1.001 EVAL P ~ INT1 13:30 - 14:00 0.501 CASE P ~ INT1 14:00 - 00:00 10.001 DRILL P ~ , PROD1 at 15.8 ppg - 4 bpm 350 psi Drop top plug Kick out with 30 bbls water thru tub - 4.8 bpm 200 psi Give to rig Displace with 480 bbls LSND mud - 7 bpm - 430 psi -Slow fo 3 bpm last 15 bbls pumped -Bump plug with 1700 psi 1000 over circulate pressure -Hold for 3 mins -Bleed off -Floats holding - CIP 02:43 Hrs -Had full returns through out cement job and was able to reciprocate until just prior to bumping the wiper plug -- RD Cementing head !lines -Flush stack with water -Lay down landing joint Install FMC pack -off -Test to 5 K -Held for 10 mins -Test good Install test plug - RU testing equipmentr -Change casg rams to VBR's (2 7/8" X 5") -Test to 250 low 4000 high - 5 mins each test -Test good - RD testing equipment -Pull test plug -install wear ring -Close annulus valves -Clear rig floor Change out saver sub from 5" to 4" Change out bails -Rig up 5" handling equipment Lay down 5" DP from derrick Change out handling equip from 5" to 4" MU BHA -Bit -Motor - MW D -Orient MW D -Collars -Jar - HWT -Surface test MWD -GPM 275 - PP PJSM -Cut drlg -Rig service -Top drive service PU 4 " dp from rack -From 364' to 5685' -Fill and circulate every 1000' picked up Freeze protected 10 3/4" X 7 5/8" annulus with 99 bbls dry crude - 2 BPM 1425 psi -Final Pressure 800 psi Con't PU 4" dp from rack from 5685' to 7850' -Circulate every 1000' picked up Con't RIH 4" dp stands from derrick from 7850' to 11102' CBU 1 X-GPM275-PP 2600-RPM40-TQ8.5 RU test equipment -Test casg to 3500 -Record on chart for 30 mins -Test good - RD test equipment Dril{ float collar -Shoe tract -Float shoe -Clean out rat hole from 11186' to 11195' -Drill 20' new hole from 11195' to 11215' -GPM275-PP 2700-RPM40-TQ13K CBU -GPM 170 to 275 - PP 1700 to 2500 psi Displace mud with 9.7 ppg LSND Bland Core mud Pump 15 bbls hi-vis sweep 25 bbl EP Mud tube spacer 25 bbl Hi-vis spacer Followed with 9.8 ppg Bland mud GPM 275 - PP 2500 Flush kill line and wash up under shakers RU testing equipment -Preform FIT - MD 11186 - TVD 6836 - Mud weight 9.8 ppg -Surface pressure 1492 = EMW 14 ppg - RDtesting equipment Clean hole ECD 10.63 - SPR's Directional Drill from 11215' to 11425' - WOB 20 -RPM 80 - TO on 10-off9-GPM275-PP on 2740-off 2450-PU215-SO Printed: 8/22/2005 11:20:11 AM BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Well Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: i ~ i Date From-To ~I Hours Task 'Code Description of Operations NPT Phase I 8/12/2005 14:00 - 00:00 10.00 DRILL P ~ PRODi 105 -ROT 140 -ECD 10.93 8/13/2005 00:00 - 03:00 ~ 3.00 DRILL P ~ PROD1 Directional Drill from 11425' - 11475' - WOB 20 -RPM 80 - TO 03:00 - 03:30 0.50 DRILL N 'DPRB LNR1 I f 4/2005 03:30 - 07:30 ~ 4.00 DRILL N ~ DPRB LNR1 07:30 - 08:00 I 08:00 - 12:00 . i 0.50 4.00 DRILL DRILL N N DPRB DPRB LNR1 LNR1 12:00 - 13:00 1.00 DRILL I N ~ DPRB LNR1 i 13:00 - 17:00 4.00 DRILL I I N I DPRB LNR1 17:00 - 18:30 1.50 DRILL N I DPRB LNR1 18:30 - 21:30 3.00 -DRILL w P ~ LNR1 21:30 - 22:00 22:00 - 22:30 0.50 DRILL P 0.50 DRILL P LNR1 LNR1 22:30 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 01:30 01:30 - 02:00 02:00 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 10:30 10:30 - 1 i :30 11:30 - 13:00 13:00 - 14:30 14:30 - 22:00 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 8/15/2005 ~ 00:00 - 02:00 02:00 - 03:30 1.00 CASE ! P 0.50 CASE I P 0.50 CASE P 1.00 CASE P 0.50 CASE P 1.50 CASE P 0.50 CASE P 1.50 CASE P 0.50 CASE P 4.50 CASE P i.00 CASE P 1.50 CASE P 1.50 CASE P 7.50 CASE P 0.50 CASE P 0.50 CASE ~ P 1.00 CASE I P 2.00 CASE P 1.50 CEMT P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNRi LNR1 LNR1 LNRi LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 on 10 -oft 9 -GPM 275 - PP on 2740 -off 2390 - PU 215 - SO 105-ROT 140-ECD 10.9 Observed 4 bbl gain - No flow increase - PU flow check well - Well flowing -Shut in well SICP 170 -SIDPP 360 -Chuck '~"- Scheve With AOGCC was notified -Returned call recieved Circ out Kick Shut in well - 30 mins SICP 360 -SIDPP 260 Con't Circ through choke - 30 spm @ 1100 psi -Waiting on kill mud from mud plant Shut in well -Empty core mud from pits -Load 11.2 ppg kill mud into pits Circ 11.2 ppg Kill mud around - 30 SPM -Moving string every 20 mins -Shut down -Check flow - No flow -Open Annular CBU - 275 GPM - ICP 3050 - FCP 2950 -RPM 80 - TO 9 - ECD 12.45 -Mud weight 11.2 ppg in 11.2 out ppg Directional Drill from 11475' to 11525' - WOB 20 -RPM 80 - TO on 8 -off 7 -GPM 275 - PP on 3025 -off 2740 '- PU 175 - SO 125 -ROT 145 -ECD 12.51 Circulate for Geog -Conference call to town -Monitor well - Well static Directional Drill from i i 525' to 11528' - T.D. 6 314" hole - W OB 20-RPM80-TOon8-off7-GPM275-PP on 3060-off 2780 - PU 175 - SO 125 -ROT 145 -ECD 12.46 CBU 1 X-GPM275-PP 2730-RPM 80-T06.5-ECD 12.41 Monitor well -Well static Pump out to shoe from 11528' to 11186' -Pump at drlg rate Rig service -Top drive service -Monitor well 30 mins -Well static RIH from 11186' to 11528' -Wash last stand to bottom CBU 1.5 X -GPM 275 - PP 2850 -ECD 12.45 -Flow Check 15 mins -Well Static Pump out to shoe from 11528" to 11186' -Pump at drlg rate CBU 1.5X-GPM275-PP 2750-RPM 70-T07 Monitor well 30 mins -Well static -Pump dry job POH from 11075' to BHA @ 354' LD 6 3/4" BHA Clear rig floor - RU liner running tools PJSM - PU 5 1/2" 17# L-80 IBT-M Liner -Make up Baker HMC hanger -Baker ZXP Liner Top Packer -Liner weight 9 K - RIH wfLiner on 4" DP from 465' to 11100' -Fill every 15 stands run Circulate 4" DP and Liner volume -GPM 147 - PP 760 - PU 165 - SO 116 - PU up Baker plug dropping head -fay on skate Con't RIH with 5 1/2" Liner from 1 i 180' to 11528' PU Baker Plug dropping head -Break circulation -Wash to bottom - CBU i X -Stage up pump from 1.5 BPM to 3.5 BPM - PP 350 to 940 -Reciprocating string 20' strokes ~.-- CBU -GPM 147 - PP 950 - PU 175 - SO 116 -PJSM (cementing) Give to Dowell Schlumberger Pump 5 bbls water Printed: 8/22/2005 ri:20:11 AM BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Well Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: I Date ~ From - To Hours ~ Task Code ~ NPT ~ Phase ', Description of Operations -- - - - - -r - - - __ - _ - - - - -- 8/15/2005 02:00 - 03:30 1.501 CEMT P LNR1 Test lines to 4000 1 b b CW b i Pump O b s -100 - 3 pm 600 pst i Pump 15 bbls Mud Push Mixed at 12.3 ppg - 3 bpm 960 psi Pump 16 bbls 79 sxs Class "G" Yield i .17 cfJsx Mixed at i 5.8 ppg - 3 bpm 865 psi Drop Dart Kick out with 2 bbls water Displace with 125 bbls mud @ 11.2 ppg - 3.5 bpm 900 psi - Bump Dart with 3500 psi set HMC hanger -Rotate 15 rounds to right 3 rounds back release off hanger -Bled off pressure floats holding 1.5 bbls back CIP 03:20 hrs 03:30 - 04:30 1.00 CASE P ~ LNRi Pressure up to 1000 psi - Unsting -Pump 50 bbls @ 10 bpm - PP 3560 -Set down 70K rotating to set ZXP -Pick up to tie i back sleave -Circulate out cement 10 bpm @ 3500 psi - No Cement seen on bottoms up 04:30 - 05:00 0.50 CASE P LNR1 Lay down Baker Plug dropping head -Prepare to Displace with 9.9 ppg Bland core mud 05:00 - 07:00 2.00 CASE P LNR1 Displace To 9.9 ppg Bland core mud -GPM 380 - PP 3000 - Reciprocate string 07:00 - 08:00 1.00 CASE P LNR1 LD 9 stands 4" out of derrick 08:00 - 12:00 4.00 CASE P LNR1 Flow check -Well Static -Pump dry job - POH to liner running toolLD liner running tool -Clear rig floor 12:00 - 13:00 1.00 CASE P LNR1 LD liner running tool -Clear rig fl6or 13:00 - 14:00 1.00 CASE P LNR1 Pull wear bushing -Instal{ test plug -Open annulus valves - RU testing equipment 14:00 - 18:00 4.00 CASE P LNR1 Test BOP's -Annular 250 low 2500 high - 5 mins each test - Pipe rams -Choke manifold - HCR Choke /Kill valves -Manual Choke /Kill valves -Upper /Lower Top drive valves -Floor ~ safety valves -Blind rams - 250 low 4000 high - 5 mins each test -Preform Accumulator test -All test were good -All test were witnessed by W SL -Chuck Scheve with AOGCC waived witness of BOP test 18:00 - 18:30 0.50 CASE P LNR1 RD Testing equipment -Pull test plug -Install wear bushing - Close annulus valves 18:30 - 21:30 3.00 CASE P LNR1 PU 4 3/4" BHA - 24 joints 2 7/8" DP @ 905' -Change to 4" elevators 21:30 - 00:00 2.50 CASE P LNR1 RIH with 4" dp from 905' to 6663' -Fill every 20 stands 6(2005 00:00 - 02:00 2.00 CASE P LNRi Con't RIH from 6663' to 10984' 02:00 - 03:00 1.00 CASE P LNR1 Cut Drlg line -Rig service -Top Drive service -Break circ - Base line RPM 30 - TO 8 to 9K - 03:00 - 03:30 0.50 CASE P LNR1 RIH -Liner top 11072' - Con't RIH to Landing collar @ 11484' 03:30 -04:30 1.00 CASE P LNR1 Break Circulation - RU test equipment -Test casg to 1000 psi for 30 mins -Record on chart -Test good - RD test equipment 04:30 - 07:30 3.00 DRILL P LNR1 Drill Landing collar @ 11482, Float collar, float shoe, and 20 ft of new hole to 11528 to 11548 new hole was drilling @ 60 ft per hr. 07:30 - 09:00 1.50 DRILL P LNR1 Circ bottoms up with 30 rpms, 10k Tq, 40spm, 1680 psi 09:00 - 10:00 1.00 DRILL P LNR1 Float check, FIT test, TVD 7166, MD 11528, MWt 10.0, 932 psi=12.5 EMWT 10:00 - 11:00 1.00 DRILL P LNRi Drop dart for circ. sub, after opening sub CBU with 70 spm 2400 psi 11:00 - 11:30 0.50 DRILL P LNR1 POOH to 5.51iner top, pull tight from 11,200 to 11,072, 20k Printed: 8!22/2005 11:20:11 AM BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: MPF-89 Common Well Name: MPF-89 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: I Date From - To 'Hours 1 Task ~ Code ~ NPT 'Phase Description of Operations 8/16/2005 11:00 - 11:30 0.50 DRILL P LNR1 over pull 11:30 - 12:30 1.00 DRILL P LNR1 RIH to 11,449 tag up on something @ 11449, pushed and worked to 11,528 12:30 - 13:00 0.50 DRILL P LNR1 CBU thru circ. sub 70spm, 2340 13:00 - 14:00 1.00 DRILL P LNR1 POOH to liner top @ 11,072 pulled 20K over @ i 1200 to 11072 14:00 - 14:30 0.50 DRILL P 1 i LNR1 Observe well, pumped dry job. 14:30 - 18:30 4.00 DRILL P LNR1 POOH, to BHA. 18:30 - 20:30 2.00 DRILL P LNR1 Stand back BHA, found outer part of landing collar on top of Stab 20:30 - 21:30 1.00 DRILL P LNR1 Clear floor and rig up Schlumberger 21:30 - 00:00 2.50 DRILL P LNR1 RIH with Gr,Usit,Ccl logging tools, logging 5.5 liner 11528 to 11,072 8/17/2005 00:00 - 02:30 2.50 DRILL P I PROD1 logging 5.5 liner 11528 to 11,072, shows poor Bond, and liner parted @ 11,445 and dropped down 3 ft 02:30 - 03:00 0.50 DRILL P ~ PRODi Rig down Schlumberger 03:00 - 06:30 3.50 DRILL P PROD1 Picking up BHA # 7, Rih with 2 7/8 drill pipe 06:30 - 11:00 4.50 DRILL P PROD1 RIH to 11,050 11:00 - 11:30 0.50 DRILL P PROD1 Fill drill pipe, flow check well, no flow 11:30 - 12:00 0.50 DRILL P PROD1 Rih from 11050 to 11528, mad pass i 1,528 to 11548, (had to work pass parted csg @ 11449) 12:00 - 20:00 8.00 DRILL P PROD1 Drilling 11,548 to 11,795 with 160GPM, 3300 psi, RPM 30, Tq 10K 20:00 - 22:30 2.50 CASE P PROD1 Flow Check, Circ 1.5 bottoms up with 170 GPM, 3300 psi, Rpm ~ I 30, ART 6.71 Tq 10K 22:30 - 23:30 1.00 CASE P PROD1 Flow check, pump out to 5.5 liner shoe @ 11528 23:30 - 00:00 0.50 CASE P PROD1 Flow check, Service rig 8/18/2005 1 00:00 - 00:30 0.50 CASE P PROD1 Rih to 11795, washed last stand to bottom 00:30 - 02:30 2.00 CASE P PROD1 Circ 1.5 bottoms up with 170 Gpm, 3300 psi, 30 rpms 02:30 - 03:00 0.50 CASE P PROD1 Pumping out to 5.5 liner shoe, pull above 10449, to 11400ft., no drag pulling past parted csg 03:00 - 03:30 0.50 CASE P PROD1 Flow check we{I, 03:30 - 05:00 1.50 CASE P PROD1 Drop dart and open circ sub., Circ bottoms with 296 GPM, 2450 Psi, @ 11400 ft., recipocate drill pipe 05:00 - 09:00 4.00 CASE P PROD1 Slug pipe, POH 09:00 - 11:30 2.50 CASE P PROD1 Laying down 2 7/8 drill pipe and BHA 11:30 - 12:00 0.50 CASE P PROD1 Clear floor 12:00 - 13:00 1.00 CASE P PROD1 Rig up to pickup liner and PJSM 13:00 - 15:00 2.00 CASE P PROD1 Picking up 24 jts of 3.5 9.2# L-80 IBT liner 745 ft., Baker HMC liner hanger, ZXP liner top packer 15:00 - 15:30 0.50 CASE P PROD1 Change out handling tools, circ liner volume, 30 Spm, 220 psi 15:30 - 23:00 7.50 CASE P PROD1 RIH with liner,. fill every 15 stands to 11400" 23:00 - 23:30 0.50 CASE P PROD1 Circ. liner and drill pipe volume 30 spm. 900 psi, P/u 205, S/o 105 23:30 - 00:00 0.50 CASE P PROD1 RIH to 11750' (went past parted csg with no problem} 8119/2005 00:00 - 00:30 0.50 CASE P PROD1 Pick up Cement head, wash to bottom 11975' 00:30 - 03:30 3.00 CASE P PROD1 Circ 1.5 bottoms up and reciprocate liner 20 ft. with 30 spm 03:30 - 12:00 ~ 8.50 ~ CASE ~ N ~ CEMT ~ PROD1 12:00 - 13:30 I 1.501 CEMT I P I I PROD1 1020 psi, P/u 205K, S/o 110K PJSM on cementing, Blending cement Cont. to Circ and reciprocate liner, Schlumberger contaminated the blended cement with Mud push, sent in blender to get more cement, mix water Cement with Schlumberger, with 5 bbls water, test lines 4K, 5 Printed: 8/22/2005 11:20:11 AM ~ ~ BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Wefl Name: MPF-89 Common W ell Name: MPF-89 Spud Date: 7/30/2005 Event Nam e: DRILL+C OMPLE TE Start : 7/23!2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 8/21/2005 Rig Name: DOYON 14 Rig Number: Date 'I' From - To ~ Hours Task Code NPT Phase Description of Operations 8/19/2005 12:00 - 13:30 1.50 CEMT P PROD1 bbls CW100,15 bbis Mud push 11.0 ppg, 25.5 bbis Class G, yield 1.17, 15.8 ppg, wash out line,drop dart, Displace with 40 bbis 8.6 ppg high vis, 10 bbis water,73.6 bbis 10.0# mud, cement and displacemnt was pumped @ 3 bbls min, Bump plug with 3500 psi, float held 13:30 - 14:00 0.50 CASE P PROD1 Set hanger with 70K, bleed off presure P!u 5 ft to take ``compression out of pipe, turn 15 rds to right to release from hanger,pressure up to 1000 psi, unsting from hanger, psi bled off to confirm, pump cement up hole 820 ft., slack off 50K while rotating to set ZXP packer, repeat 3 times 14:00 - 15:00 1.00 CASE P PRODi Circ. out cement and reciprocate pipe, 100 spm 2980 psi, 8.8 bbls cement to surface. 15:00 - 15:30 0.50 CASE P PRODi Lay down cement head 15:30 - 16;00 0.50 CASE P ~ PROD1 Test liner top packer with 1500 psi for 10 min., good test 16:00 - 17:30 1.50 CASE P PROD1 Displace well with 20 bbis high vis pi11,70 bbls 8.8 brine,30 bbis high vis pill, 610 bbls 8.8 brine, 100 spm, 2600 psi - 17:30 - 00:00 6.50 CASE P PROD1 PJSM, Lay down 4" drill pipe 8/20/2005 00:00 - 01:00 1.00 CASE P PROD1 Laying down 4" and running tools 01:00 - 03:00 2.00 BUNCO RUNCMP Slip and cut drilling line, change out saver sub 03:00 - 04:00 1.00 BUNCO RUNCMP Pull wear ring, Test csg to 3500 psi for 30 min. record on chart, good test 04:00 - 06:00 2.00 BUNCO RUNCMP Rig up to pickup 4.5 12.6# L-80 TCII tubing, PJSM 06:00 - 00:00 18.00 BUNCO RUNCMP Picking up 4.5 12.6# L-80 TCII tubing with Baker S-3 packer, Compensator and torque turn, and stabbing guide was used 8/21/2005 00:00 - 01:00 1.00 BUNCO RUNCMP Picking up 4.5 12.6# L-80 TCII tubing with Baker S-3 packer, total 265 jts. Compensator and torque turn, and stabbing guide was used 01:00 - 02:30 1.50 RUNCOtW P RUNCMP Space out and land tubing @ 11022', XN nipple 11010, Baker packer 10,986, X nipple 10965, x nipple 2992 02:30 - 03:00 0.50 BUNCO RUNCMP RILDS, test TWC with 1000 psi for 5 min. 03:00 - 04:30 1.50 BUNCO RUNCMP Clear floor, Nipple down Bops 04:30 - 07:00 2.50 BUNCO RUNCMP Nipple up 11" FMC 11X 4 1/16 5K Tubing Adapter, test to 5000 psi for 10 min., Nipple up 4 1(16 ClW 5000 psi Tree, shell test tree with 5000 psi for 10 min. 07:00 - 08:00 1.00 BUNCO RUNCMP Pull TWC, Rig up Circ. lines 08:00 - 10:30 2.50 BUNCO RUNCMP Displace well with 168 bbis 8.8 brine, follow by 222 bbls 8.8 brine treated with corrosion inhibitor, 3 bbis min 250 psi, rig up Lubricator and test to 1000 psi 10:30 - 12:00 1.50 BUNCO RUNCMP Freeze protect tubing and annulus, with 104 bbis diesel 2 bbis min. 650 psi 12:00 - 13:00 1.00 BUNCO RUNCMP Let freeze protection U-Tube 13:00 - 14:30 1.50 BUNCO RUNCMP Drop ball and rod, pressure up to 4200 psi and set packer and I record for 30 min. test witness by WSL 14:30 - 15:30 1.00 BUNCO RUNCMP Bled tubing pressure to 2100 psi and test annulus and packer to 4000 psi for 30 min. test, test witness by WSL 15:30 - 16:30 1.00 BUNCO RUNCMP Rig down Circ lines and hot oil unit. 16:30 - 18:00 1.50 BUNCO RUNCMP Suck out cellar, Install BPV, Secure well, Release rig @ 18:00 hrs 8!2112005 Printed: 8/22/2005 11:20:11 AM • • Well: MPF-891 Accept: 07/29/2005 Field: Milne Point Unit / Kuparuk River Sands Spud: 07/30!2005 API: 50-029-23268-00-00 Release: 08/21 /2005 Permit: 205-090 Riq: Doyon 14 POST-RIG WORK 10/08/05 LOGGED SCMT FROM TD UP TO 10950'. CEMENT INTERVAL FOUND FROM APPROXIMATELY 11280' UP TO LINER TOP AT 11021'. LOGGED JEWELRY LOG UP FROM TD TO 10500'. PRIMARY DEPTH CONTROL USED TO LOG FROM TD TO SURFACE. TD FOUND AT 11707'. 11/02/05 PERFORATE 3.5" TUBING FOR CEMENT SQUEEZE FROM 11540' TO 11545' USING 2.5" HSD 2504 PJ HMX, 4 SPF. TEST FOR INJECTIVITY. SET 3.5" HES FASDRILL BRIDGE PLUG AT 11550. T/I/0=250/0/50 INJECTIVITY TEST. PUMPED 1.7 BBLS DIESEL DOWN TBG. TBG PRESSURED UP TO 2000 PSI. PUMPED 1.7 BBLS DIESEL DOWN IA TO PRESSURE UP TO 1500 PSI. PUMPED 25 BBLS DIESEL DOWN TBG AT 0.5 BPM @ 2250 PSI. FINAL WHP=1800/1400/200 11/03/05 T/I/0=400/1300/150 PUMP TBG INJECTIVITY TEST. (SHUT IN)(PRIOR TO POI AFTER PLUG SET) PUMPED 10 BBLS DIESEL INTO TBG/ ESTABLISHED INJECTION RATE OF 0.5 BPM @ 2250 PSI. FINAL WHP'S=1600/450/150 11/11/05 13450' OF 1-314" OD CT W/722K RUNNING FOOTAGE JOB SCOPE: REPAIR POOR PRIMARY CEMENT JOB ON 3-1/2" LINER WITH A LARC -RIH/MIX AND PUMP 17 BBLS 15.8 PPG LARC CMT. COULD NOT OBTAIN HIGH PRES SQUEEZE. BUMP WHP TO 2200 PSI-(600 PSI ABOVE SWHP) WHP HOLDING 1980 PSI.PLACED 11.5 BBLS CMT BEHIND PIPE. CONTAMINATE TO 11440' CHASE BIO TO SURFACE, 11/14/05 CTU 5 - MIRU - MU -RIH WITH BOT MOTOR/2.80"CEMENT MILL -TAG CEMENT 11414' MILL CEMENT WITH LIGHT MOTOR WORK TO 11554'- MILL FASDRILL FROM 11559' TO 11574' FASDRILL BROKE FREE- PUSH TO BTM @ 11712` CTM. CIRCULATE CUTTINGS OFF BTM TO SURFACE CHASING W/ 30 BBLS FLOPRO. 11/25/05 LOGGED SCMT PASSES AT 30 FPM. LOG COVERS 11040'-11725' DEPTH CORRECTED TO SPERRY LWD LOG DATED 19-AUG-05 RUN #5. TAGGED TD AT 11725'. HAD TROUBLES GETTING TOOL TO BOTTOM FROM 5600'-6000'. MADE TWO TOOL CONFIGURATIONS, SECOND CONFIGURATION MADE IT PAST TOUGH SPOT ON THIRD ATTEMPT AT 300 FPM. DID NOT SEE ANY OVERPULL WHILE POOH. GOOD ZONE ISOLATION FROM 11530'-11595'. ALSO FOUND GOOD BOND BETWEEN 3.5" AND 5.5" LINERS FROM 11135'-11300'. 12/23/05 _ PERFORATED FROM 11623' - 11643' USING 2.5" HSD 2506 PJ, HMX GUN (20'). T/ I/ O = 0/ 0/ 0 PRIOR TO SHOT. T/ I/ O = 50/ 0/ 0 AFTER PERFORATION. 1/1/06 PERFORATED FROM 11592' TO 11603' WITH 2.5" HSD 2506 PJ HMX GUNS. TD TAGGED AT 11692' ON ALL PASSES. Printed: 8/22/2005 17:20:05 AM Halliburton Sperry-Sun Milne Point Unit BPXA MPF-89 Job No. AKZZ3856242, Surveyed: 17 August, 2005 Survey Report 14 September, 2005 Your Ref: AP1500292326800 Surface Coordinates: 6035613.38 N, 541673,49E (70° 30' 29.5780" N, 149° 39' 32,5092" VV) Grid Coordinate System: NAD27Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.18ft above Mean Sea Level ~~~1--r~-~Ui"1 CiRtLLING SERVFCES A Halliburton Company DEFIP~iT? .'c Survey Ref: svy1541 • Hatliburton Sperry-Sun Survey Report for MPF-89 Your Ref: API 500292326800 Job No. AKZZ3856242, Surveyed: 17 August, 2005 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°1100tt) 0.00 0.000 0.000 -45.18 0.00 0.00 N 0.00E 6035613.38 N 541673.49E 0.00 CB-SS-GYRO - Wellnav Gyro 100.00 0.130 283.400 54.82 100.00 0.03 N 0.11 W 6035613.41 N 541673.38E 0.130 -0.02 172.00 0.100 304.800 126.82 172.00 0.08 N 0.24 W 6035613.46 N 541673.25E 0.072 -0.03 260.00 0.340 202.760 214.82 260.00 0.12 S 0.41 W 6035613.26 N 541673.09E 0.425 -0.28 351.00 0.450 122.540 305.82 351.00 0.56 S 0.21 W 6035612.82 N 541673.28E 0.567 -0.59 439.00 1.300 70.200 393.81 438.99 0.40 S 1.02E 6035612.98 N 541674.51E 1.233 0.08 532.00 1.680 68.900 486.78 531.96 0.44 N 3.29E 6035613.84 N 541676.77E 0.410 1.83 MWD+IIFR+MS 559.02 1.790 69.840 513.78 558.96 0.73 N 4.05E 6035614.13 N 541677.54E 0.420 2.42 649.80 3.210 61.000 604.48 649.66 2.45 N 7.61E 6035615.87 N 541681.08E 1.616 5.52 744.64 5.480 53.980 699.04 744.22 6.40 N 13.59E 6035619.86 N 541687.05E 2.454 11.69 837.79 6.790 50.140 791.65 836.83 12.55 N 21.42E 6035626.05 N 541694.84E 1.473 20.63 932.18 10.060 39.480 885.02 930.20 22.49 N 30.94E 6035636.04 N 541704.31E 3.825 33.73 1025.54 12.620 37.250 976.55 1021.73 36.91 N 42.30E 6035650.52 N 541715.59E 2.782 51.65 1118.14 14.040 32.630 1066.65 1111.83 54.42 N 54.49E 6035668.10 N 541727.67E 1.916 72.73 1212.95 14.910 27.120 1158.46 1203.64 74.96 N 66.25E 6035688.71 N 541739.32E 1.717 96.34 1306.22 15.880 23.560 124$.38 1293.56 97.34 N 76.82E 6035711.15 N 541749.76E 1.452 121.09 1398.40 20.090 17.300 1336.04 1381.22 124.03 N 86.57E 6035737.89 N 541759.37E 5.019 149.36 1491.39 20.760 16.020 1423.19 1468.37 155.12 N 95.87E 6035769.03 N 541768.49E 0.866 181.39 1585.47 22.250 17.550 1510.72 1555.90 188.13 N 105.84E 6035802.10 N 541778.28E 1.692 215.45 1679.38 27.800 21.700 1595.78 1640.96 225.46 N 119.31E 6035839.51 N 541791.54E 6.195 254.92 1773.02 28.560 23.710 1678.33 1723.51 266.25 N 136.39E 6035880.39 N 541808.38E 1.298 299 07 1865.27 27.030 23.460 1759.93 .1805.11 305.67 N 153.60E 6035919.90 N 541825.37E 1.663 . 342.05 1957.76 25.940 24.060 1842.71 1887.89 343.42 N 170.22E 6035957.75 N 541841.78E 1.213 383.27 2051.74 27.730 24.830 1926.57 1971.75 382.03 N 187.78E 6035996.46 N 541859.12E 1.940 425.68 2146.34 31.700 25.710 2008.71 2053.89 424.42 N 207.81E 6036038.96 N 541878.92E 4.222 472.56 2240.96 35.520 28.230 2087.50 2132.68 471.06 N 231.61E 6036085.73 N 541902.45E 4.297 524.91 2335.23 38.330 29.340 2162.86 2208.04 520.68 N 258.89E 6036135.50 N 541929.46E 3.063 581.46 2427.50 42.570 28.070 2233.06 2278.24 573.18 N 287.61E 6036188.17 N 541957.88E 4.681 641.23 2522.36 45.810 27.840 2301.07 2346.25 631.58 N 318.60E 6036246.74 N 541988.54E 3.420 707.30 2615.65 47.320 27.900 2365.21 2410.39 691.47 N 350.27E 6036306.80 N 542019.87E 1.619 775.00 2711.96 49.530 27.810 2429.11 2474.29 755.16 N 383.93E 6036370.68 N 542053.17E 2.296 847.00 2807:62 51.770 28.510 2489.76 2534.94 820.37 N 418.84E 6036436.09 N 542087.72E 2.409 920.90 2898.97 50.330 28.520 2547.19 2592.37 882.79 N 452.75E 6036498.70 N 542121.28E 1.576 991.86 2991.70 50.410 28.300 2606.33 2651.51 945.61 N 486.73E 6036561.71 N 542154.91E 0.202 1063.21 3084.98 51.600 27.800 2665.03 2710.21 1009.59 N 520.82E 6036625.88 N 542188.64E 1.342 1135.65 14 September, 2005 - 13:22 Page 2 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-89 Your Ref: API 500292326800 Job No. AKZZ3856242, Surveyed: 17 August, 2005 Milne Point Unit Measured Depth (ft) 3181.05 3275.72 3370.18 3463.01 3557.50 3652.35 3746.67 3840.65 3934.77 4028.68 4120.42 4216.17 4309.67 4405.43 4495.35 4590.97 4686.02 4781.30 4873.85 4968.85 5062.83 5156.04 5251.61 5347.12 5439.94 5534.06 5627.86 5723.85 5818.19 5911.15 6005.85 6100.26 6194.69 6289.22 6380.66 Incl. 50.500 49.950 49.980 51.370 51.460 51.390 51.030 50.840 50.510 51.200 51.280 51.440 51.400 51.180 51.380 51.700 53.170 53.990 55.380 57.060 58.530 61.090 64.320 66.890 67.960 67.580 66.920 66.560 67.080 68.020 67.980 68.030 66.500 67.720 66.960 True Azim 28.660 29.070 28.910 29.450 29.610 29.180 30.010 29.690 29.750 31.090 30.910 31.340 31.310 30.670 31.050 30.350 29.980 30.340 30.740 30.180 30.580 30.410 29.060 25.920 24.970 23.720 24.070 23.860 24.680 24.260 23.880 24.560 25.870 24.640 24.860 Sub-Sea Depth (ft) 2725.42 2785.99 2846.75 2905.58 2964.51 3023.65 3082.74 3141.97 3201.61 3260.90 3318.33 3378.12 3436.43 3496.32 3552.56 3612.04 3669.98 3726.55 3780.05 3832.87 3882.95 3929.82 3973.64 4013.10 4048.73 4084.34 4120.61 4158.52 4195.65 4231.15 4266.63 4301.99 4338.48 4375.25 4410.48 Vertical Depth (ft) 2770.60 2831.17 2891.93 2950.76 3009.69 3068.83 3127.92 3187.15 3246.79 3306.08 3363.51 3423.30 3481.61 3541.50 3597.74 3657.22 3715.16 3771.73 3825.23 3878.05 3928.13 3975.00 4018.82 4058.28 4093.91 4129.52 4165.79 4203.70 4240.83 4276.33 4311.81 4347.17 4383.66 4420.43 4455.66 Local Coordinates Northings Eastings (ft) (ft) 1075.42 N 556.16 E 1139.14 N 591.28 E 1202.40 N 626.33 E 1265.09 N 661.35 E 1329.36 N 697.75 E 1393.97 N 734.15 E 1457.89 N 770.45 E 1521.18 N 806.77 E 1584.41 N 842.87 E 1647.21 N 879.75 E 1708.53 N 916.59 E 1772.55 N 955.25 E 1834.99 N 993.25 E 1899.05 N 1031.72 E 1959.27 N 1067.71 E 2023.65 N 1105.94 E 2088.79 N 1143.79 E 2155.08 N 1182.31 E 2220.12 N 1220.69 E 2288.18 N 1260.71 E 2356.78 N 1300.93 E 2426.20 N 1341.81 E 2499.94 N 1383.91 E 2577.09 N 1424.03 E 2654.49 N 1460.85 E 2733.86 N 1496.77 E 2812.95 N 1531.81 E 2893.53 N 1567.63 E 2972.59 N 1603.27 E 3050.79 N 1638.86 E 3130.96 N 1674.67 E 3210.79 N 1710.58 E 3289.58 N 1747.68 E 3368.34 N 1784.83 E 3444.97 N 1820.15 E Global Coordinates Northings Eastings (ft) (ft) 6036691.90 N 542223.60 E 6036755.82 N 542258.37 E 6036819.28 N 542293.07 E 6036882.16 N 542327.73 E 6036946.63 N 542363.77 E 6037011.44 N 542399.80 E 6037075.57 N 542435.75 E 6037139.06 N 542471.71 E 6037202.49 N 542507.45 E 6037265.50 N 542543.98 E 6037327.03 N 542580.48 E 6037391.26 N 542618.78 E 6037453.91 N 542656.43 E 6037518.18 N 542694.54 E 6037578.61 N 542730.19 E 6037643.20 N 542768.06 E 6037708.55 N 542805.54 E 6037775.06 N 542843.69 E 6037840.31 N 542881.70 E 6037908.60 N 542921.34 E 6037977.42 N 542961.18 E 6038047.07 N 543001.67 E 6038121.04 N 543043.36 E 6038198.42 N 543083.04 E 6038276.02 N 543119.43 E 6038355.60 N 543154.90 E 6038434.88 N 543189.49 E 6038515.66 N 543224.86 E 6038594.92 N 543260.06 E 6038673.32 N 543295.21 E 6038753.68 N 543330.57 E 6038833.72 N 543366.03 E 6038912.72 N 543402.69 E 6038991.68 N 543439.39 E 6039068.51 N 543474.29 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 1.340 1210.30 0.670 1282.96 0.134 1355.17 1.564 1426.86 0.163 1500.56 0.362 1574.57 0.785 1647.93 0.333 1720.72 0.354 1793.36 1.328 1865.96 0.176 1937.21 0.389 2011.68 0.050 2084.44 0.570 2158.86 0.398 2228.74 0.664 2303.35 1.577 2378.47 0.913 2454.93 1.543 2530.19 1.835 2608.89 1.605 2688.16 2.751 2768.45 3.605 2853.17 4.025 2940.10 1.491 3025.80 1.294 3112.90 0.783 3199.35 0.426 3287.49 0.971 3374.18 1.094 3460.07 0.374 3547.83 0.670 3635.33 2.064 3722.42 1.761 3809.49 0.860 3893.86 • • 14 September, 2005 - 13:22 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-89 Your Ref: API 500292326800 Job No. AKZZ3856242, Surveyed: 17 Augusf, 2005 Milne Point Unit Measured Depth (ft) 6472.75 6566.95 6661.13 6749.16 6792.86 6889.04 6983.66 7077.57 7172.54 7267.30 7359.55 7453.26 7545.05 7641.54 7736.97 7831.15 7921.12 8017.66 8113.70 8207.86 8301.41 8395.33 8489.61 8582.13 8676.91 8769.18 8864.80 8954.51 9012.75 9106.58 9201.91 9298.04 9391.35 9484.27 9579.74 Incl 67.530 67.240 67.150 68.860 69.010 68.380 66.450 66.450 66.040 66.750 67.870 66.740 69.080 67.670 66.780 66.120 65.840 67.010 67.740 67.620 67.050 67.070 65.500 64.620 65.270 65.850 66.540 66.870 66.920 67.540 68.320 67.390 65.640 65.710 65.910 True Azim 23.700 23.690 24.480 23.910 23.960 24.200 23.330 23.620 22.810 23.170 23.180 23.750 24.620 25.010 25.250 26.110 26.140 25.600 24.820 23.840 23.240 22.020 22.840 23.240 23.080 23.740 24.410 23.900 23.210 23.370 23.300 23.460 24.100 23.340 23.400 Sub-Sea Depth (ft) 4446.10 4482.32 4518.83 4551.80 4567.50 4602.45 4638.79 4676.31 4714.57 4752.51 4788.09 4824.25 4858.77 4894.33 4931.27 4968.90 5005.52 5044.13 5081.08 5116.84 5152.89 5189.49 5227.41 5266.42 5306.56 5344.74 5383.33 5418.81 5441.67 5477.98 5513.80 5550.04 5587.22 5625.49 5664.61 Vertical Depth (ft) 4491.28 4527.50 4564.01 4596.98 4612.68 4647.63 4683.97 4721.49 4759.75 4797.69 4833.27 4869.43 4903.95 4939.51 4976.45 5014.08 5050.70 5089.31 5126.26 5162.02 5198.07 5234.67 5272.59 5311.60 5351.74 5389.92 5428.51 5463.99 5486.85 5523.16 5558.98 5595.22 5632.40 5670.67 5709.79 Local Coordinates Northings Eastings (ft) (ft) 3522.38 N 1855.07 E 3602.01 N 1890.02 E 3681.27 N 1925.45 E 3755.72 N 1958.89 E 3792.99 N 1975.44 E 3874.80 N 2012.00 E 3954.75 N 2047.21 E 4033.71 N 2081.50 E 4113.60 N 2115.76 E 4193.53 N 2149.68 E 4271.77 N 2183.17 E 4351.08 N 2217.60 E 4428.65 N 2252.44 E 4510.07 N 2290.09 E 4589.73 N 2327.45 E 4667.54 N 2364.86 E 4741.32 N 2401.05 E 4820.93 N 2439.65 E 4901.14 N 2477.41 E 4980.51 N 2513.30 E 5059.65 N 2547.77 E 5139.48 N 2581.05 E 5219.27 N 2613.98 E 5296.47 N 2646.82 E 5375.41 N 2680.58 E 5452.49 N 2713.96 E 5532.37 N 2749.65 E 5607.55 N 2783.37 E 5656.65 N 2804.77 E 5736.12 N 2838.98 E 5817.24 N 2873.97 E 5898.97 N 2909.31 E 5977.28 N 2943.81 E 6054.80 N 2977.87 E 6134.74. N 3012.41 E Global Coordinates Northings Eastings (ft) (ft) 6039146. 12 N 543508. 77 E 6039225. 94 N 543543. 27 E 6039305. 39 N 543578. 25 E 6039380 .03 N 543611. 28 E 6039417. 39 N 543627. 62 E 6039499 .41 N 543663. 72 E 6039579 .55 N 543698. 48 E 6039658 .71 N 543732. 33 E 6039738 .78 N 543766. 14 E 6039818 .90 N 543799. 61 E 6039897 .33 N 543832. 66 E 6039976 .83 N 543866. 64 E 6040054 .60 N 543901. 05 E 6040136 .23 N 543938. 24 E 6040216 .09 N 543975 .16 E 6040294 .11 N 544012 .13 E 6040368 .10 N 544047. 90 E 6040447 .93 N 544086 .06 E 6040528 .34 N 544123 .37 E 6040607 .91 N 544158 .81 E 6040687 .24 N 544192 .84 E 6040767 .26 N 544225 .67 E 6040847 .23 N 544258 .15 E 6040924 .61 N 544290 .55 E 6041003 .74 N 544323 .88 E 6041081 .01 N 544356 .82 E 6041161 .08 N 544392 .06 E 6041236 .46 N 544425 .35 E 6041285 .68 N 544446 .49 E 6041365 .34 N 544480 .25 E 6041446 .65 N 544514 .78 E 6041528 .57 N 544549 .66 E 6041607 .08 N 544583 .72 E 6041684 .79 N 544617 .35 E 6041764 .92 N 544651 .44 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 1.316 3978.75 0.308 4065.64 0.779 4152.42 2.033 4234.01 0.359 4274.76 0.695 4364.33 2.209 4451.63 0.283 4537.64 0.892 4624.47 0.826 4711.20 1.214 4796.21 1.330 4882.59 2.696 4967.60 1.509 5057.28 0.961 5145.27 1.092 5231.60 0.313 5313.78 1.316 5402.26 1.068 5490.90 0.971 5577.97 0.849 5664.23 1.196 5750.58 1.846 5836.75 1.029 5920.54 0.703 6006.30 0.905 6090.23 0.965 6177.67 0.639 6260.03 1.093 6313.56 0.679 6399.99 0.821 6488.25 0.980 6577.20 1.978 6662.73 0.749 6747.34 0.217 6834.34 • C7 14 September, 2005 - 13:22 Page 4 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for MPF-89 Your Ref.• API 500292326800 Job No. AKZZ3856242, Surveyed: 17 August, 2005 Milne Point Unit Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9672.44 64.840 23.970 5703.24 5748.42 6211.91 N 3046.26E 6041842.28 N 544684.86 E 9765.22 62.280 24.420 5744.55 5789.73 6287.68 N 3080.31E 6041918.24 N 544718.47 E 9861.33 59.150 24.120 5791.56 5836.74 6364.09 N 3114.76E 6041994.84 N 544752.50 E 9957.60 55.760 24.510 5843.34 5888.52 6438.03 N 3148.17E 6042068.97 N 544785.49 E 10049.97 52.940 25.250 5897.17 5942.35 6506.12 N 3179.73E 6042137.24 N 544816.67 E 10144.39 50.130 25.630 5955.90 6001.08 6572.88 N 3211.48E 6042204.17 N 544848.05 E 10238.46 47.980 25.800 6017.54 6062.72 6636.89 N 3242.31E 6042268.36 N 544878.52 E 10334.38 45.570 25.820 6083.23 6128.41 6699.81 N 3272.74E 6042331.44 N 544908.59 E 10428.30 43.460 26.190 6150.19 6195.37 6758.99 N 3301.60E 6042390.78 N 544937.12 E 10520.29 41.050 26.040 6218.28 6263.46 6814.53 N 3328.83E 6042446.47 N 544964.04 E 10615.15 39.090 25.030 6290.87 6336.05 6869.62 N 3355.16E 6042501.71 N 544990.06 E 10710.04 35.700 23.470 6366.24 6411.42 6922.13 N 3378.85E 6042554.36 N 545013.46 E 10804.33 31.060 21.790 6444.96 6490.14 6969.98 N 3398.85E 6042602.32 N 545033.19 E 10899.08 27.780 22.090 6527.48 6572.66 7013.15 N 3416.23E 6042645.58 N 545050.32 E 10988.57 24.790 22.110 6607.71 6652.89 7049.86 N 3431.14E 6042682.38 N 545065.03 E 11082.20 21.940 22.190 6693.65 6738.83 7084.25 N 3445.14E 6042716.85 N 545078.83 E 11163.11 19.520 22.880 6769.32 6814.50 7110.71 N 3456.10E 6042743.36 N 545089.65 E 11199.99 18.960 23.920 6804.14 6849.32 7121.86 N 3460.93E 6042754.54 N 545094.41 E 11241.81 18.760 24.930 6843.71 6888.89 7134.17 N 3466.52E 6042766.88 N 545099.93 E 11339.43 13.490 20.820 6937.46 6982.64 7159.06 N 3477.19E 6042791.84 N 545110.46 E 11385.85 12.510 17.890 6982.69 7027.87 7168.91 N 3480.66E 6042801.70 N 545113.88 E 11435.42 13.310 16.960 7031.01 7076.19 7179.48 N 3483.97E 6042812.29 N 545117.13 E 11466.66 14.950 15.980 7061.30 7106.48 7186.79 N 3486.13E 6042819.62 N 545119.25 E 11578.80 15.810 22.390 7169.43 7214.61 7214.82 N 3495.93E 6042847.70 N 545128.89 E 11674.87 14.250 21.650 7262.21 7307.39 7237.92 N 3505.28E 6042870.85 N 545138.11 E 11763.12 13.750 21.810 7347.84 7393.02 7257.75 N 3513.18E 6042890.72 N 545145.90 E 11795.00 13.750 21.810 7378.81 7423.99 7264.78 N 3516.00E 6042897.77 N 545148.68 E All data is in Fe et (US Survey) unless o therwise stated. Directions and coordinates are relative to True North. Vertical depths are relativ e to MPF-89. Northings and Eastings are relative to MPF-89. Global Northings and Eastings are relat ive to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from M PF-89 and ca lculated along an Azimuth of 25.840° (True). Based upon Mi nimum Cu rvature type calculations, at a Measured Depth of 11795.OOft., The Bottom Ho le Displacement is 8070 .89ft., in the D irection of 25.826° (True). Dogleg Vertical Rate Section Comment (°/100ft) 1.282 6918.55 2.793 7001.59 3.268 7085.37 3.538 7166.48 3.122 7241.52 2.993 7315.44 2.290 7386.49 2.513 7456.38 2.263 7522.22 2.622 7584.08 2.177 7645.13 3.709 7702.73 5.017 7754.51 3.465 7800.94 3.341 7840.48 3.044 7877.53 3.006 7906.12 1.780 7918.26 0.916 7931.77 5.520 7958.83 2.544 7969.20 1.667 7980.16 5.305 7987.68 1.698 8017.18 1.636 8042.04 0.568 8063.33 0.000 8070.89 Projected Survey BPXA 14 September, 2005 - 13:22 Page 5 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-89 Your Ref_ AP( 500292326800 Job No. AKZZ3856242, Surveyed; 17 August 2005 Milne Point Unit Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11795.00 7423.99 7264.78 N 3516.00 E Survey tool program for MPF-89 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 532.00 531.96 To Measured Vertical Depth Depth (ft) (ft) 532.00 531.96 11795.00 7423.99 Comment Projected Survey Survey Tool Description CB-SS-GYRO - Wellnav Gyro MWD+IIFR+MS BPXA • 14 September, 2005 - 13:22 Page 6 of 6 DriiiQuest 3.03.06.008 Halliburton Sperry-Sun Milne Point Unit BPXA MPF-89 (mwd) Job No. AKMW3856242, Surveyed: 17 August, 2005 Survey Report 74 September, 2005 Your Ref: API 500292326800 Surface Coordinates: 6035613.38 N, 541673.49E (70° 30' 29.5780" N, 149° 39' 32.5092" VI/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 45.18ft above Mean Sea Level p~r~iry-emu • 5 E R V I G E S Survey Ref: svy1542 A Halliburton Company Halliburton Sperry-Sun Survey Report for MPF-89 (mwd) Your Ref: API 500292326800 Job No. AKMW3856242, Surveyed; 17 August, 2005 BPXA Milne Point Unif Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) {ft} (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -45.18 0.00 0.00 N 0.00E 6035613.38 N 541673.49E 0.00 CB-SS-GYRO - Wellnav Gyro 100.00 0.130 283.400 54.82 100.00 0.03 N 0.11 W 6035613.41 N 541673.38E 0.130 -0.02 172.00 0.100 304.800 126.82 172.00 0.08 N 0.24 W 6035613.46 N 541673.25E 0.072 -0.03 260.00 0.340 202.760 214.82 260.00 0.12 S 0.41 W 6035613.26 N 541673.09E 0.425 -0.28 351.00 0.450 122.540 305.82 351.00 0.56 S 0.21 W 6035612.82 N 541673.28E 0.567 -0.59 439.00 1.300 70.200 393.81 438.99 0.40 S 1.02E 6035612.98 N 541674.51E 1.233 0.08 532.00 1.680 68.900 486.78 531.96 0.44 N 3.29E 6035613.84 N 541676.77E 0.410 1.83 MWD Magnetic 559.02 1.990 69.800 513.78 558.96 0.75 N 4.10E 6035614.15 N 541677.58E 1.152 2.46 649.80 3.450 61.370 604.46 649.64 2.60 N 7.97E 6035616.03 N 541681.45E 1.663 5.82 744.64 5.740 54.130 698.99 744.17 6.75 N 14.32E 6035620.21 N 541687.77E 2.486 12.32 837.79 7.070 50.480 791.55 836.73 13.13 N 22.52E 6035626.63 N 541695.94E 1.493 21.63 932.18 10.360 39.660 884.85 930.03 23.36 N 32.42E 6035636.92 N 541705.78E 3.880 35.15 1025.54 12.930 37.580 976.28 1021.46 38.10 N 44.15E 6035651.73 N 541717.43E 2.789 53.54 1118.14 14.360 32.590 1066.27 1111.45 55.99 N 56.65E 6035669.69 N 541729.83E 1.999 75.08 1212.95 15.230 27.200 1157.94 1203.12 76.97 N 68.68E 6035690.74 N 541741.74E 1.716 99.21 1306.22 16.210 23.820 1247.72 1292.90 99.78 N 79.54E 6035713.60 N 541752.47E 1.438 124.47 1398.40 20.420 17.500 1335.22 1380.40 126.90 N 89.58E 6035740.78 N 541762.35E 5.044 153.26 1491.39 21.100 16.300 1422.17 1467.35 158.44 N 99.15E 6035772.37 N 541771.75E 0.863 185.81 1585.47 22.600 17.830 1509.49 1554.67 191.90 N 109.44E 6035805.89 N 541781.85E 1.705 220.42 1679.38 28.140 21.840 1594.32 1639.50 229.67 N 123.22E 6035843.74 N 541795.42E 6.173 260.41 1773.02 28.910 23.810 1676.59 1721.77 270.87 N 140.57E 6035885.04 N 541812.54E 1.298 305.06 1865.27 27.390 23.640 1757.93 1803.11 310.72 N 158.08E 6035924.98 N 541829.82E 1.650 348.55 • 1957.76 26.290 23.750 1840.45 1885.63 348.96 N 174.86E 6035963.31 N 541846.39E 1.191 390.28 2051.74 28.080 24.610 1924.05 1969.23 388.12 N 192.46E 6036002.57 N 541863.77E 1.950 433.20 2146.34 32.060 25.430 2005.90 2051.08 431.05 N 212.52E 6036045.62 N 541883.59E 4.229 480.58 2240.96 35.870 28.060 2084.36 2129.54 478.21 N 236.35E 6036092.91 N 541907.15E 4.315 533.42 2335.23 38.700 29.120 2159.36 2204.54 528.34 N 263.69E 6036143.19 N 541934.21E 3.078 590.45 2427.50 42.930 27.770 2229.18 2274.36 581.37 N 292.38E 6036196.38 N 541962.61E 4.683 650.68 2522.36 46.190 27.900 2296.76 2341.94 640.22 N 323.46E 6036255.40 N 541993.35E 3.438 717.19 2615.65 47.700 27.970 2360.45 2405.63 700.44 N 355.39E 6036315.80 N 542024.95E 1.620 785.31 2711.96 49.910 28.060 2423.88 2469.06 764.42 N 389.43E 6036379.97 N 542058.62E 2.296 857.72 2807.62 52.130 28.590 2484.05 2529.23 829.87 N 424.71E 6036445.62 N 542093.54E 2.360 932.01 2898.97 50.720 28.770 2541.01 2586.19 892.52 N 458.99E 6036508.46 N 542127.46E 1.551 1003.34 2991.70 50.780 28.580 2599.68 2644.86 955.52 N 493.44E 6036571.66 N 542161.57E 0.171 1075.06 3084.98 51.970 27.920 2657.90 2703.08 1019.72 N 527.93E 6036636.04 N 542195.69E 1.390 1147.87 14 September, 2005 - 13:20 Page 2 of 6 QrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for MPF-89 (mwd) Your Ref: API 500292326800 Job No. AKMW3856242, Surveyed: 17 August, 2005 Milne Point Unii Measured Depth (ft) 3181.05 3275.72 3370.18 3463.01 3557.50 3652.35 3746.67 3840.65 3934.77 4028.68 4120.42 4216.17 4309.67 4405.43 4495.35 4590.97 4686.02 4781.30 4873.85 4968.85 5062.83 5156.04 5251.61 5347.12 5439.94 5534.06 5627.86 5723.85 5818.19 5911.15 6005.85 6100.26 6194.69 6289.22 6380.66 Incl. 50.870 50.320 50.350 51.740 51.830 51.780 51.410 51.220 50.880 51.580 51.660 51.810 51.770 51.570 51.380 52.060 53.520 54.360 55.740 57.410 58.900 61.460 64.710 67.260 68.340 67.960 67.290 66.920 67.460 68.410 68.340 68.410 66.880 68.090 67.350 True Azim 28.850 29.280 29.380 30.100 30.130 30.760 30.380 30.260 30.800 31.020 31.120 31.480 31.060 30.270 31.350 30.490 30.100 30.330 30.950 30.170 30.720 30.740 29.640 26.180 24.990 23.810 23.920 23.700 24.620 24.050 23.850 24.510 25.840 24.760 25.190 Sub-Sea Depth (ft) 2717.81 2777.91 2838.20 2896.56 2955.02 3013.67 3072.26 3131,00 3190.17 3248.98 3305.93 3365.23 3423.07 3482.46 3538.46 3597.70 3655.18 3711.27 3764.28 3816.61 3866.20 3912.54 3955.80 3994.68 4029.75 4064.78 4100.49 4137.83 4174.40 4209.33 4244.23 4279.02 4314.93 4351.13 4385.80 Vertical Depth (ft) 2762.99 2823.09 2883.38 294'x.74 3000.20 3058.85 3117.44 3176.18 3235.35 3294.16 3351.11 3410.41 3468.25 3527.64 3583.64 3642.88 3700.36 3756.45 3809.46 3861.79 3911.38 3957.72 4000.98 4039.86 4074.93 4109.96 4145.67 4183.01 4219.58 4254.51 4289.41 4324.20 4360.11 4396.31 4430.98 Local Coordinates Northings Eastings (ft) (ft) 1085.79 N 563.63 E 1149.73 N 599.17 E 1213.12 N 634.78 E 1275.80 N 670.60 E 1340.02 N 707.85 E 1404.28 N 745.62 E 1467.92 N 783.21 E 1531.25 N 820.24 E 1594.30 N 857.43 E 1657.11 N 895.04 E 1718.71 N 932.15 E 1782.95 N 971.21 E 1845.74 N 1009.34 E 1910.36 N 1047.66 E 1970.78 N 1083.69 E 2035.17 N 1122.25 E 2100.53 N 1160.44 E 2167.09 N 1199.20 E 2232.36 N 1237.86 E 2300:63 N 1278.17 E 2369.45 N 1318.62 E 2438.96 N 1359.94 E 2512.61 N 1402.78 E 2589.70 N 1443.58 E 2667.21 N 1480.69 E 2746.76 N 1516.78 E 2826.08 N 1551.87 E 2906.98 N 1587.57 E 2986.33 N 1623.16 E 3064.82 N 1658.66 E 3145.28 N 1694.40 E 3225.34 N 1730.35 E 3304.38 N 1767.49 E 3383.33 N 1804.80 E 3460.03 N 1840.53 E Global Coordinates Northings Eastings (ft) (ft) 6036702. 32 N 542231.02 E 6036766. 45 N 542266.20 E 6036830. 04 N 542301.46 E 6036892. 92 N 542336.92 E 6036957. 35 N 542373.81 E 6037021. 82 N 542411.22 E 6037085. 67 N 542448.45 E 6037149. 20 N 542485.13 E 6037212. 46 N 542521.96 E 6037275. 49 N 542559.22 E 6037337. 30 N 542595.99 E 6037401. 75 N 542634.68 E 6037464. 76 N 542672.46 E 6037529. 59 N 542710.41 E 6037590. 20 N 542746.10 E 6037654. 81 N 542784.31 E 6037720. 39 N 542822.12 E 6037787. 16 N 542860.51 E 6037852. 64 N 542898.81 E 6037921 .14 N 542938.73 E 6037990 .19 N 542978.80 E 6038059 .93 N 543019.73 E 6038133 .82 N 543062.15 E 6038211 .13 N 543102.52 E 6038288 .85 N 543139.19 E 6038368 .61 N 543174.83 E 6038448 .12 N 543209.48 E 6038529 .23 N 543244.73 E 6038608 .77 N 543279.87 E 6038687 .46 N 543314.93 E 6038768 .11 N 543350.22 E 6038848 .38 N 543385.71 E 6038927 .62 N 543422.41 E 6039006 .78 N 543459.28 E 6039083 .68 N 543494.58 E Dogleg Rate (°/100ft) 1.372 0.679 0.087 1.614 0.098 0.525 0.504 0.225 0.574 0.767 0.122 0.334 0.356 0.680 0.963 1.002 1.570 0.903 1.589 1.887 1.662 2.747 3.552 4.251 1.662 1.232 0.722 0.439 1.066 1.169 0.210 0.654 2.079 1.659 0.919 Vertical Section 1222.89 1295.93 1368.50 1440.52 1514.56 1588.86 1662.52 1735.66 1808.61 1881.54 1953.15 2027.99 2101.13 2175.98 2246.06 2320.83 2396.30 2473.10 2548.69 2627.70 2707.27 2787.84 2872.80 2959.96 3045.90 3133.23 3219.91 3308.29 3395.21 3481.33 3569.32 3657.04 3744.37 3831.68 3916.29 Comment BPXA • 14 September, 2005 - 13:20 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPF-89 (mwd) Your Ref: API 500292326800 Job No. AKMW3856242, Surveyed: 17 August, 2005 Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 6472.75 67.900 23.940 4420.86 4466.04 3537.47 N 1875.93E 6039161.32 N 543529.54E 1.390 4001.42 6566.95 67.590 23.970 4456.53 4501.71 3617.15 N 1911.32E 6039241.19 N 543564.49E 0.330 4088.55 6661.13 67.510 24.660 4492.50 4537.68 3696.47 N 1947.16E 6039320.71 N 543599.89E 0.682 4175.57 6749.16 68.840 24.320 4525.23 4570.41 3770.83 N 1981.04E 6039395.27 N 543633.34E 1.553 4257.26 6792.86 69.000 24.600 4540.94 4586.12 3807.95 N 1997.92E 6039432.48 N 543650.02E 0.701 4298.02 6889.04 68.370 24.600 4575.90 4621.08 3889.42 N 2035.22E 6039514.16 N 543686.86E 0.655 4387.60 6983.66 66.440 23.710 4612.26 4657.44 3969.12 N 2070.97E 6039594.06 N 543722.16E 2.217 4474.92 7077.57 66.440 24.290 4649.79 4694.97 4047.76 N 2105.98E 6039672.89 N 543756.73E 0.566 4560.96 7172.54 66.030 23.850 4688.07 4733.25 4127.12 N 2141.43E 6039752.45 N 543791.73E 0.605 4647.83 7267.30 66.730 24.010 4726.03 4771.21 4206.48 N 2176.65E 6039832.00 N 543826.51E 0.755 4734.60 7359.55 67.850 24.670 4761.65 4806.83 4284.01 N 2211.72E 6039909.73 N 543861.14E 1.382 4819.67 7453.26 66.730 24.340 4797.83 4843.01 4362.66 N 2247.58E 6039988.58 N 543896.56E 1.239 4906.09 7545.05 69.050 25.200 4832.37 4877.55 4439.87 N 2283.21E 6040065.99 N 543931.76E 2.672 4991.11 7641.54 67.660 25.500 4867.96 4913.14 4520.92 N 2321.61E 6040147,25 N 543969.70E 1.469 5080.79 7736.97 66.770 25.460 4904.92 4950.10 4600.35 N 2359.46E 6040226.89 N 544007.10E 0.933 5168.77 7831.15 66.110 26.450 4942.56 4987.74 4677.97 N 2397.24E 6040304.72 N 544044.45E 1.191 5255.10 7921.12 65.830 26.380 4979.20 5024.38 4751.56 N 2433.79E 6040378.52 N 544080.59E 0.319 5337.27 8017.66 66.990 25.750 5017.84 5063.02 4831.03 N 2472.66E 6040458.21 N 544119.01E 1.342 5425.73 8113.70 67.720 24.490 5054.81 5099.99 4911.28 N 2510.29E 6040538.67 N 544156.19E 1.430 5514.36 8207.86 67.600 24.200 5090.60 5135.78 4990.63 N 2546.19E 6040618.22 N 544191.64E 0.312 5601.42 8301.41 67.040 23.500 5126.68 5171.86 5069.58 N 2581.09E 6040697.36 N 544226.10E 0.914 5687.69 8395.33 67.050 22.290 5163.31 5208.49 5149.24 N 2614.74E 6040777.21 N 544259.30E 1.186 5774.05 8489.61 65.500 23.430 5201.24 5246.42 5228.77 N 2648.26E 6040856.93 N 544292.38E 1.982 5860.24 8582.13 64.610 23.830 5240.26 5285.44 5305.63 N 2681.88E 6040933.97 N 544325.57E 1.039 5944.07 8676.91 65.250 23.590 5280.42 5325.60 5384.23 N 2716.40E 6041012.77 N 544359.65E 0.713 6029.86 8769.18 65.830 24.140 5318.63 5363.81 5461.04 N 2750.39E 6041089.76 N 544393.20E 0.830 6113.80 8864.80 66.520 24.710 5357.25 5402.43 5540.68 N 2786.56E 6041169.61 N 544428.92E 0.904 6201.24 8954.51 66.850 24.260 5392.76 5437.94 5615.66 N 2820.70E 6041244.77 N 544462.64E 0.590 6283.60 9012.75 66.900 23.430 5415.63 5460.81 5664.65 N 2842.35E 6041293.88 N 544484.02E 1.313 6337.13 9106.58 67.520 23.550 5451.98 5497.16 5743.98 N 2876.83E 6041373.41 N 544518.05E 0.671 6423.56 9201.91 68.300 23.610 5487.83 5533.01 5824.94 N 2912.17E 6041454.56 N 544552.93E 0.820 6511.83 9298.04 67.380 23.700 5524.08 5569.26 5906.49 N 2947.89E 6041536.31 N 544588.20E 0.961 6600.79 9391.35 65.640 24.210 5561.28 5606.46 5984.69 N 2982.63E 6041614.71 N 544622.50E 1.931 6686.32 9484.27 65.700 23.940 5599.56 5644.74 6061.99 N 3017.17E 6041692.20 N 544656.60E 0.273 6770.94 9579.74 65.900 23.750 5638.69 5683.87 6141.64 N 3052.37E 6041772.05 N 544691.36E 0.277 6857.97 BPXA • • 14 September, 2005 - 13:20 Page 4 of 6 DritlQuest 3.03.06,008 Milne Point Unit Measured True Sub-Sea Vertical Depth Incl. Azim, Depth Depth (ft) (ft) (ft) 9672.44 64.830 24.450 5677.33 5722.51 9765.22 62.280 24.920 5718.65 5763.83 9861.33 59.160 24.680 5765.65 5810.83 9957.60 55.770 24.930 5817.42 5862.60 .10049.97 52.940 25.800 5871.24 5916.42 10144.39 50.130 26.030 5929.97 5975.15 10238.46 47.980 26.220 5991.61 6036.79 10334.38 45.570 26.430 6057.30 6102.48 10428.30 43.460 26.830 6124.27 6169.45 10520.29 41.060 26.280 6192.34 6237.52 10615.15 39.090 25.760 6264.93 6310.11 10710.04 35.710 24.150 6340.30 6385.48 10804.33 31.070 22.170 6419.01 6464.19 10899.08 27.790 22.590 6501.52 6546.70 10988.57 24.800 22.530 6581.74 6626.92 11082.20 21.950 22.420 6667.68 6712.86 11163.11 19.530 22.370 6743.34 6788.52 11199.99 18.980 24.300 6778.16 6823.34 11241.81 18.780 24.950 6817.73 6862.91 11339.43 13.570 21.290 6911.45 6956.63 11385.85 12.560 18.420 6956.67 7001.85 11435.42 13.310 17.000 7004.98 7050.16 11466.66 14.950 16.590 7035.28 7080.46 11578.80 15.810 22.870 7143.41 7188.59 11674.87 14.250 22.020 7236.19 7281.37 Halliburton Sperry-Sun Survey Reporf for MPF-89 (mwd) Your Ref: AP/ 500292326800 Job No. AKMW3856242, Surveyed: 17 August, 2005 Local Coordinates Northings Eastings (ft) (ft) 6218.56 N 3086.78 E 6294.03 N 3121.46 E 6370.12 N 3156.62 E 6443.78 N 3190.67 E 6511.61 N 3222.81 E 6578.10 N 3255.11 E 6641.89 N 3286.40 E 6704.53 N 3317.39 E 6763.39 N 3346.90 E 6818.72 N 3374.56 E 6873.60 N 3401.35 E 6925.83 N 3425.69 E 6973.49 N 3446.14 E 7016.54 N 3463.86 E 7053.15 N 3479.07 E 7087.47 N 3493.27 E 7113.96 N 3504.18 E 7125.12 N 3509.00 E 7137.43 N 3514.64 E 7162.36 N 3525.43 E 7172.22 N 3529.00 E 7182.80 N 3532.37 E 7190.10 N 3534.58 E 7218.04 N 3544.64 E 7241.06 N 3554.16 E Global Coordinates Northings Eastings (ft) (ft) 6041849.15 N 544725 .33 E 6041924.82 N 544759 .59 E 6042001.11 N 544794 .33 E 6042074.96 N 544827 .96 E 6042142.97 N 544859 .72 E 6042209.64 N 544891 .65 E 6042273.60 N 544922 .57 E 6042336.42 N 544953 .21 E 6042395.44 N 544982 .39 E 6042450.93 N 545009 .74 E 6042505.95 N 6042558.31 N 6042606.10 N 6042649.24 N 6042685.93 N 6042720.33 N 6042746.88 N 6042758.08 N 6042770.41 N 6042795.41 N 6042805.29 N 6042815.88 N 6042823.19 N 6042851.19 N 6042874.26 N 11763.12 13.750 22.150 7321.82 7367.00 7260.84 N 3562.19E 6042894.09 N 11795.00 13.750 22.150 7352.78 7397.96 7267.86 N 3565.05E 6042901.12 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-89. Northings and Eastings are relative to MPF-89. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from MPF-89 and calculated along an Azimuth of 25.840° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11795.OOft., The Bottom Hole Displacement is 8095.14ft., in the Direction of 26.129° (True). 545036.23 E 545060.27 E 545080.46 E 545097.93 E 545112.93 E 545126.94 E 545137.71 E 545142.46 E 545148.03 E 545158.68 E 545162.20 E 545165.51 E 545167.67 E 545177.58 E 545186.98 E 545194.89 E 545197.71 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 1.343 6942.19 2.786 7025.24 3.254 7109.05 3.528 7190.18 3.158 7265.24 2.982 7339.16 2.291 7410.21 2.518 7480.09 2.266 7545.93 2.640 7607.78 2.107 7668.85 3.708 7726.46 5.054 7778.28 3.469 7824.75 3.341 7864.32 3.044 7901.40 2.991 7930.00 2.281 7942.15 0.694 7955.68 5.436 7982.82 2.585 7993.26 1.643 8004.24 5.259 8011.77 1.670 8041.31 1.640 8066.17 0.568 8087.48 0.000 8095.04 Projected Survey • • 14 September, 2005 - 13:20 Page 5 of 6 DrillQuest 3.03.06.008 r Milne Point Unit Comments Halliburton Sperry-Sun Survey Report for MPF-89 (mwd) Your Ref: AP/ 500292326800 Job No. AKMW3856242, Surveyed; 17 August, 2005 BPXA Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11795.00 7397.96 7267.86 N 3565.05E Projected Survey Survev tool program for MPF-89 (mwd From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 532.00 531.96 CB-SS-GYRO - Wellnav Gyro 532.00 531.96 11795.00 7397.96 MWD Magnetic • • 14 September, 2005 - 13:20 Page 6 of 6 DrillQuest 3.03.06.008 r1 -_.J • 16-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPF-89 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,795.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 911911~~5~~18 Date~l'~ ~VJ"~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~S- ®~ • • 16-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-89 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and ~`.PDF fifes. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,795.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~, ~/ ~ Date ~ ~~Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.as-o~d rL""-C:~A.NICAL INTEGRITY REPORT ~~UD D=.:~: - ~ ~~3o~OS OPER ~ FIELD ~`~ ~`~Cc:P~CI~. =;G Rr~~~ „I . r~LL NUMBER ~~~ ~-~~ n~LL DAT~_ TD:t~'1~5 ?~..'Zy~~TVD; ?BTD: t~'1~, ?ID ~~Cl, f TVD ~.si~^g : ~~ Shoe : ~~~~~ MD TVD ; LV : ~~0`~~ ?~ 'r'~`~i ~~~.~~ =_:~e_. ~~~~ Shoe. ~~'\~`~ ~ 2`TD; .'CP. ll~l~ '~~ ',"D ~~o'-='~ ~~~ P2ciser ~~~, ~~ T'J7i Set at `l®~-~ ole S,~e ~o ~ ~~ and Perfs 1\ ~~ ~- to II~Op~ ~ . L1~~--~ 11 G,`l~ '.~C'r'.~?~=C~_T, 1NTEGRTTY - P?_RT #~ cnnulus Press Test: =~ ?S min ~0 min Coc~ents '~* CHPNIC~~ INTEGRITY - pA~'T # Z ~ C(~ ~h ~~ Cement Volumes :~ ~~t. Liner c ~`~; ~ ~~5~.,~ ; DV ~~ _ __ _ c~~r~~ c~rCV~c~.~~ ~c~ ~ T~`J 1- C.~t Jol to cover ~er~; ~Mpcrtc~~c~.v~sJ~r-:c`.c.~~~-. c~~~4~~ =;:eoret~cal TOC ~ ~C h~~ ~r w Cement Bond Log (Yes or No)~LS ; In AOGCC file t,~a~1~p S~ CBL Evaluation, gone above perfs ~,~--~ Production Z.og: Type Evaluation C0~#CLJSI0~1S Part i 1 : ~ /'\ 'art f 2 : F-'l, ~ ~ S BP' EXPLORATION Page ~ of 2 Casin Re ort - Actual Data for PRODUGTiON LINER 1 Legal Well Name: MPF-89 Report #: 5 Spud Date: 7/30/2005 Gommon Well Name: MPF-$9 Start: 7/23/2005 Report Date: 8/15/2005 Event Name: DRILL+COMPLETE End: Date Landed: 8/18/2005 General Information String Type: PRODUCTION LINER 1 Permanent Daturn Mea n Sea Level Hole Size: 4.750 (in) Hole TMD: 11,795.0 (ft) Hole ND 7,425.0 (ft) KB-Datum 45.30 (ft) Water TMD: (ft) Str Wt on Slips: (Ib) Ground Level: 11.00 (ft) CF Elevation: 45.30 (ft) Liner Overlap: (ft} Max Hole Angle: 50.00 (°) Circ Hours: 3.00 (hr) Mud Lost (bbl} KB to Cutoff: 11,014.94 (ft) Days From Spud: 16.75 (days) Casing,,Flange / Wellhead anufacturer: FMC Model: FMC G29 Top Hub/Flange: 11.000 (in) i 5,000 (psi) Hanger Model: Baker HMC Packoff Model: BTM Hub/Flange: 11.000 (in) / 5,000 (psf) dual TMD Set; 11,795.00 (ft) Integral Casing Detail Rein Size vNight Grade Drift Th~aads J fS ~ ~ r~~th lop TND ~ 4anufaeturri ~ ~ f ond . P lax UD P~1in IC ~ Comp. Nair link ~Ih'fil (~,nJ ~ `t` If j rind (ink LINER TIE-BACK 6.420 1 11.08 11,014.94 BAKER NI 6.420 5.750 PACKER (PERMAN ENT) 6.540 BTC 1 6.34 11,026.02 BAKER NI 6.540 4.880 LINER HANGER 6.500 BTG 1 6.56 11,032.36 BAKER NI 6.500 4.830 O 5.670 ACME 2 3.64 11,038.92 BAKER NI 5.670 2.990 ASING PUPJOINT 4.480 9.20 L-80 IBT-M 1 3.84- 11,042.56 SUMITOMO NI 4.480 2.992 CASING JOINTS 4.250 9.20 L-80 IBT-M 21 652.04 11,046.40 SUMITOMO Nl 4.250 2.992 CASING JOINTS 4.250 9.20 L-80 IBT-M 1 31.24 11,698.44 N SUMITOMO NI 4.250 2.992 LANDING COLLAR 4.300 IBT-M 1 1.05 11,729.68 BAKER NI 4.300 3.000 ASING JOINTS 4.250 9.20 L-80 IBT-M 1 30.60 11,730.73 SUMITOMO NI 4.250 2.992 LOAT COLLAR 4.280 IBT-M 1 1.08 11,761.33 HALLIBURTON NI 4.280 CASING JOINTS 4.250 9.20 L-80 IBT-M 1 31.39 11,762.41 SUMITOMO NI 4.250 2.992 FLOAT SHOE 4.290 IBT-M 1 1.20 11,793.80 HALLIBURTON NI 4.290 Printed: 12/1EJ2005 10:46:18 AM BP EXPLORATION Page 2 of 2 Casin Re ort -Actual Data for PRODUCTION LINER 1 Legal Well Name: MPF-89 Report #: 5 Spud Date: 7/30/2005 Common Well Name: MPF-89 Start: 7/23/2005 Report Date: 8/15/2005 Event Name: DRILL+COMPLETE End: Date Landed: 8/18/2005 Non-Integral Casing Accessories r,cr_e;;or~+ ~~1~nufachirer Number n Prv~ ~ 1 op lft ) FoUom lfti CENTRALIZER HALLIBURTON 48 f Punted: 12/102005 10:46:18 AM • BP EXPLORATION Page 1 of 3 Cementing Report Legal Well Name: MPF-89 Spud Date: 7/30/2005 Common Wetl Name: MPF-89 Report #: 3 Report Date: 8!1512005 Event Name: DRILL+COMPLETE Start: 7!23/2005 End: Cement Job Type: Primary Pn~ar~_ ~nuee~ ~P~i Hnle ~Qiir:ez~ C~Sinc Plug Hole Size: 6.750 (in) Hole Size: Hole Size: Hole Size: D Set: 11,528.0 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 8/14/2005 SQ Date: Date Set: BTM set: (ft) Csg Type: DRILLING LINER 1 SQ Type: Csg Type: Plug Date: sg Size: 5.500 (in) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: DRILLING LINER 1 Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: DOWELL SCHLUMBERGER Pipe Movement Rot Time Start: 00:00 Time End: 00:00 RPM: Init Torque: (ft-Ibf) Avg Torque: (ft- Ibf) Max Torque: (ft-Ibf) Rec Time Start:23:30 Time End: 03:15 SPM: 1 Stroke Length: 20.0 (ft) Drag Up: 175 ,000 (Ib) Drag Down 116,000 (Ib) Stage No: 1 of 1 Type: PRIMARY CEMENT Start Mix Cmt: 01:40 Disp Avg Rate: 3.50 (bbl/min) Returns: Full olume Excess %:40.00 Start Slurry Displ : 02:20 Disp Max Rate: 3.50 (bbl/min) Total Mud Lost (bbl) Meas. From EST. GAUGE HOLE Start Displ: 02:35 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 03:20 Press Prior: (ft) o Cementing: 3.00 End Pump Date: 8/15/2005 Press Bumped: 3,500 (psi Ann Flow After: N Mud Circ Rate: 147 (gpm) Top Plug: N Press Held: 3 (min) Mixing Method: BATCH Mud Circ Press: 940 (psi) Bottom Plug: Y Float Held: Y Density Meas By: DENSOMETER Mud Data Type: LSND Density: 11.20 (ppg) Visc: 53 (s/qt) PJ1YP 21 (cp)/20 (Ib/100ftZ) Gels 10 sec: 9 (Ibl100ft2) Gels 10 min: 19 (Ibl100ftZ) Bottom Hole Circulating Temperature: 120 (°F) Bottom Hole Static Temperature: 148 (°F) Displacement Fluid Type: OLD MUD Density: 11.20 (ppg) Volume: 127.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: SPACER Descripti on: SPACER WATER Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: (sk) Density: 8.34 (ppg) Yield: (ft'/sk) Mix Water: () ater Source: LAKE Slurry Vo110.0 (bbl) Water Vo1:10.00 (bbl) Other Vol: (bbl) Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (ps) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (ps) Printed: 1?1162005 1Q44:49 AM BP EXPLORATION Page 2 of 3 Cementing Report Legal Well Name: MPF-89 Spud Date: 7/30/2005 Common Well Name: MPF-89 Report #: 3 Report Date: 8/15/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: SPACER Description: SPACER WEIGHTED Class: Purpose: SPACER Slurry Interval (ft) To: (ft) Cmt Vol: (sk) Density: 12.30 (ppg) Yield: (ft'/sk) Mix Water. O ater Source: LAKE Slurry Vo195.0 (bbl) Water Vo1:15.00 (bbl) Other Vol: (bbl) Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (p s) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: CEMENT Description: TAIL SLURRY Class: GCLASS Purpose: PRODUCTION Slurry Interval: 11,072.0 (ft;fo: 11,528.0 (ft)Crrrt Vol: 79 (sk) Density: 15.80 (ppg) Yield: 1.170 (ft'/sk) Mix Water: 5.16 () ater Source: DOWELL Slurry Vo116.0 (bbl) Water Vo1:9.70 (bbl) Other Vol: (bbl) -------~ Foam Job: N est Data Time Temp Pressure Thickening Time: 2.15 Temperature:120 (°F) Compressive Strength 1:3.10 120 (°F) 500 (psi) Free Water: (%) Temperature:120 (°F) Compressive Strength 2: 120 (°F) (psi) Fluid Loss: 9.0 (cc) Temperature:120 (°F) Fluid Loss Pressure: 1,000 (ps) Stage No: 1 Slurry No: 3 of 3 -Additives TradeFNam e _ ~~_ Concpntratio~~ in~ _ I iq~jd Con c. _~n~ D047 0.2 GAUSX D600G 2.0 GAUSX D065 0.3 % WT D800 0.1 % WT Printed: 12/1612005 10:44:49 PM Page 3 of 3~ BP EXPLORATION Cementing Report agal Well Name: MPF-89 ommon Well Name: MPF-89 vent Name: DRILL+COMPLETE Casing Test Shoe Test Est Press: 2,500 (ps) Pressure: 12.50 (ppge) ~r: 30 (min) Tool: N =ment Found between Open Hole: 20.0 (ft) ioe and Collar: Y Hrs Before Test 24.0 LgylSurvey Evaluation Run: N er Pressure: (psi) d Quality: Run: N d Quality: ip Survey: N Prior to Log: Spud Date: 7/30!2005 Report #: 3 Report Date: 8/15/2005 Start: 7!2312005 End: Liner Top Test Liner Lap: 114.00 Pos Test ,14.00 (ppge) Tool: N Neg Test (ppge) Tool; N Hrs Before Test 24.00 Cement Found on Tool: N Interpretation Summary Cement Top: 11,072 (ft) How Determined: TAG WITH BiT TOC Sufficient: N Job Rating: GOOD If Unsuccessful Detection Indicator: Remedia{ Cementing Required: N Number of Remedial Squeezes: Remarks to Dowell Schlumberger ip 5 bbls water t lines to 4000 ip 10 bbbs CW-100 - 3 bpm 600 psi ip 15 bbls Mud Push Mixed at 12.3 ppg - 3 bpm 960 psi ip 16 bbls 79 sxs Class "G" Yield 1.17 cflsx Mixed at 15.8 ppg - 3 bpm 865 psi p Dart c out with 2 bbls water dace with 125 bbls mud @ 11.2 ppg - 3.5 bpm 900 psi -Bump Dart with 3500 psi set HMC hanger -Rotate 15 rounds to right 3 ids back release off hanger -Bled off pressure floats holding 1.5 bbls back 03:20 hrs up to 1000 psi - Unsting -Pump 50 bbls @ 10 bpm - PP 3560 -Set down 70K rotating to set ZXP -Pick up to tie back sleave - out cement 10 bpm @ 3500 psi - No Cement seen on bottoms up 10~4A'd9 AM BP EXPLORATION Page 1 of 3 Cementing Report Legal Well Name: MPF-89 Spud Date: 7/30/2005 Gommon Well Name: MPF-89 Report #: 4 Report Date: 8/18/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Cement Job Type: Primary Primary _ rli{~pze - Open Hale : t ie~~~~, G'~sin~ --- PI i+ Hole Size: 4.750 (in) Hole Size: Hole Size: Hole Size: TMD Set: 780.1 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 8/18/2005 SQ Date: Date Set: BTM set: (ft) Csg Type: PRODUCTION LINER 1 SQ Type: Csg Type: Plug Date: sg Size: 3.500 (in) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: PRODUCTION LINER 1 Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: DOWELL SCHLUMBERGER Pipe. Movement Rot Time Start: 00:00 Time End: 00:00 RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-I bf) Max Torque: (ft-Ibf) Rec Time Start:00:30 Time Enid: 12:30 SPM: 1 Stroke Length: 20.0 (ft) Drag Up: 205 ,000 (Ib) Drag Down 105,000 (Ib) Stage'No: 1,,of 1 Type: PRIMARY CEMENT Start Mix Cmt: 12:00 Disp Avg Rate: 3.00 (bbUmin) Returns: Full olume Excess %:40.00 Start Slurry Displ: 12:00 Disp Max Rate: 3.00 (bbllmin) Total Mud Lost (bbl) Meas. From: EST. GAUGE HOLE Start Displ: 12:30 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 13:13 Press Prior: (ft) To Cementing: 12.00 End Pump Date: 8/18/2005 Press Bumped: 3,500 (ps) Ann Flow After: N Mud Circ Rate: 126 (gpm) Top Plug: N Press Held: 3 (min) Mixing Method: BATCH Mud Circ Press: 990 (ps) Bottom Plug: Y Float Held: Y Density Meas By: DENSOMEfER Mud Data Type: LSND Density: 10.00 (ppg) Visc: 61 (s/qt) P~//YF 17 (cp)/30 (Ib/100ft2) Gels 10 sec: 9 (!bl100ft2) Gels 10 min: 12 (Ibf100ft2) Bottom Hole Circulating Temperature: 120 (°F) Bottom Hole Static Temperature: 148 (°F) Displacement Fluid Type: OLD MUD Density: 10.00 (ppg) Volume: 125.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: SPACER Description: SPACER WATER Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: (sk) Density: 8.34 (ppg) Yield: (fta/sk) Mix Water: () ater Source: LAKE Slurry Vo110.0 (bbl) Water Vo1:10.00 (bbl) Other Vol: (bbl) Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (ps) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (ps) Printed: 12I1fJ2005 10:4&28 AM n BP EXPLORATION Faye 2 of 3 Cementing Report Legal Well Name: MPF-89 Spud Date: 7/30/2005 Common Well Name: MPF-89 Report #: 4 Report Date: 8/18/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: SPACER Description: SPACER WEIGHTED Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: (sk) Density: 12.30 (ppg) Yield: (ft'!sk) Mix Water: Q ater Source: LAKE Slurry Vo115.0 (bbl) Water Vo1:15.00 (bbl) Other Vol; (bbl) Foam Job: N est Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (ps) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (ps) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (p si) Stage No; 1 Slurry No: 3 of 3 Slurry Data Fluid Type: CEMENT Description: TAIL SLURRY Class: G-CLASS Purpose: PRODUCTION lurry Interval: 11,014.0 (f t)fo: 11,795.0 (ft)Cmt Vol: 123 (sk) Density: 15.80 (ppg) Yield: 1.170 {ft'/sk) Mix Water. 5.16 () ater Source: DOWELL Slurry Vo125.8 (bbl) Water Vo{:9.70 (bbl) Other Vol: (bbl) Foam Job: N est Data Time Temp Pressure Thickening Time: 4.22 Temperature:120 (°F) Compressive Strength 1:3.10 120 (°F) 500 (psi) Free Water: (%) Temperature:120 (°F) Compressive Strength 2: 120 (°F) (psi) Fluid Loss: 9.0 (cc) Temperature:120 (°F) Fluid Loss Pressure: 1,000 (psi) Stage No: 1 Slurry No: 3 of 3 -Additives -Trade Nam e _ TvnE; (;nn r i n l~ l~ ~~i~l ~~r~r , ~lni D047 0.2 GAUSX D600G 2.0 GAUSX D065 0.3 % WT D800 0.11 % Wl" Printed: 12116!2005 10:45:28 AM BP EXPLORATION Page 3 of 3 Cementing Report Legal Well Name: MPF-89 Spud Date: 7!3012005 Common Well Name: MPF-89 Report #: 4 Report Date: 8/18/2005 Event Name: DRILL+COMPLETE Start: 7/23/2005 End: Casing Test Shoe Test Liner Top Test Test Press: 3,500 (ps) Pressure: (ppge) Liner Lap:114.00 For: 30 (min) Tool: N Pos Test 14.00 (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test (ppge) Tool: N Shoe and Collar: Y Hrs Before Test 24.0 Hrs Before Test 24.00 Cement Found on Tool: N Log/Survey Evaluation Interpretation Surllmary CBL Run: N Cement Top: 11,014 (ft) Under Pressure: (ps) How Determined: CALCULATED Bond Quality: TOC Sufficient: N Cet Run: N Job Rating: GOOD Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Remarks Give to Dowell Schlumberger rump 5 bbls water est lines to 4000 Pump 5 bbbs CW-100 - 3 bpm 950 psi Pump 15 bbls Mud Push Mixed at 11 ppg - 3 bpm 960 psi Pump 25.8 bbls 123 sxs Class "G" Yield 1.17 cf/sx Mixed at 15.8 ppg - 3 bpm 865 psi Drop Dart Displace with 125 bbls mud @ 10 ppg - 3.5 bpm 900 psi -Bump Dart with 3500 psi set HMC hanger -Rotate 15 rounds to right 3 rounds back release off hanger -Bled off pressure floats holding Pressure up to 1000 psi - Unsting -Pump 25 bbls @ 10 bpm - PP 3200 -Set down 70K rotating to set ZXP -Pick up to tie back sleave - Circulate out cement 10 bpm @ 3200 psi - 8.8 bbls Cement seen on bottoms up Printed: 12!16"2005 10.45.28 AM $P EXPLC3RATlON ©alf O erations Re OI't Pacle 1 of perator: BP EXPLORATION Rig: DOYON 14 Report: 22 ell: MPF-89 Event: DRILL+COMPLETE Date: 8/1 912 0 05 p asing ¢e: in osts in: ig crept: st TVD 7,424.0 (ft) Casing (MD): 11,186.0 (ft) Daily Mud: 15,103 Rig Release: 8/21!2005 Progress: (ft) Next Casing Size: 3.500 (in) Cum Mud: 242,459 Spud Date: 7/3012005 uth Depth: 11,857,0 (ft) Next Casing (MD): 11,857.0 (ft) Daily Well: 102,361 WX Date: Hole Size: 4.750 (in) Next Casing (TV~: 7,489.0 (ft) Cum Well: 3,394,542 Elev Ref: Mean Sea Level UDFSlTarget: 21.50/20.75!20.50 Liner Size: 3.500 (in) eologist Larry Vendl Liner (MD): 11,795.0 (ft) KB Elev: 45.30 (ft) ngineer: Dave Johnson Liner Top (MD): 11,014.0 (ft) Tot. Personnel: 44 Supervisor: Green f Willoughby Program Cost Ahead: 0 USD, Days Ahead: -3.00 Weather: 3314MPH / NE / 30 urrent Status; Rigging up to run Tubing 4hr Summary: P/u head, Circ, Cement, Set liner, Circ, Displace, L1D Pipe 4hr Forecast: L!D pipe,Run Tubing, space out,land,Nipple down Nipple up. omments: No Accidents - No Spills - No Incidents a s ince ast ree a s: Last Csg Test Press.: 1,000 (psi) Last BOP Press. Test: 8/15!2005 Last Abandonment Drill: 7!29!2005 Last Trip Drill (D1): 8/17/2005 ext BOP Press. Test 8!29/2005 Last Accum. Drill (D4): 8/5!2005 Last Safety Meeting: 8/19/2005 Last Spill Drill: 8!19!2005 No. Stop Cards: Re ulato A enc Ins :N Non-compliance Issued: N Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill} FIT TVD 7,166.0 (ft) Stroke Rate Pressure Stroke Rate Pressure Stroke Rate Pressure FR EMW: 12.50 (ppg) MAASSP: 930 (psi) est Pressure: 967 (psi) Kick Tolerance: (ppg) ai o a ng eig t: a i i rs: r um a us - n i an i ser ROP Cum: Pidc Up WI.: Daily Sliding Hrs:0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate B (min): Slack Off Wt.: Cum Bit Hrs: OB (max): Circ. Rate Riser: RPM Mm.: Circ. Rate Hole: Ann. Vel. Riser: (ftlmin) RPM DH: Circ. Off Bottom: Ann. Vel. DC: 373.0 (fUmi orq. on Bottom: Circ. On Bottom: Ann. Vel. DP: 255.0 (ftimi ype: sec ge s: mg m Time/Loc: !PIT 10 min gels: (Ibi100ft2) K+: (mg/L) Solids: (%) Depth: 11,795. (ft) Fluid Loss: (ccl30min) CaC12: (%} Oil: (%) Temp: 50 (°~ HTHP Temp: (°F) NaCI: (%) Water: (°l°) Density: 8.80 (ppg) HTHP WL: (ccl30min) CI-: (mg/L) OiVWater: / Funnel Visc.: (slgt) Cake: (i32") Sand: (%) Daily Cuttings: (bbl) ECD: (ppg) MBT: (ppb) HGS: (ppb) Cum Cuttings: (bbl) PV: (cp) Lime: (ppb) LGS: (ppb) Lost Downhole: (bbl) YP (1bl100ftZ) FM: (mL) Pf/Mf: / (mUmL) Lost Surface: (bbl) rom- o rs ase as c roity o e pera ion O . De th hr) 00:00-00:30 0.50 PROD1 CASE PU P Pidc up Cement head, wash to bottom 11975' 11 795 00:30-03:30 3.00 PROD1 CASE CIR P Circ 1.5 bottoms up, and reciprocate finer 20 ft. with 30 spm, 1020 11,795 psi, P/u 205K, S/o 110K PJSM on cement/ Blendin cement 03:30-12:00 8.50 PROD1 CASE CIR N CENff Cont. to Circ and reciprocate liner, Schlumberger contaminated the Printed: 1711 C,r2005 1 Q 37:14 AM BP EXPI.Of2ATlON Dart ~ eratiOns Re OI't Page 2 of Aerator: BP EXPLORATION Rig: DOYON 14 Report: 22 ell: MFF-89 Event: DRILL+COMPI~TE Date: 8119/2005 rom- o rs ase as ctiwty a pera ion O . De th hr 03:30-12:00 8.50 PROD1 CASE CIR N CEMT mix water 11 795 12:00-13:30 1.50 PROD1 CEMT CMT P Cement with Schlumberger, with 5 bbls water, test lines 4K, 5 bbls 11,795 CW100,15 bbls Mud push 11.0 ppg, 25.5 bbls Class G, yield 1.17, 15.8 ppg, wash out line,drop dart,Displace with 40 bbls 8.6 ppg high vis, 10 bbls water,73.6 bbls 10.0# mud, cement and displacemnt was pum ed 3 bbls min, Bum plu with 3500 si, float held 13:30-14:00 0.50 PROD1 CASE PKRST P Set hanger with 70K, bleed off presure P!u 5 ft to take compression 11,795 out of pipe, turn 15 rds to right to release from hanger,pressure up to 1000 psi, unsting from hanger, psi bled off to confirm, pump cement up hole 820 ft., slack off 50K while rotating to set ZXP packer, repeat 3 times 14:00-15:00 1.00 PROD1 CASE CIR P Circ. out cement and reciprocate pipe, 100 spm 2980 psi, 8.8 bbls 11 795 cement to surface. 15:00-15:30 0.50 PROD1 CASE LD P Lay down cement head 11,795 15:30-16:00 0.50 PROD1 CASE TSTPRS P Test liner top packer with 1500 psi for 10 min., good test 11 795 16:00-17:30 1.50 PROD? CASE DISPL P Displace well with 2D bbls high vis pi11,70 bbls 8.8 brine,30 bbls high 11 795 vis ill 610 bbls 8.8 brine 100 s m 2600 si 17:30-00:00 6.50 PROD1 CASE LD P PJSfv1. Lay down 4" drill pipe om an ours om an ours om an ours FAIRWEATHER 2 DOYON 2 DOYON 27 DOYON 0 DOYON 5 fvl-I DRILLING FLUIDS 2 -SUN 2 SPERRY-SUN 2 ETCO 2 nc or Tension ig Heading: Sea Height: Rig Heave: Riser Tension: DL: Sea Dir.: Rig Roll: Riser Angle/Dir.: well Height: Sea Period: Rig Pitch: Current: Current Direction: omments: ann an e o co a ota o a ost Phase Prod % Total NPT % Total WOW °!o Tota Prod % Total NPl" °lo Total WOW % Tota Hours USD SURF 187.00 97.4% 5.00 2.6°l0 192.00 1,222,782. 3.00 100.0 3.00 186,083.0 INT1 143.00 100.0 143.00 1,032,622. PROD1 76.50 90.0°Jo 8.50 10.0% 85.00 301,415.3 LNR1 77.50 83.3% 15.50 16.7% 93.00 648,841.6 RUNCMP 2,797.0 0 0 0 0 0 0 Pl~M2tl: 77/1CY2005 1Q37:14 AM BP EXPLORATION Dail ~ e~at1UCIS Re Oft Page 1 of perator: BP EXPLORATION Rig: DOYON 14 Report: 22 ell: MPF-89 Event: DRILL+COMPLETE Date: 811 912 0 0 5 p asing ize: in os s in: ig ccept: st TVD 7,424.0 (ft) Casing (MD): 11,186.0 (ft) Daily Mud: 15,103 Rig Release: 8121!2005 rogress: (ft) Next Casing Size: 3.500 (in) Cum Mud: 242,459 Spud Date: 7{30!2005 uth Depth: 11,857.0 (ft) Next Casing (MD): 11,857.0 (ft) Daily Well: 102,361 WX Date: Hole Size: 4.750 (in) Next Casing (TVD): 7,489.0 (ft) Cum WeO: 3,394,542 Elev Ref: Mean Sea Level DOL/DFS/Target: 21.50/20.75/20.50 Liner Size: 3.500 (in) eologist Larry Vendl Liner (MD): 11,795.0 (ft) KB Elev: 45.30 (ft) Engineer: Dave Johnson Liner Top (MD): 11,014.0 (ft) Tot. Personnel: 44 upervisor: Green 1 Willoughby Program: Cost Ahead: 0 USD, Days Ahead: -3.00 Weather: 33 ! 4 MPH ! NE 130 urrent Status: Rigging up to run Tubing 4hr Summary: P/u head, Circ, Cement, Set liner, Circ, Displace, LID Pipe 4hr Forecast: L/D pipe,Run Tubing, space out,land,Nipple dowrtNipple up. omments: No Accidents - No Spills - No Incidents a s ince ast ree a s: Last Csg Test Press.: 1,000 (psi) ast BOP Press. Test: 8!15/2005 Last Abandonment Drill: 7/29/2005 Last Trip Drill (D1): 8/17/2005 ext BOP Press. Test 8129/2005 Last Accum. Drill (D4): 8/5/2005 Last Safety Meeting: 8/1912005 Last Spill Drill: 8/19/2005 . Stop Cards: Re ulato A enc Ins :N Non-com liance Issued: N Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) FIT TVD 7,166.0 (ft) Stroke Rate Pressure Stroke Rate Pressure Stroke Rate Pressure FIT EMW: 12.50 (ppg) AASSF 930 (psi) est Pressure: 967 (psi) Kick Tolerance: (ppg) ai o a mg eig ai y i rs: r um atus - n in an ts er ROP Cum: Pidc Up Wt.: Daily Sliding Hrs:0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate OB (min): Slack Off Wt.: Cum Bit Hrs: B (max): Circ. Rate Riser: RPM Mm.: Circ. Rate Hole: Ann. Vel. Riser: (fUmin) RPM DH: Circ. Off Bottom: Ann. Vel. DC: 373.0 (fUmi orq. on Bottom Circ. On Bottom Ann. Vel. DP: 255.0 (ft/mi ype: sec ge s: mg m Time/Loc: /PR 10 min gels: (Ib/100ft2) K+: (mg/L) Solids: (%) Depth: 11,795. (ft} Fluid Loss: (cc130min) CaCl2: (%) Oil: (%) Temp: 50 (°F) HTHP Temp: (°F) NaCI: (%) Water: (%) Density: 8.80 (ppg) HTHP WL: (cc/30min) CI-: (rrrg/L) OiUWater: ! Funnel Visc.: (s/qt) Cake: (/32") Sand: (%) Daily Cuttings: (bbl) ECl7. (ppg) MBT: (ppb) HGS: (ppb) Cum Cuttings: (bbl) PV: (cp) Lime: (ppb) LGS: (ppb) Lost Downhole: (bbl) YP (Ib/100ftz) PM (mL) PFIMF: / (mL/mL) Lost Surface: (bbl) roar o rs ase as c ivity a peratton Op. De th hr 00:00-00:30 0.50 PROD1 CASE PU P Pidc up Cement head, wash to bottom 11 5' ~~t'1Cl ~ 11 795 00:30-03:30 3.00 PROD1 CASE GR P Circ 1.5 bottoms up, and reciprocate liner 20 ft. with 30 spm, 1020 11,795 psi, P/u 205K, S/o 110K PJSM on cementi Blendin cement 03:30-12:00 8.50 PROD1 CASE CIR N CEMT Cont. to Circ and reciprocate finer, Schlumberger contaminated the Printed: 12!162005 11:06:12 AM BP EXPLORATION Dail O erations Re Ort Page 2 of Aerator: BP EXPLORATION Rig: DOYON 14 Report: 22 ell: MPF-89 Event: DRILL+COMPLETE Date: 8/19/2005 roar o rs ase as cUvdy a peraUon O . De th hr 03:30-12:00 8.50 PROD1 CASE CIR N CEMT mix water 11 795 12:00-13:30 1.50 PROD1 CEMT CMT P Cement with Schlumberger, with 5 bbls water, test lines 4K, 5 bbls 11,795 CW100,15 bbls Mud push 11.0 ppg, 25.5 bbls Class G, yield 1.17, 15.8 ppg, wash out line,drop dart,Displace with 40 bbls 8.6 ppg high vis, 10 bbls water,73.6 bbls 10.0# mud, cement and displacemnt was um ed 3 bbls min, Bum lu with 3500 psi, float held 13:30-14:00 0.50 PROD1 CASE PKRST P Set hanger with 70K, bleed off presure P/u 5 ft to take compression 11,795 out of pipe, turn 15 rds to right to release from hanger,pressure up to 1000 psi, unsting from hanger, psi bled off to confirm, pump cement up hole 820 ft., slack off 50K while rotating to set ZXP packer, repeat 3 times 14:00-15:00 1.00 PROD1 CASE CIR P Circ. out cement and reciprocate pipe, 100 spm 2980 psi, 8.8 bbls 11 795 cement to surface. 15:00-15:30 0.50 PROD1 CASE LD P Lay down cement head 11,795 15:30-16:00 0.50 PROD1 CASE TSTPRS P Test liner top packer with 1500 psi for 10 min., good test 11 795 16:00-17:30 1.50 PROD1 CASE DISPL P Displace well with 20 bbls high vis pi11,70 bbls 8.8 brine,30 bbls high 11 795 vis ill 610 bbls 8.8 brine 100 s m 2600 si 17:30-00:00 6.50 PROD1 CASE LD P PJSIvt, Lay down 4" drill pipe om an ours man ours om an ours FAIRWEATHER 2 DOYON 2 DOYON 27 OYON 0 DOYON 5 M-I DRILUNG FLUIDS 2 Y-SUN 2 SPERRY-SUN 2 CO 2 nc or Tension Rig Heading: Sea Height: Rig Heave: Riser Tension: L: Sea Dir.: Rig Roll: Riser Angle/Dir.: / well Height: Sea Period: Rig Pitch: Current: Current Direction: omments: anne an e o co a ota o a ost Phase Prod % Total NPT % Total WOW % Tota Prod % Total NPT °fo Total WOW % Tota Hours USD URF 187.00 97.4% 5.00 2.6% 192.00 1,222,782. PRE 3.00 100.0 3.00 186,083.0 INT1 143.00 100.0 143.00 1,032,622. PROD1 76.50 90.0% 8.50 10.0% 85.00 301,415.3 WR1 77.50 83.3% 15.50 16.7% 93:00 648,841.6 RUNCMP 2,797.0 0 0 0 0 0 0 Printed: 12/162005 11:06:12 AM BP EXPLORATION Fage 1 ot2 Gasin Re ort -Actual. Data.#or DRiLLFNG LINER 1 Legal Well Name: MPF-89 Report #: 4 Spud date: 7/30/2005 Common Well Name: MPF-89 Start: 7/23/2005 Report Date: 8/14/2005 Event Name: DRILL+COMPLETE End: Date Landed: 8/14/2005 General Information String Type: DRILLING LINER 1 Permanent Datum Mean Sea Level Hole Size: (in) Hole TMD: 11,528.0 (ft) Hole ND 7,1116.0 (ft) KB-Datum 45.30 (ft) Water TMD: (ft) Str Wt on Slips: (Ib) Ground Level: 11.00 (ft) CF Elevation : 45.30 (ft) Liner Overlap: 114.0 (ft) Max Hole Angle: 69.08 (°) Circ Hours: 3.00 (hr) Mud Lost (bbl) KB to Cutoff: 11,072.41 (ft) Days From Spud: 15.75 (days) Casing Flange (,Wellhead Manufacturer: Model: Top Hub/Flange: 11.000 (in) ! (psi) Hanger Model: Packoff Model: BTM Nub/Flange: (in) / (ps) dual TMD Set: 11,528.00 (ft) Integral Casing Detail Item Size ~ '~'deighi Grade Drift Threads ,ITS ~ L~ngfh Top ~ 1Ff ~ f'~_ii~utactwer~ Cond . 1:1ar UD Akin ID Comp. Nang (in)` ~ rll>.%ftl ~ (in) ~ jflj ittj ~ lini (in) PACKER (PERMANENT 6.540 IBT 1 17.44 11,072.41 BAKER NI 6.540 4.830 LINER HANGER 6.370 IBT 1 6.70 11,069.85 BAKER NI 6.370 4.880 UBING PUPJOINT 5.500 17.00 L-80 4.767 IBT-M 1 19.90 11,096.55 SUMITOMO NI 5.500 4.892 LINER 5.500 17.00 L-80 4.767 IBT-M 9 367.68 11,116.45 SUMITOMO NI 5.500 4.892 LANDING COLLAR 1 11,484.13 BAKER LINER 5.500 17.00 L-80 4.767 IBT-M 1 40.65 11,484.13 SUMITOMO NI 5.500 4.892 FLOAT COLLAR 6.070 IBT 1 1.42 11,524.78 HALLIBURTON NI 6.070 4.892 FLOAT SHOE 6.070 IBT 1 1.80 11,526.20 HALLIBURTON NI 6.070 4.892 - - Non-Integral Casing Accessories - - r~,C~GCSSOry , 1Vi r~nll tc~CtllrEr - S hli_lnll~: l I~ '~ _ Top.{ft) E~+~qna (ft) CENTRALIZER HALLIB URTON 20 11,116.0 11, 542. TOP RINGS HALLIBURTON 10 11,136.0 11,522.0 • Printed: 12/1fi@005 10:45:47 AM BP EXPLORATf©N Page 2 of 2 Ga in Re ort - Actual Data for DRiLL1NG LINER 1 Legal Well Name: MPF-89 Report #: 4 Spud Date: 7/30/2005 Common Well Name: MPF-89 Start: 7/23/2005 Report Date: 8/14/2005 Event Name: DRILL+COMPLETE End: Date Landed: 8/14/2005 2 perjoint with stop ring in the middle Remarks • ~~ Printed: 1211 e12005 10:0.5:47 AM • WELL SERVICE REPORT WELL JOB SCOPE UNIT M PF-89 RWO CAPITAL CTU #5 DATE DAILY WORK DAY SUPV 11/11/2005 CEMENT SQUEEZE MCINNIS COST CODE PLUS KEY PERSON NIGHT SUPV MKD337444-D DS-ANDERSON GROVER MIN ID DEPTH TTL SIZE 2.992 " 11401 FT 4.5 " DAILY SUMMARY RU CTU #5...... 13450' of 1-3/4" od CT w/722K running footage Job scope: Repair poor primary cement job on 3-1/2" liner with a LARC -RIH/Mix and pump 17 bbls 15.8 ppg LARC cmt. Could not obtain high pres squeeze. Bump whp to 2200 psi-(600 psi above SWHP) WHP holding 1980 psi.Placed 11.5 bbls cmt behind pipe. Contaminate to 11440' chase Bio to surface. POH & RD Well is FP w/ Meth 2,500'. Job not complete....Well to be left SI & WOC + 48 hours... Pack-offs leaked (due to ice on CT) Misting s ra across location. SRT est 3/4 gl.s ill of wellbore fluids. LOG ENTRIES Init T bg, IA, OA 450 0 TIME ________ DEPTH .__.___..._._ TBG _. _ _ CTP __ _ _ BPM BBLS _ _ COMMENTS _ _ _ 00:01 _..__._ 0 ___ .__ _ .. . ..____ _ . _ ____. _ T _ __..__.__.__.__..._.__.__..~.____. _._ __ _ _ _ Job start. CTU #5 out of shop from repair to T-bar . _ .~ __ _ - 00:02 . 0 _ _ . ~ T _ _______.~_..___.___._ __.__..__ _ ._._ ~__ _ _ ^._ __ ^T _ Spot equip and RU 02:59 0 Chain inspection 03:25 0 MU BHA: 2" CRCTC, 2.125" xo, 2-2" od stngrs & 2" SDN OAL 12.58' 03:34 0 Get on well and PT 200/4000 03:40 0 RIH (Well FP'd Open choke for CT displacement) 04:55 _6200 ~ 26_0 Wt ck_11.5K_ ~ ~ ~~ 05:14 7950 250 __ Wt ck 12.5K 05:46 11000 200 Wt ck 20K 05:56 _..........._...__.. 11563 .._.____.....__ 600 _...___._.._..._ _~_.._._..._ ~_._.___ ~.__.._._ Tag EZ Drill Comp. Plug PU 11,556' _._.._.~_.__ ..____.._.._.._...._........_____._.__....____~_..__.._...._W_..___.__.._ _------_.__.._...__.~._.~_.._.._-.-- 05:57 11546 575 g Paint fla #1 0_6:09 11446_ 250 _ _ Paint flag #2 (11 0' off Comp Plug) _ 06:18 11446 2025 2610 _ ~.5 0/2 _ _ _ __~ _ ^ ~~~~~ Injectivity Test down CT___. ___ __ 06:22 11446 2070 3270 1 5 I R 06:25 11446 2100 3800 1.25 7 IR 06:50 9550 _ Pull up to drop FL in backside 07:20 9550 350 450 0 0 Gas to migrating to surface 07:45 9550 2450 2600 3.5 On line with 1 % KCL down back side to kill well - 3.5 bpm at 2450 psi 09:09_ _9_550 2275 _ 2500 _ 3.5 _ 25 2/0 Swap to meth for cap on BS ~~ 09:15 9550 2250 2450 1.2 _ 262/0 _ SD pu mp on BS and RU cementers ~~~~ ~~ ...09:23.. ......._....9550... ......2040... . 2875.. ..._..._.....8.. __~__301... _ ...RIH - pump_down coil......_ ................_........__._....._............__.._..........................._.._____._..._.........._._....-.____.__.._.._...._____.~..__.... 10:30 ---._.._- 11556 -- V _-_ 2000 . _ 1850 0 Down on pump tag FasDrill at 11561' do - 11556' up 10:34 . _ 11545 .__ ..__ -._ 2100 __. 3800 _. ~ 1.5 ___.._ 322 ...._~_______..___.._ .............__...__..._._..~._...._.._______~__~_ _. -_ PUH - on line down coil with water for Injectivity rate - .5 bpm/1850 psi - 1 bpm/2025 psi - 1.5 bpm/2100 psi (max'd out on coil) -Down on pump 10:53 7400 670 820 0 PUH -let whp stabilize 11:43 11340 1870 2100 .2 348/0 RBIH- at min rate -start batching and QC cement 12:56 11340 1450 1600 .2 351 Increase pressure on IA 1400 _1_3:16 1134_0_ T 1_600 2000 .2 355 Continue at min rate d wn coil -cement ready - FL 51 mill - FC .82 " o 13:25 11542 1775 2050 _____ .6 _ 360/0 _ _ _ _ RIH to flag at 11546' -cementers ~~~ ...13:37... .......11542.. ......1600.. ......1780 _.._......_._1... ...__..__.__.___..... -cementers priming up PT lines 4000.psi ___..__.........._.._...._.......__.._..._...._...._...__........_..._._._.._._.._..._.._.._...._._..._.... 13:42 11542 1950 3000 1 Pump water spacer ahead 13:51 11542 1945 3050 1 10 Swap to cement -park above perfs at 11540' 14:08 11535 1990 2630 1 17 Swap to water (total cement pumped 17 bbls) 14:20 11535 2020 2360 1 29.6 Cement at noz i • 14:23 11535 2200 2560 14:26 11535 2100 2640 14:39 10725 1600 2600 14:46 ~ 10000 ~ 1625 ~ 1860 ~ 0 ~ 54.7 ~ SD pump and close choke CIP at 14:46 hrs -with 8 bbls behind pipe 14:56 10000 1610 2130 .5 55/0 Circulate meth over gooseneck 15:07 10000 1600 1860 .8 62.6 SD pump trap whp - FP surface line 15:11 10000 1800 2100 .2 63.2 Bump whp 200 psi to 1800 15:26 10000 1668 .2 WHP bled to 1668 15:28 10000 1818 2090 .2 63.3 Bump to 1818 psi 15:39 -_ -- __ _ 10000 1679 .3 WHP bled to 1678 .... - ._ _ 15:40 ..._._....._..___-- 10000 -___-_- 1900 --.-.--- 2100 ---__....._._ .3 ____~ _ 63._6_ ~ .._._____J~_--_--._ ~._..---..__~._.---_...._..._.._...____~ u___-----..__...----...__.._.._-.-- -.._~ Bump to 1900 psi 15:51 10000 1730 WHP bled to 1730 15:52 10000 1950 2060 .2 64.3 Bump whp to 1950 16:11 10000 1758 WHP bled to 1 758 16:12 10000 1900 2100 .3 64.4 _ _ _ Bump whp to 1900 TT 16:25 10000 1788 WHP bled t o 1788 16:26 1.0000 1900 2100 .2 64.6 _ Bump whp to 1900 16:39 10000 1806 WHP bled to 1806 16:40 10000 2000 2200 .2 64.8 Bump whp to 2000 16:50 ___ _. 10000 __ 1885 WHP bled to 1885 . .._ 16:52 ._..---._..___ 10000 _._.____ _. 2100 . 2300 T_ .2 _ .._.__ _ 65.1 ._ ___ __._.___._______.._..___._~_____...._..__..~.___.._.___________._____ Bump whp to 2100 17:02 10000 1980 WHP bled to 1980 17:04 10000 2180 2350 .3 65.4 Bump whp to 2180 17:12 10000 1985 WHP bled to 1985 17:13 _100_0_0_ 2200 2400 -~ .3 65.8 ~~ Bump whp to 2200 _17:23_ 100_00 202_2_ _ WHP bled to 2022 ^ ~ ~- ~ ~ ^ ~~ ~ ~ ~ ~ ~~ 17:25 10000 2250 2460 .3 _ 66.1 _ _ _ _ _ _ _ _ __ _ _ _ _ Bump whp to 2250 -additional 3.5 bbls for total 11.5 bbls cement behind 17:28 1000 0 2040 0 Dro 3!4" ball - bled to 2040 IA p W H P 1300 / OA 0 17:33 _ _ 10000 _ 1950 _ 3300 __ 1.2 _ ^^ _ _ _ _ _ _ _ _ On line with 2 bbl water spacer -bleed lA to 200 psi 17:35 10000 1600 3800 1.5 2 Swap to Bio 17:41 10000 1735 3835 1.6 10 RIH to contaminate cement 17:59 10950 1665 3620 1.9 31 Bio at noz inc rate 18:09 11540 1690 3700 1.9 57 Contaminate to 11540 18:14 11200 1550 3700 1.9 63 Swap to KCL 18:33 11400 1650 3000 1.9 92 Water at noz 18:34 11440 1625 3000 1.9 95 POH chasing Bio to surface after recipricating to 11440, 3 times 19:57 3800 1550 3500 2 255/0 Meth water 20:15 750 500 2300 1.5 66 Pack-off leaking drop wellhead Ares (Misting drips on location-less than a gallon spill) 20:55 0 500 2000 1.1 85 At surface Wash up BOP equipment Close in choke 21:02 0 500 1700 1 91 Close swab & Trap 500 psi on welt. (Call Endicott Env.Security (Allan) Report ___ _ ~ __ ~ _ ~ spill) 21:27 0 500 __ ____ _ _ _ __ Pop off well..... (Neal w/SRTon loation. Est. spill volume @ 314 gallon) _____ 22:08 0 RD 23:59 0 Off location .... Job incomplete.... Cement & Fas-Drill to be drilled out + 48 hrs Final Tbq, IA, OA 500 433 0 SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL ASRC $950 $950 DOW ELL $14,866 $14,866 PAD THREE ~~~~-~- --_.^ ~ $654 __ _.- _.__ _ $654 PEAK $1,186 $1,186 SCHLUMBERGER $4.820 $24.045 1 34.6 WHP increaing but not much 1 36.5 Open choke start laying in 1:1 with 7 bbls behind pipe. 1 46.5 Cement out noz. Lost add.1 bbl behind pipe -Pull to safety holding 1600 psi on well - • VECO _ _ ____ $14,627 $14,627 WAREHOUSE u $12,804 $14,44_2 HALLIBURTON $0 $7,223 LITTLE RED $0 $1.528 FLUID SUMMARY 252+60+38+2+ bbls 1 % kcl 190 bbls xskcl 7+10+5+3+12+90 bbl meth xxx bbls diesel 63 bbls Biozan 10+ 38+bbls Fresh Water 17 bbls cmt SAFETY NOTES AL FIELD ESTIMATE: Flange to valve on Tiger Tank developed a small drip. The drip was diesel and was contained inside temporary dike and cleaned up. Spill control was notified. #2 Packoff {eaked while POH. Misting occured and stained snow on location est. less than a gallon .Spill reported to Mine Security (Allan) at 21:15. WELL SERVICE REPORT WELL JOB SCOPE UNIT MPF-'89 RWO CAPITAL CTU #5 DATE DAILY WORK DAY SUPV 11!14/2005 MILL MCINNIS COST CODE PLUS KEY PERSON NIGHT SUPV MKD337444-D DS-LAVOIE GROVER MIN ID DEPTH TTL SIZE 2.992 " 11022 FT 4.5 " DAILY SUMMARY CTU 5 - M1RU - MU -RIH with BOT Motor/2.80"Cement Mill -Tag cement 11414' mill cement with light motor work to 11554'- Mill FasDrill from 11559' to 11574' FasDrill broke free- push to btm @ 11712' ctm. Circu{ate cuttings off btm to surface chasing w/ 30 bbls flopro . FP well 2,500' wi th 60/40 methanol. RD and move Job com lete LOG ENTRIES Init Tbg, IA, OA 850 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 08:01 0 Travei to MPF-89 09:0_0 _ 0 On location 09:30 _ _ _ _ 0 _ __ ~ __ _____ _ _ _ ~ ~ _ ______ __ _ _ _ MfRU_- transfer and spot support equip - ^^ ~~ ~ ~~~~ 11:15 0 _ _ __ _ MU BOT/ MHA - 2.25 CC (pull test 15k - PT 3500) - 2.13 DCV - 2.13 Disco (314 ball) - Circ Vlv (518 ball) - 2.13 X-treme Motor - 2.80 Mill - OAL 14.54' 12:17 _ _0_ ~ 850_ _ ~ 1 3 PT surface equip 300/4000 psi - test motor-heard noise 12:36 0 0 _ _ RIH -bleed whp off -pump 1 %XSKCL at min rate to displace meth from coil. 13:29 3500 45 450 .3 21 Wt ck at 8k 13:30 3500 45 350 .3 30 Safety meeting -current events -focus on job at hand -take time to do job right - _ __ __ __ _ _ __ walkarounds -notification. _ _ 13:53 3500 90 335 .3 35 __ _ _ _ Continue RIH '^ ~ _ ~~~ ~~~ ~~ 14:44 7000 90 330 .3 49 Wt ck at 14.5k 15:25 10000 100 425 _ .3_ _ 65 Wt ck at 21 k 15:45 11300 100 465 .3 _ _ 75 _ Wt ck at 26k 15:48 11325 110 1160 1.4 80 Continue RIH -increase rate -still on 1 %XSKCL 15:52 11404 110 1170_ 1.4 86_ Tag at 11404 _ ~ ~~~ 15:54 11404 110 1275 1.4 90 Motor working ~ 16:01 11413 110 1200 1.4 97 Wt ck at 25.5k 16:07 11430 110 1320 1.4 106 Swap to flopro • 16:12 11435 110 1670 1.4 111 Swap to water 16:15 11435 110 1490 1.4 118 Wt ck at 25.5k 16:37 11470 112 1285 1.5 151 Light motor work 16:40 _ _ 11_475 112. 1_290 1.5 155 Swap to flopro 16:44 _ 114_80 112 1670 _1.5_ 160_ _ Swa_p t o water ^~~ ~~~~~ 16:56 11500 113 1503 1.5 178 _ _ Wt ck at 26.2k ~~~~ ~~_~ 16:58 11505 113 1465 1.5 205 Light motor work 17:18 11530 115 1530 1.5 210 Swap to flopro 17:20 11495 190 1525 1.5 215 Swap to water 17:_24 1153_5 _130_ 1_530 1.5 22_0 Light motor work 17:36 11554 119. 1640 1.5 _ 235 _ __ _ Light motor work ~~~~~ _ Swap to flopro - 17:39 11559 120 1600 1.5 245 _ _ _ Swap to water T____ _ ~ _ 17:46 11559 120 1600 1.5 282 Milling on FasDrill 18:06 11570 150 1485 1.5 284 Wt ck at 26K 18:11 11574 120 1500 1.5 290 Motor stall 18:13 11564 130 1350 1.5 292 Swap to flopro 18:17 11572 125 1730 1.5 297 Swap to water 18:18 _ _ 11574 125 1590 1.5 __ 308 _ Motor stall ~~~~~~~`~`~~ ~ ~~ 18:31 11717 127 1495 1.5 335 Pushing FasDrill from 11574 to btm 11717 18:45 11712 125 1400 1.5 337 PU 11712 ctm - FasDrill on btm 18:51 10550 125 3000 1.5 371 Circ flopro chase cutting to surface 19:25 10600 125 3000 1.5 __ 401 1% xs kcl RBIH washing through cement area ~ 19:45_ 11_7_00_ 125_ 2790 1.6 4_30_ _ _ POH chasin g cuttings, cement to surface ~ ~ 19:46 11690 125 1600 1.5 _ 432 _ _ ____ _ Environmental standdown w/crew: discussion on the 5 incidents in Milne and corrective actions to prevent= more diligence in taking the time to get equip set up right. Weather changed immediately from fall to colder winter weather..Watching indicators for possible problems, correct working equip., proper spacing of equip., obtaining fit for purpose and right amount of equip before starting the job. Not overcoming safety systems. Stop the job if not comfortable, or don't know how to proceed. Ask questions if you don't know. The importance of location walk arounds. Hazard recognition and the tie it has to safety as well as the environment. Pressure testing, the final check for integrity of equipment. 20:06 ___..._...- 10200 --..._.._. _ _ 125 ~_____ 1400 ....._._..._.-.-- 1.5 -..._._.._.._-- 465 ......___._. _ Drop 518" ball _ _ _~_.. ._ _ - . _._ _. _ __ ~__ ` . . 20:24 9260 115 700 .6 . 486 . p _ _ _. - -_~_ . ____`. _ . _ _ _ . ~ . _ __. Dro rate for ball to seat 20:32 9080 120 3200 .6 490 Open Circ sub 20:33_ 9070_ 125 _1_200 _ __2_ 493 Increase rate POH 21:31 4000_ _ 120 1700 _2 ^ _ 604 _ __ ~ ~~ ~ Meth ~ ~~~~~ 21:44 2550 121 3700 1.9 634 _ ____ _ _ Meth @ nozzle _ ~!~^ ~~ 22:21 0 At surface. Close swab & FP surface lines 22:50 0 POP off well & !ay down BOT BHA 22:53 0 Ball recovered RD 23:59 0 Job com lete Final Tb , IA, OA 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL _ ASR_C __ _ _ _ _ --~-~- --~ ~ $950 $1,900 _ _ __.__.. --- ~__ - - BAKER THRU TUBING ---_---$4,500 _ -~~~~~ $4,500 DOW ELL $9,728 $24,594 MI FLUIDS ^_-_~^~^~~~~~ $1,845 $1,845 ORBIS _ _ ~__ ~ $438 _ ~ $438 PAD THREE $438 $1,092 PEAK $1,196 $2,3 8 2 VECO $11,045 _ _ $25,672 WAREHOUSE $9,083 $23,525 SCHLUMBERGER $0 $24,045 HALLIBURTON LITTLE RED $0 ~ $7,223 TOTAL FIELD ESTIMATE: I $39.223 I $118.743 FLUID SUMMARY 360 bbls 1 % XSKCL 5+5+5+5+5+30 bbls FloPro 3+bbls 60/40 Meth RE: FW: MPF-89i SCMT log--205-090 ~ • • Subject: RE: FW: MPF-89i SCMT 107--205-090 FrORI: "(urbanov, Ali G"' <Ali.Gurbanov@bp.com> Datc: ~~~ed, 11 .lan 2006 1 ~:~~:01 -~)900- "Co: Thomas Maunder ~ ~ om maunder(u~~rdmin.state.ak.u~=~ CC: ".lulian, .IcnniCcr Y" ~_Jennif~e.r.Julianiu~hp.com=> Hi Tom, Sorry for a delay true thought that you received all the cement reports for MPF-$9. I have just talked to Jennifer abut this she says that ail document has been faxed to you. Anyway the attachments above are the F-89 cement reports. Please let me know if you need some other information about this job. Regards, Ali Gurbanav F pad engineer phone: 907 564 50-3 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 11, 2006 2:33 PM To: Thomas Maunder Cc: Julian, Jennifer Y; Gurbanov, Ali G Subject: Re: FW: MPF-89i SCMT log--205-090 Jennifer or Ali, I was looking back at MPF-89 and I don't believe I ever received the cementing reports for the 3-1/2" liner. I have looked into our file and don't find anything there. Could you please send. Thanks, Tom Maunder, PE AOGCC Thomas Maunder wrote, On 12/16/2005 6:55 AM: Jennifer, Fax is OK. The number is 276-7542. I also need the cementing reports for the 3-1/2" liner. In particular, both should include the morning report from the rig. Thanks, Tom Maunder, PE AOGCC 1 of4 1/17/2006 4:04 PM RE: FW: MPF-89i SCMT log--205-090 • • Julian, Jennifer Y wrote, On 12/15/2005 4:49 PM: Hi Tom, Is it ok if I fax this to you? I am having trouble getting it off the web. Let me know what your fax number is if this works for you, Thanksl 1J Jennifer Julian 240-8037 (cell) From: Gurbanov, Ali G Sent: Thursday, December 15, 2005 4:37 PM To: Julian, Jennifer Y Subject: RE: FW: MPF-89i SCMT log--205-090 importance: High Hi Jennifer, Gould you please provide Tom Maunder with Coil Tubing cement resqueeze report. I"II be out of the office until 12I28/05. Many thanks, Ali From: Thomas Maunder [mailto:tom maunder@adminstate.ak.us] Sent: Thursday, December 15, 2005 1:37 PM To: Gurbanov, Ali G Cc: Ohms, Danielle H Subject: Re: FW: MPF-89i SCMT log--205-090 Previat Ali, Danielle, thanks for resending the message. The original didn't make it. I would concur with the assessment regarding the isolation from about 11560 up.. I don't have the benefit of the original log, but there is definitely a contrast in the bonding below there. Given that a squeeze was performed, the difference in age of the cement could be playing a part in the response. The bond presentation illustrates isolation sufficient to confine the water to the Kuparuk formation and to the particular interval you intend to perforate. Thanks for emailing the log. It makes for quick turnaround on your requests. One request I do have is that you send copies of the primary and squeeze cementing reports for the 3-1/2" liner. The only remaining requirement will be the witnessed MIT after the well has warmed up. Please have the field people contact the Inspector a couple of weeks after the well has been in service. Call or message with any questions. Tom Maunder, PE AOGCC Ohms, Danielle H wrote, On 12/15/2005 11:20 AM: 2 of 4 1/17/2006 4:04 PM RE: FW: MPF-89i SCMT log--205-090 • • Trying to send this again. From: Gurbanov, Ali G Sent: Wednesday, December 14, 2005 1:28 PM To: Thomas Maunder Cc: Ohms, Danielle H Subject: MPF-89i SCMT log Hi Tom, I'm the F pad engineer working for Milne point. We have obtained a second SCMT log for F-89i on 11/24/05. As you might not be familiar with the new well F-89i, I would like to give you a brief introduction about the well history. The new well F-89i has been drilled and completed in the A sands to support the offset producers L-14 and L-25. The well was completed with 3.5" liner across the A sands from 11,549' - 11,652' MD. It is anon-fractured, vertical, A sand injector. Initially this well will be perforated across the Al sands to be able to obtain maximum vertical conformance under matrix injection. After some time on injection, a decision about perforating the A2 sand will be made. The B sands will not be targeted. The first cement bond log (10/08/05) run in MPF-89i shows no cement in the bottom of the 3-1/2" liner across the Kuparuk A sands. Annular volume was over flushed by about 6 bbls. A coil tubing cement ReSqueeze was performed in order to have sufficient cement isolation above the targeted Kuparuk A sands. The second SCMT log was conducted on 12/24/05. We believe that we have good cement bond log above the target zones. 1 have talked to Gary Elmore about the last cement bond log for F-89 and he feels we have good cement up to at least 11,504' MD. Per book specifications, 3.5" casing requires less than 10 ft of 80% or better Bond Index to achieve hydraulic zonal isolation. tt appears to him we have approximately 50 ft of good cement in place above 11,554' MD. Initial Perforations are planned for: 11,592' -11,643' MD (KUP Al sands) Please let me know if you agree that the bond is adequate as we are planning to perforate this new well The attachments are the SCMT and reservoir logs. «MPF-89_24-NOV-05_SCMT PRINT_final (3).ZIP» «MPF-89i log details.ZlP» Many thanks in advance for your cooperation. Regards, Ali Gurbanov Ph: 907 564-503 PRODUCTION LINER.pdf Content-Description: PRODUCTION LINER.pdf Content-Type: application octet-stream 3 of 4 1/17/2006 4:04 PM RE: FW: MPF-89i SCMT log--205-090 • Content-Encoding: base64 Content-Description: CEMENT DRLG LNR.pdf '. ':CEMENT DRLG LNR.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: CEMENT PROD LNR.pdf ''CEMENT PROD LNR.pdf Content-Type: application/octet-stream '' Content-Encoding: base64 Content-Description: Daily Drilling Report 18.pdf Daily Drilling Report 18.pdf Content-Type: application/octet-stream Content-Encoding: base64 _ __. _. Content-Description: Daily Drilling Report 22.pdf Daily Drilling Report 22.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: DRILLING LINER.pdf iDRILLING LINERpdf Content-Type: application/octet-stream Content-Encoding: base64 _ _ _. Content-Description: F-89cement resqueeze .ZIP 'F-89cement resqueeze .ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 4 of 4 1/17/2006 4:04 PM ., _ _ itAD ~ .:: ~ _ _ ` ~ ; l!' .. .~ , ~'~ ,: k: r ~ a }~ k a y 1 33 jjj ~~~.~ ~ ~ ~G ~, ~ ' •I i ~ ~~1 ( ttt t ~ ': •~ ~r ~a• i yax 's t r ~ e s ~ .. .. " .~ + : ti V i "i ~ 5 s v ~ G: P n ~. ' '.. i . s i.~ , .n o• r =< k I R x jj G ~: . i ~j ~f r ' •» - ~ ' I I F ~ ,r 1 1 J a+~ I ~ :. } f ~ 1 •.:.:C °y ~ 1 r 1 E 3 ~ .` ~ .~ ` .: ~ i ~ ~ ~ 1 s 1 9 , r ~ r rf` j i . ~ ~; 4 ~ 2 I ~ ~ i ~ ~ k _:~ ~ ~4Ti~ICr~~fICG~ flOt SJSDOI~~~j dt ~~lh ` ~.~Ori~i ~i~° ~, 1 li .~~~~ ~~ ~_Lf(I~~~CfC _ ._ _ __. 3 -. i ~ ------ - _. ,,,,, • F ~.~` ~ ,~. ~~ ~+~~ MPF- 8 9 ~~ .~ ~~~..:.• ' API: 500292326800 ,, a..t"'_ SCALE: 1:240 PLOT DATE:13-Oct-2005 MPU XUP~adbook a 0 N ro n C Id call . ...........~ M ~ro ~N RPS ; N 6 IN 16 hl H "J H N D 2 OFR.M 200 b GRMM a SEDP IN 0 CiAPI 150 0.2 OER<u, 200 '~ -67 0 ` 5 . - - 11150 I.' ' ( H -6800 -Note: 1200 There are problems with the recorded resistivity that is displayed in this log The Gamma Ray trace is as recorded .' ~ and has not been corrected to the - ~ ;Primary Depth Controlled SCMT lag. I ` Marker picks are based on original data and have not been corrected. - ~ ~ ° - - KLGM ~- Not To Scale -~ N c c_ N ri m 0 J • KL(iM TKUD ,, ., u TD=11,795 11 /17/05 Sehiumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # I r,r, ne ..r: NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. 02-306 10980587 -- RST vain 07/17/05 oL 1 I,OIOf l;U 1 PSI-07 10674389 RST 10/27/03 1 1 PSI-07 10679045 RST 12/26/03 1 1 L3-02 11072860 RST 06/13/05 1 1 X-16A 10980531 RST 03/01/05 1 1 F-30 10987523 RST 06/22/05 1 1 W-31 10913021 RST 06/30/05 1 1 Z-15 10980580 RST 07/10/05 1 1 C-30 10980583 RST 07/13/05 1 1 W-39A 10928650 MCNL 10/16/05 1 1 18-31A H-02A 10942210 10928622 MCNL MCNL 04/28/05 04/05/05 1 1 1 1 05-24A 10928609 MCNL "(PRINT SENT 1/24/05)' 12/22/04 1 K-06A 11075903 MCNL 07/30/05 1 1 L-03 10913041 OH LDWG EDIT FOR WIRELINE DATA OS/O1/05 2 1 1 B-02A 10889169 SCMT 09/22/04 1 H-05 10674407 CBL 01/21/04 1 G-13A E-06A 10563175 11051045 SCMT SCMT 06/17/03 05/19/05 1 1 W-20 10672389 USIT 06/03/04 1 MPF-87A 10708043 USIT 01/08/04 1 MPA-03 11058243 USIT 09/07/05 1 MPF-89 r'_ 11051088 USIT 08/17/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: I~ ~`~ :~)~' 4'ji ~ 4~ ~d' ~ ,J~„~-\ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ ~~~~ li t ~-~ CJ • • • Y: ~ .. ,_ ~ ,. "' " "`° "°~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West ?th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-89, October 21, 2005 AK-MW-3856242 1 LIS formatted Disc with verification listing. 13 3 ~ ~- API#: 50-029-23268-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-technical data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99649-6612 Date: ~ ~ ~~~1 Signed: ~US -- OqC~ 10/18!05 schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh 3t NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 1 .... Il.. ..4:.. NK-20 10889223 PPROF W/DEFT 03121105 1~ P2-34 11072853 TEMPERATURE PRESSURE LOG 06/05/05 1 N-14A 10991753 LDL 01/22/05 1 4-38/K-34 10933591 PPROF WIDEFTIGHOST 10129104 1 B-19A 11058502 RST 05106105 1 1 15-31B 10942223 MCNL 07/16/05 1 1 MPF-89 11132060 SCMT (PDC-GR) 10/08!05 1 " ~"I DS 16-01 10980601 INJECTION PROFILE 08/15/05 1 DS 16-15 10980599 PPROF W/DEFT 08/13/05 1 DS 09-10 11058237 INJECTION PROFILE 08/16105 1 M-30 11072877 INJECTION PROFILE 08/04/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~ ~~ ~ Alaska Data & Consulting Services 2525 Gambell Street, Su' a 400 Anchorage, AK 99 838 A, ATTN: Beth ,'1 Received by: U C] Re: MPF-89 5-1/2 & 3-1/2 liner. Subject: Re: MPF-89 ~-I/2 ~~ 3'-1/2 liner. From: Thomas Maunder <tom_ma~u~der(aadmin.state.ak.us=~> ~,~ -~~ Date: Wed, 17 .~,u,~ ~(~c:~ti 1(~:07:~' -(~~t)O Tv: ".li~hnsc~n, Druid :~. (I~~air~~~c.~thcr)" <-john>>~cBP.com> Dave, How do you get all the fun?? Your plan is to fully cement the 3-1l2" liner to above the 5-1l2" liner. The 35' below the 5-1/2" shoe and the cement placed on up should give you isolation. It will have to be verified by log, but I don't believe that you all should have difficulty satisfying the isolation requirements. Thanks for keeping me informed. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote, On 8/17/2005 3:58 PM: Tom, On MPF-89 (an injector) we took a kick at 11475' and after killing the well, we set a drilling liner from 11072 to 11528' near the base of the D sand, as we previously discussed. The cement plug was bumped and the hanger set with 3500 psi with the liner having good integrity. Subsequently, the liner and casing was retested to 1000 psi, drilled out and an FIT equivalent to 12.5 ppg done after drilling 20' of new hole. We tripped out and ran an USIT log. The USIT log should poor bonding (for zonal isolation on an injector) and and it also appears that the liner came apart in a connection with a 2 to 3' gap at 11443' in the coupling. Tripping confirms a tight spot at that depth. The well integrity was deemed sufficient to drill ahead and our plan was to isolate the C, B and A sands with good isolation by cement in the 3-1/2" liner. The 3-1/2 liner will be set and cemented from TD to above the 5-1/2 liner top. Our current mud weight is 10.0 ppg and there is no communication with the higher pressured D zone. After drilling through the A sands it appears that approximately 40' of the D sand was faulted and we will only have 35' from the shoe of the 5-1/2 contingency liner to the top of the A sands instead of the minimum 50' to 100' that we expected. We do not see a viable way to repair the 5-1/2 liner to insure bonding in that section with the liner parted. Will 35' be sufficient with good isolation. We are currently drilling in the Miluveach and are expecting to reach TD this evening Dave 1 of 1 8/18/2005 9:07 AM STATE OF ALASKA ,i2aioa OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re~~~;y~aslmi:~.stUte.ak.us• aogcc I/Y}_~d~oe b~:v~ad :~n.state.ak.us l~ol ~ ;eckensten :~acmin.state.a~.~xs Contractor: Doyon Rig No.: 14 DATE: 8/5/2005 Rig Rep.: Egholm/Gochenauer Rig Phone: 670-3270 Rig Fax: 670-3269 Operator: BP Op. Phone: 670-3268 Op. Fax: 670-3269 Rep.: E.E. Vaughn Field/Unit & Well No.: MP F-89 PTD # 205-090 Meridian: UM Location: Section: 06 Township: T13N Range: 10E Operation: Drlg: XXXX Workover: Explor.: Test: Initial: ~CXX Weekly: Other: Test Pressure: Rams: 250/4000 Annular: 250/2500 Valves: 250/4000 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 P Pipe Rams 1 2-7/8 x 5 P Lower Pipe Rams 1 3-1/2 x 6 P Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 1 3 1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 2 P CHOKE MANIFOLD: Quantity Test Res No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3090 P Pressure After Closure 1900 P 200 psi Attained 33 P Ful{ Pressure Attained 2 min 50 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @ 2200 Test Results Number of Failures: 1 Test Time: 9 Hours Components tested Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ~ir:•3 re~~~;~adrr:in.state.a>i.us Remarks: The rig had lust come off of maintenance and the BOP was completely broken down and inspected. The rig crew failed to tighten the flange properly between the blinds and the drilling 24 HOUR NOTICE GIVEN YES x NO Date 08/03/05 Time 7:30 AM Test start Waived By Jeff Jones Witness E. Vaughn/M.Egholm Finish BOP Test (for rigs) BFL 1/28/04 BOP Doyon 14 8-05-05.x1s RE: MPF-89 Two stage cement on surface casi~ • Subject: RE: MPF-89 Two stage cement on surface casing. From: "Johnson, David A. (Fairweather)" <john23@BP.com> Date: Fri, OS Aug 2005 07:42:17 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> No lost circulation or problems circulating out the 1st stage. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, August 05, 2005 7:39 AM To: Johnson, David A. (Fairweather) Subject: Re: MPF-89 Two stage cement on surface casing. Good news Dave. I presume there was no lost circulation or other unusual events. Tom Johnson, David A. (Fairweather) wrote, On 8/5/2005 7:32 AM: Tom, The 10-3J4" cementing went as programmed. They recovered the spacer and an estimated 10 BBLS of cement from the 1st stage when they circulated through the ES Cementer. An estimated 260 BBLS of cement was circulated to surface on the second stage. Dave 1 of 1 1/11/2006 2:26 PM Re: MPF-89 Cement Volumes - 10 3/4" Surfad~sing. • Subject: Re: MPF-89 Cement Volumes - 10 3/4" Surface Casing. From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Mon, O1 Aug 2005 10:05:33 -0800 To: "Johnson, David A. (Fairweather)" <john23@BP.com> CC: "Johnson, Frederick C" <Frederick.Johnson@BP.com>, "Kara, Danny T" <KaraDT@BP.com>, Skip Coyner <Skip.Coyner@asrcenergy.com> David, It would appear that you are incorporating what cementing history is available from F pad and others in order to meet the regulatory requirements. You have "deepened" the stage tool depth which could make the difference avoiding lost circulation. Unfortunately, you will only know when you pump the job. Based on the information you have provided, you plan is acceptable. Please keep me advised regarding how the operation goes. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, For the 1st stage, MPF-88 pumped 40% volume excess from the shoe at 7859' to the ES cementer at 1935', lost returns (volume not recorded) and had 50 BBLS of cement to surface on the 1st stage displacement. They were unable to reciprocate the casing and obviously the cement channeling was extreme. The 2nd stage cement was pumped with out initially circulating and the dye marked spacer was seen in returns while still mixing cement. Possibly the 2nd stage cement filled the channel from the stage collar up. This well had a +I- 64° degree angle vs. 70° on MPF-93 and the proposed 67° on MPF-89. The casing for MPF-93 was stuck off bottom at 7925' with the ES cementer at 2509'. Assuming some channeling, the cement volume on the 1st stage cement was +/- 551ess than theoretical. Circulation was lost shortly before bumping the plug so additional cement would not have helped. No cement or spacer was seen from the 1st stage cement job indicating little channeling problems. It is doubtful that they will be able to reciprocate casing on the 1st stage for MPF-89. We could increase the cement volume slightly but I would prefer not to pump more than 10 to 15% max. We should. reach casing point sometime tomorrow morning. Dave From: Thomas Maunder [mailtoaom_maunder@admin.state.ak.us] Sent: Friday, ]uly 29, 2005 3:59 PM To: Johnson, David A. (Fairweather) Cc: Johnson, Frederick C; Kara, Danny T; Skip Coyner Subject: Re: MPF-89 Cement Volumes - 10 3/4" Surface Casing. David, et al, I understand your desire to minimize potential problems and meet the regulatory requirements. The two examples you give cover both ends of the spectrum. What was the performance on MPF-93?? I looked in the records at MPF-88 and their experience was not good at all, although it appears that a very large volume of cement was pumped on the first stage. On that basis, it is not too much of a surprise that MPF-88 had problems. I looked back on some of the wells I planned on F pad in late 1998 and 30% XS was what was used below the stage tool. We only have the DEAF summary reports in our file which don't give a lot of detail. I don't remember any problems at that time. 1/11/2006 2:26 PM Re: MPF-89 Cement Volumes - 10 3/4" Surfa•asing. Your math is correct that the planned volume is 7% XS of the total interval. Optimizing the cementing volume to avoid problems is prudent planning. It is probable that when you open the stage tool, that you will circulate up your preflush or spacer. That will give a good indication of where the cement top is. Is it planned to reciprocate the casing on the 1st stage?? Before I close my comments here, I'd like to have the answers to the questions I have posed. Thanks, Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, MPF-89 will probably be running surface casing on August 5th. The intent of the cement design on MPF-89 is not to leave an uncemented section but to avoid lost returns while initiating circulation through the ES cementer. The volume from the shoe to the ES cementer is 7% excess instead of the normal 30% excess below permafrost used on single stage cement jobs. The worst case scenario would be to lose the ability to circulate cement to surface on the 2nd stage. We are hoping to have minimum cement volume above the stage collar. MPC-42 used 5% excess volume on the 1st stage and recovered thick contaminated mud and 20 BBLS of cement. They did minor have problems during the initial circulation for the 2nd stage. MPC-43 used 1 % excess, did not recover any cement but also lost 200 BBLS of fluid while displacing the 1st stage cement. This was probably due to the length of the section. ES Maxi um 1st Sta a Volume % Excess Well Depth Cementer 9 An le Calculated Pum ed Recovered Pum ed Recove C-42 5807 1902 47.5 260.7 274 20 5% 7°l0 C-43 9361 1985 68.5 485.6 491 0 1 % 0% Note: C-43 lost 200 BBLS while cementing 1st stage Dave ', From: Thomas Maunder fmailtoaom_maunder@admin.state.ak.us] Sent: Thursday, July 28, 2005 7:09 AM To: Johnson, David A. (Fairweather) Cc: Johnson, Frederick C; Kara, Danny T; Skip Coyner Subject: Re: MPF-89 Cement Volumes - 10 3/4" Surface Casing. David, When do you anticipate cementing the surface casing on this well?? As I pointed out to Skip on MPF-91 regarding similar cement design, the plans being proposed are a combination of the surface and intermediate casing cementing requirements. If it is BP's intent to have an uncemented section of the surface casing, then a letter should be submitted requesting the variance according to the requirements ', of 20 AAC 25.030 (g). Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: 1/11/2006 2:26 PM Re: MPF-89 Cement Volumes - 10 3/4" Surfac~sing. • Tom, We have redesigned the cement volumes on MPF-89 for the 1st stage cement on the 10 3/4" surface casing.. The total volume has been reduced to 279.5 BBLS lead and tail. The reduction was made to insure that we did not get to much cement and cement contaminated mud above the ES Cementer at 2800' and reduce the possibility of losing circulation while circulating thru the ES Cementer for the 2nd stage. Due to the casing being set at 67 degrees there is a higher chance of cement channeling. This total cement volume will be 7% over gauge hole volume from the shoe to the ES Cementer at 2800'. If the hole volume runs 30% excess as is normally calculated, the cement top would be at 3500' assuming no channeling. This is +/- 667' above the TUZC. The 15.8 ppg tail cement was increased from 50 BBLS to 92 BBLS. The second stage cement has remained unchanged. A new well plan schematic is attached. Casing Size 10-3/4", 45.5, L-80, BTC Surface Casing at 6,726' MD 1st Stage - 6726' MD to 3500' MD w/ 30% Excess. Tail cement = 1000' MD Basis Use 30% excess below the Base of the Permafrost. Note: This is +/-17 BBLS (7% excess) over gauge volume to ES Cementer at 2800' Total Cement Volume: 338 bbl Wash 10 bbl water 20 bbl CW 100 Spacer 50 bbl of MudPush Lead 187.5 bbl, 237 sk of Arctic Set Lite: 10.7 ppg and 4.44 ft3/sx Tail 92 bbl, 441 sk "G" mixed at 15.8 Ib/gal & 1.17 ft3/sx Temp Casing Point BHST 80° F (estimated by Dowell) Casing Size 10-3/4", 45.5, L-80, BTC Surface Casing at 6,726' MD 2nd Stage - 2800' MD to Surface Basis Excess from Base of the Permafrost to Surface = 150% over gauge hole. Use 30% excess below the Base of the Permafrost. Tail cement = 500' MD. Total Cement Volume: 399 bbl Wash 10-bbl water 20 bbl CW 100 Spacer 50 bbl of MudPush Lead 357 bbl, 452 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft3/sx '~,' Tail 42 bbl, 202 sx "G" mixed at 15.8 Ib/gal & 1.17 ft3/sx Dave Office: 564-4171 Cel1:632-5806 «MPF-89 Well Plan Schematic.ZlP» 1/11/2006 2:26 PM M • • I;? I ~ ~ ~ ~`' rte, ~, ~-°~ , ~ ~~ ~ , ~, ,;;, ~1 ~ 1 J ~ i~ , ;., ,~ ~,;,~ ~ ~, ~' ~~ !lam ~ , ~ _ , , ~ ~~ ~ '~-; ~aSB~ OIIi ~D ~-S COI~TSERQA'TIO1~T COMI~IISSIOlY June 13, 2005 David Johnson Drilling Engineer BP Exploration (Alaska) Inc. ACT PO Box 19661 Z Anchorage, AK 99519 Request for Waiver of Diverter Requirements at 20 AAC 25.035 (c) :Milne Point Unit F-89...205-090 Dear Mr. Johnson: 333 W. 7~" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 We have received your request for exception to the Diverter requirements at 20 AAC 25.035 (c) for Milne Point F-89. In support of this request, you relate information regarding the number of wells drilled on MPU F Pad including the surface hole strata anticipated, structural setting for the Schrader Bluff formation in the area and the absence of any indications of shallow gas (free or hydrate) or over-pressure while drilling prior wells. The majority of wells on F Pad are completed in the Kuparuk River formation with a few wells completed in the Sag River. There are no Schrader Bluff wells and the nearest Schrader injection well is some 3.5 miles to the SE. The Commission agrees that the record does not reveal any known problems with natural pressure or shallow gas on F Pad. A possibility does exist for production operations to "induce" shallow hazards if there is a compromise to a well's integrity during normal operations. At this time, the Commission has not been notified that an integrity problem exists for any production or injection well on F Pad. One prior communication issue, (T x IA) on MPF-83i was repaired with a workover in summer 2004. Regardless of the past drilling history in the F Pad area, the operator must be prepared to accommodate drilling hazards that may develop over time. Each well should be carefully monitored to detect any developing drilling hazards, and subsequent operations conducted accordingly. Dialogue with Milne Point operations should be ongoing so that any changes in injection well performance are highlighted. Your request to waiver of the diverter requirements for MPF-89 (205-090) is approved. This approval is specifically for MPF-89. If waivers for additio wells on MPF pad are desired, your request should be included with the Permit to rill s done here. Please contact Tom Maunder, PE at 793-1250 with any sj,on S FRANK H. MURKOWSKl, GOVERNOR K. • ~ ~ ~ 1 ALASKA OIL A1QD GAS COI~TSERQATIOI~T COMD'IISSI011T Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPF-89i ~~ a, FRANK H. MURKOWSKI, GOVERNOR ~4 i a' ~~ 333 W. T" AVENUE. SUITE 100 ~% ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 BP Exploration (Alaska) Inc. Permit No: 205-090 Surface Location: 2162' FSL, 2889' FEL, SEC. 06, T13N, R10E (As Staked) Bottomhole Location: 4178' FSL, 4606' FEL, SEC. 32, T14N, R10E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commissio o rtness any required test. Contact the Commission's petroleum field inspector at 907) 65 -3~ (pager). Orman DATED this day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i A ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1~" /_ .. `R,; `~ ~ ,~~ Co f,, ,~ C~3 1a. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil t<Au{tipie~one ^ Stratigraphic Test ®Service ^ Development Gas ®Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^Single Well Bond No. 2S100302630-277 ~ 11. Well Name and Number: MPF-89i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11857 ° TVD 7489' 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surface: 2162' NSL 2889' WEL SEC 06 T13N R10E (As Staked) ~ 7. Property Designation: ' ADL 355017 Sands , , . , Top of Productive Horizon: 4131' NSL, 4628' WEL, SEC. 32, T14N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: 07/08/05 Total Depth: 4178' NSL, 4606' WEL, SEC. 32, T14N, R10E, UM 9. Acres in Property: ._.256ff' ~~~ ~ ~~; 14. Distance to Nearest Property: 7500' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x-541673 ' y-6035613 ~ Zone-ASP4 10. KB Elevation (Height above GL): 45.3 feet 15. Distance to Nearest well Within Pool 1280' away from MPF-61 16. Deviated Wells: Kickoff Depth: ~~'.g~' feet- Maximum Hole Angle: ~ 67 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2959 '° Surface: 2230 ~ 18. asmg Program: Size: Specifications Setting Depth Ta Bottom uantlty of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD TVD includin sta a data 42" 20" 92# H-40 Welded 72' 34' 34' 106' 106' 60 sx Arctic Set A rox. 13-1/2" 10-3/4" 45.5# L-80 BTC 6726' Surface Surface 6726' 4595' 81 sx ASL, 233 sx Class'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 11190' Surface Surface 11190' 6845' 67 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT-M 817' 11040' 6708' 11857' 7489' 164 sx Class 'G' fig. PRESENT 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): Casing Length Size Cement Volume MD TVD t C n ctor rf Int i Pr ction i r Perforation Depth MD (ft): Perforation Depth ND (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 to the best of my knowledge. Contact David Johnson, 564-4171 Printed Name Dan Kar Title Senior Drilling Engineer Prepared By Name/Number; Si nature Phone 564-5667 Date t. o ~ a5 Sondra Stewman, 564-4750 Commission Use Only Permit To Drill ~ ~,' - Number: ~~ v~® API Number: ~., 50- C.?~`' "` .Z~ ~~~ -~~ Permit Approval Date: v~ See cover letter for other requirements Conditions of Approval: Sa les equired ^ Yes ~No Mud Log Required ^ Yes No H roge Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No ~'-' APPROVED BY / ~~ ~~ A roved B THE COMMISSION Date ~P Form 10-401 ~leviSed 0 00 -°~ ~ ~ubmit/In Duplicate • • by Well Name: MPF-89 Kuparuk A Sand Injector Drilling and Completion Plan Summary T e of Well: Ku aruk A Sand In'ector Surface Location: 2,162' FSL and 2,889' FEL ' (As Staked) Section 6, T13N, R10E UM ° E = 541,673.5' - N = 6,035,613.37' ' T1 -Near Base of Colville 4010' FSL and 4683' FEL 11,163' TMD Section 32, T14N, R10E UM E = 545,090' N = 6,042,760' Z = 6,820' TVD T2 -Top of TMLV 4,131' FSL and 4,628' FEL 11,657' TMD Section 32, T14N, R10E UM E = 545,144' N = 6,042,882' Z = 7,295' TVD T3 - TD 4,178' FSL and 4,606' FEL 11,857' TMD Section 32, T14N, R10E UM E = 545,165' N = 6,042,929' Z = 7,489' TVD Distance to Pro a line 7,500' Distance to nearest well 1,280' from MPF-61 AFE Number: Estimated Start Date: 7/8/2005 Ri Do on 14 Ri da s to com lete: 21 MD: 11,857' TVD: 7,489' Max Inc: 67 KOP: 300' KBE: 45.3' Well Desi n: "S-Curve", Sin le Zone In'ector with Intermediate Casin Ob'ective: Ku aruk A Sand • • Mud Program: 13-1/2" Surface Hole (0' - 6726'): LSND Densi PV YP H API Filtrate Chlorides 8.6-9.3 10-40 25-30 8.0-9.0 NC-8.0 <1500 9-7/8" Intermediate Hole (6726' -11190'): LSND Densi PV YP H API Filtrate Chlorides 8.8-9.3 10-20 20-30 8.5-9.5 5-7 < 1500 6-3/4" Kuparuk Section (11190 -11857'): Bland LSND Dens PV YP H API Filtrate 8.8-9.3 8-15 20-28 9.0-9.5 <6 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site CaN 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 / ND 42" 20" 92# H-40 Welded 72' 34' 106' / 106' 13.5" 10.75" 45.5# L-80 BTC 6,726' 0' 6,726' / 4,595' 9.875" 7.625" 29.7# L-80 BTC-M 11,190' 0' 11,190' / 6, 845' 6.75" 4.5" 12.6# L-80 IBT-M 817' 11,040'/6,708' 11,857' / 7,489' N/A 4.5" 12.6# L-80 TCI I 11,040' 0 11,040'/6,708' Evaluation Program 13-1/2" Section Open Hole: MWD/GR Gyro IFR/CASANDRA S er InSite 9-7/8" Section Open Hole: MWD/GR/RESlABI IFR/CASANDRA S er InSite 6-3/4" Section Open Hole: MWD/GR/RES/ABI - Neu/Den/Geo Tap - +/- 90' Core (3.5") IFR/CASANDRA S er InSite Cased Hole: GR / SCMT / CCL 2 Cement Program: • Casin Size 10-3/4", 45.5, L-80, BTC Surface Casin at 6,726' MD Basis from Base of the Permafrost to Surface - % over gauge hole. Us °° excess below the Base o Permafrost. Tail cement = 500' Total Cement Volume: 858 bbl Wash 10 bbl water 25 bbl CW S acer 50 b MudPush Lead bbl, 881 sx of Arctic Set Lite: 10. and 4.44 ft /sx Tail 50 bbl, 233 sx "G" mixed at 15.6 Ib/ al & 1. 0 ft /sx Casin Point BHST 80 F estimated b Dowell Casin Size 7-5/8", 29.7#, L-80, BTC-M Intermediate Casin at 11,189' MD Basis Tail cement = 1000' MD above the T 40% Excess over Gauge Hole 1L1.,C~M ~~f. Total Cement Wash 5-bbl water Volume: 34.4 bbl 25 bbl CW 100 S acer 40 bbl of MudPush Tail 57.2 bbl, 267 sx "G" mixed at 15.6 Ib/ al & 1.20 ft /sx Tem BHST =150°F from Schlumber er Chart Liner Size 4-1/2", 12.6#, L-80, IBT-M Production Liner: 11,039'to 11,856' MD Basis Top of cement to be 200' above the TOL. Liner Lap > 150'. O en Hole excess = 40%. Total Cement Volume: 28.2 bbl Wash 5-bbl water 20 bbl CW 100 S acer 20 bbl of MudPush Tail 34.1 bbl, 164 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST =180°F from SOR Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 13.5 in Surf - 6,726' 6,726' MXC1 .50 - .70 450 - 600 2 9.875 in 6,726' -11,190' 4,464' PDC .50 - .70 500-600 3 6.75 in 11,190' - 11,857' 667' PDC .45 - .55 275-325 • • MPF-89 10-3/4" Surface Casing Revised Cementing Program June 13, 2005 Casing Size 10-3/4", 45.5, L-80, BTC Surface Casing at 6,726' MD 1 Sta e - 6726 MD to 2800 MD Basis Use 30% excess below the Base of the Permafrost. Tail cement = 500 MD. Total Cement Wash 10 bbl water Volume: 858 bbl 25 bbl CW 100 S acer 50 bbl of MudPush Lead 246 bbl, 312 sx of Arctic Set Lite: 10.7 pp and 4.44 ft /sx Tail 50 bbl, 239 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Temp Casin Point BHST 80° F estimated b Dowell Casing Size 10 3/4", 45.5, L-80, BTC Surface Casing at 6,726' MD 2 Sta e - 2800 MD to Surface Excess from Base of the Permafrost to Surface = 150% over gauge Basis hole. Use 30% excess below the Base of the Permafrost. Tail cement = 500' MD. Total Cement Wash 10-bbl water Volume: 34.4 bbl 25 bbl CW 100 S acer 50 bbl of MudPush Lead 357 bbl, 452 sx of Arctic Set Lite: 10.7 ppg and 4.44 ft /sx Tail 42 bbl, 202 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Formation Marl-cars: Formation Tops MD ft ND ft Pore Pressure si EMW Ib/ al BPRF 1985 1895 803 8.35 TUZC 4167 3401 1457 8.35 SBF1-NB 5344 4055 1741 8.35 OA 5732 4207 1807 8.35 KLGM 11190 6845 2953 8.35 TKUD 11326 6975 3009 8.35 TKUC 11450 7095 2878 7.85 TKUB 11476 7120 2888 7.85 TKUA 11548 7190 2917 7.85 TKA3 11558 7200 2921 7.85 TKA2 11574 7215 .2927 7.85 TKA1 11600 7240 2937 7.85 TMLV 11657 7295 2959 7.85 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Integrity tests: Kick tolerance: • Integrity tests: • Planned completion fluid: 2,959 psi at 7295' TVD (Top of the MLV) 2,230 psi at (Based on a full column of gas at 0.1 psi/ft) 3,000 psi $- FIT to 11.3 Ib/gal 20' below the 10-3/4" shoe. 47-bbl with 9.0 Ib/gal mud at the 10-3/4" shoe. FIT to 12.0 Ib/gai 20' below the 7-5/8" shoe. Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: • Hydrates have not been reported on any of the F-Pad wells and are not expected in MPF-89. ' • 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. ~ggardlessti of this good drilling practices need to be maintained. l Expected Pressures • The Schrader Bluff sands are expected to be normally pressured: 8.35 ppg. • The Kuparuk A sands are expected to be slight{y depleted down to 7.85 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 wi11 be employed while drilling (ie: wind socks, H2S detectors, etc.) 4 'Hydrocarbons • Hydrocarbons may be encountered in the Ugnu through the Schrader Bluff sands, and will be encountered in the Kuparuk sands. Faults One (1) fault may be intersected in the lower Colville at ± 11,083' MD, 6,745 VD 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-89 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-89 is 7,500 ft from the nearest Milne Point property line. ' Distance to Nearest Well Within Pool • MPF-89 is 1,280 ft from the nearest Kuparuk A sand penetration in MPF-61. 5 DRILL & COMPLETION PROCEDURE Pre-Riq Operations 1. .The 20" conductor will be installed pre-rig. Drillin 1. MIRT. (Install diverter unless waived by AOGCC) 2. Drill 13.5" surface hole through Schrader Bluff sands to +/-4595' TVD. - 3. Run and cement 10.75" surface casing. - 4. Install wellhead and NU/Test BOPE. 5. Drill 9.875" intermediate hole into the Kalubik. 6. Run and cement 7-5/8" intermediate casing. 7. Drill 6-3/4" hole into the Kuparuk. " 8. Take a 90' 6.5" X 3.5" core 9. Ream core run and continue drilling 6-3/4" hole through the Kuparuk sands and into the Miluveach. ~' 10. Run and cement a 4.5" liner with HGR, ZXP & PBR. ' 11. Displace the well with kill weight brine. LDDP. 12. Run a 4-1/2" tubing string for injection with packer. 13. ND BOP/NU Tree. 14. RD & MO Doyon 14. Post-Riq: 1. Freeze protect well. 2. Run GR-SCM to if not run with drilling rig. 3. Perforate well. ' 6 SIMPSON LAGOON /-~--- -___'\ z J ' " 6 5 FPAD 4 / ~ ~ 21 c~ 35'19 o_ -N- / ~ ~O ¢ ~ \ \ ~ ~ L PAD / \ Q~7 ~s s \ d Q \ -N- I I LEGEND ~ ~ 18~ 1 I \ -} AS-BUILT WELL CONDUCTOR I ^ EXISTING WELL CONDUCTOR 1 1 I ~ VICINITY MAP I ^ 78 ^ 77 ~ NOTES N.T.S. I ^ 74 ^ 73 I 1. DATES OF SURVEY: FEBRUARY 17 & 21, 1998. I ^ 70 ^ 69 2. REFERENCE FIELD BOOK: MP98-01 (P ~. 17-20). I ^ 66 ^ 65 I 3. ALASKA STATE PLANE COORDINATES I ^ 62 ^ 61 I ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 1927. ` ^ 54 ^ 53 i 5. PAD SCALE FACTOR IS 0.99990199. I ^ 91 ^ 50 ^ 49 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS F-1 SOUTH AND F-2 8g 5 I NORTH. 88 ^ 42 ^ 4 ^ 38 ^ 37 I 0 F q °°° ~E C I •86 ^ 30 ^ 29 I ° ~Q qs~ °° ` ` ^ 85 I ~ ° , 9 I ^ 26 ^ 25 ~e°49~ °e~t ^ 22 ^ 21 I °°°o°°°°°°°°°°°°°°°°°°°°°°°e°°° I ^ 83 ^ 18 ^ 17 I I ^ 14 ^ 13 I °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° ~ ~ I ~ 80 ^ 10 ^ 9 ~^~, ~° STEPHEN STOLL ° ,~ I ^ s ^ 5 I ° ~~ 6726-S ° /~T ^ 7s ^ 2 ^ 1 I ° h ° F~ Fop° °°°°°°°°P~O I I ~ESSI ONA~ ~' I 1 ~ S ER BE cOR S TMARTAMICATE 1 PROPERLY REGISTERED AND LICENSED \ ' TO PRACTICE LAND SURVEYING IN \ ' THE STATE OF ALASKA AND THAT \ F P ~ D / MAIDEPBYTMEEOREUNDER MY DRRECT SUPERVISION AND THAT ALL , 1 _ _ / 9 R8 YT21LS N A D D I 1 CORREC~ AS OF FEBRUAR I OCATF~ WITHIN PROTRACTF~ SEC. 06. T_ 13 N_ R_ 10 F.. UMIAT MERIDIAN. AI ASKA ~ WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS 81 Y=6,035,417.63 N=10,075.20 70'30'27.660" ' " 70.5076833' 11 0 1,967' FSL ' X= 541,534.68 E= 4,774.97 149'39 36.630 149.6601750" ' 3,029 FEL 86 Y=6,035,539.54 N 10,224.65 70'30'28.855" 70.5080153' 10 9 2 089' FSL ' X= 541,621.11 E= 4,775.01 149'39'34.064" 149.6594622' ' FEL 2,941 87 Y= 6,035,564.51 N 10,255.23 70'30'29.099 70.5080831' 11 1 2 114' FSL ' X= 541,638.76 E= 4,774.97 149'39'33.540" 149.6593167' ' FEL 2,923 88 Y=6,035,588.83 N=10,285.00 70'30'29.337" 70.5081492' 11 4' 2,138' FSL ' X= 541,655.92 E= 4,774.91 149'39'33.031" 149.6591753' . FEL 2,906 89 Y=6,035,613.38 N=10,315.19 70'30'29.578" 70.5082161' 11 5' 2,162' FSL ' X= 541,673.49 E= 4,775.05 149'39'32.509" 149.6590303' . FEL 2 888 90 Y=6,035,637.84 N=10,345.21 70'30'29.818" 70.5082828' 11 7 2,187' FSL ' X= 541,690.89 E= 4,775.10 149'39'31.993" 149.6588869' ' FEL 2,870 i r. xooerl, °"""'° STOLL CHECKED: RFA :• B P E X P~ O R A TI O N O n ° DATE: 2 27 98 l J~ "' DRA`MNG: MPU FAB SHEET: _,~ a Boa ND: MILNE POINT UNIT F-PAD ~ ~4~00 Cbo AS-BUILT WELL CONDUCTORS 1 of 1 0 2 27 9 ISSUED FOR INFORMATION SS A °'° ~µ°~^'~° SCALE: p pc p N0. DATE REVISION BV CHK 1 " = ZOO' 81 ~ 86~ ~~~ ~~~ 89 ~ 90 F ~~ BP EX PLORATION M P F-89 Field: Milne Point Kuparuk A Sand ENG: D. John n Pad: F-Pad Producer RIG: Doy 14 RKB: ft DIR / LWD OH FORM DE PTH HOLE CASING MUD INFO MWD LOGS MD TVD SIZE SPECS PIT INFO INFO 20.000 ' Wellhead NONE NONE Permafrost 91.1-I H-40 FMC Gen 5 106' 30° Wel d, Insul 20° x 11" 5K MWD/GR None Lead Cement Test Csg to Gyro as needed 697 Bbls, 881 sx 2000 psi IFR/Cansandra 10.7 ppg 4.44 ft3/sx Base Permafrost 1985' 1895' Surface Csa 10-3/4" 45.5# 150% Excess TUZC 4167' 3401' L-80, BTC In Permafrost • ~ Int. Yield 5210 psi / CoNaspse 2470 psi Tail Cement Schrader Bluff-NB 5344' 4055' ': , - a ; 50 bbls, 233 sx 40% Excess Bebw f, 15.6 ppg Permafrost Schrader Bluff-OA 5,732' 4,207 ~ 1.20 ft3/sx ~ Casing Point 6726' 4595' ~ ~' 13.5' MWD/GR/RES None ~~ IFR/Cansandra 67° Inter. Casina Cement Siurrv 40% Excess 7-5l8" 57.2 bbls, 267 sx 29.7 Ibs/ft 15.6 ppg -- L-80, BTC-M 1.20 ft3/sx Test Csg to Int. Yield 6890 psi Class 'G° 2500 psi Collaspse 4790 psi T of Came 10,190' 6, 49° op/LNR2XP/P ,040' 6,708' ~" KLGM 11,190' 6,845' / ;~' Cesi :Point 11,190' 6,845' "' 19.2 9.875' B/Colville MWD/GR/RES Top / Kuparuk D 11,326' 6,975' € Prod Liner Liner Cement eu/DeNGeo Ta Top / Kuparuk B 11,476' 7,120' 4-1/2" , 12.6# 28 bbl, 132 sx Test LNR to +/- 90' Core Top / Kuparuk A 11,548' 7,190' L-80, IBT-Mod Class G, 15.8# 3000 psi IFR/Cansa ra Top /Miluveach 11,657' 7,295' Int. Yie~ 8430 psi 1.17 ft3/sx 40% Excess Liner'Poirrt 11,857 7,489' 14.8' 6.75" Collaspse 7500 psi Miluveach 6/2/200 5 MPF -89 Well Plan Schem atic.xls by BP EXPLORATION MPF-89 Field: Milne Point Kuparuk A Sand ENG: D. Johnson Pad: F-Pad Producer RIG: Doyon 14 RKB: 45.3 ft DIR / LWD OH FORM DEPTH HOLE CASING MUD INFO 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 2nd Stage Lead MWD/GR None Lead Cement Test Csg to Gyro as needed 357 Bbls, 442 sx 2000 psi IFR/Cansandra 10.7 ppg-4.44 ft3/sx Tail Cement Base Permafrost 1985' 1895' 42 bbls, 202 sx Surface Csg 15.8 ppg-1.17ft3/sx 10-3/4" ES Cemente 2800' 2544' 10-3/4" 45.5# 1st Stage Lead 150 % Excess TUZC 4167' 3401' L-80, BTC Lead In Permafrost Int. Yield 5210 psi 246 Bbls, 312 Sx Collaspse 2470 psi 10.7 ppg-4.44 ft3/Sx Schrader Bluff-NB 5344' 4055' Tail Cement 30% Excess Below 50 bbls, 239 sx Permafrost Schrader Bluff-OA 5,732' 4,207' 15.8 ppg-1.17 ft3/sx Casing Point 6726' 4595' 67° 13.5" MWD/GR/RES None iFR/Cansandra 67° Inter. Casino Cement Slurry 40% Excess 7-5/8" 57.2 bbls, 267 sx 29.7 Ibs/ft 15.6 ppg L-80, BTC-M 1.20 ft3/sx Test Csg to Int. Yield 6890 psi Class "G" 2500 psi Collaspse 4790 psi Top of Cement 10,190' 6,030' 49° ~t Top/LNR/ZXP/PBR 11,040' 6,708' KLGM 11,190' 6,845' ~•" Casin Point 11,190' 6,845' 19.2' 9.875" B/Colville MWD/GR/RES Top / Kuparuk D 11,326' 6,975' "t Prod Liner Liner Cement eu/Den/Geo Ta Top / Kuparuk B 11,476' 7,120' 4-1/2" , 12.6# 28 bbl, 132 sx Test LNR to +/- 90' Core Top / Kuparuk A 11,548' 7,190' L-80, IBT-Mod Class G, 15.8# 3000 psi IFR/Cansandra Top /Miluveach 11,657' 7,295' ::: Int. Yield 8430 psi 1.17 ft3/sx 40% Excess Liner Point 11,857 7,489' 14.8' '`~ 6.75" Colaspse 7500 psi Miluveach 6/13/2005 MPF-89 Well Plan Schematic.xls Tree: 4-1/16" - 5K FMC ~ M P F-89 Pro O$e DF elev. = 45.3-ft Wellhead: 11" x 4.5" 5K p ~ Orig. GL. elev.= 11-ft w/ 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile 20" 91.1-Ib/ft H-40 Conductor @ 114` KOP @ 0' ~ Max hole angle in tubing = 67 earee 4.5" HES X-Nipple 10.75-in 45.5-Ib/ft L-80 BTC Casing @ 6726` TMD 4.5" 12.6# L-80 TCII tubing ~4 y Top 4-1/2" Liner 11,040' ZXP Liner Top Packer 7.625-in 29.7-Ib/ft L- BTC-M Casing @ 11,19 TMD ' Perforated KuparukA-ands ~ 1/2-in 12.6# L-80 IBT-M Liner@11 ,857 TMD DATE REV. BY COMMENTS Oi~lune-05 DAJ Proposed Kuparuk Injector 4.5" HES X-Nipple 7.0 x 4.5° S-3 P ' ck /- 10, 080' 4.5; HES XN- pple MILNE POINT UNIT WELL MPF-89 API NO: 50-OZ9- BP EXPLORATION (AKA Tree: 4-1/16" - 5K FMC' Wellhead: 11" x 4.5" 5K w/ 4.5" TCII T&B Tubing Hanger CIW "H" BPV profile IV11- F-~9 I-~{~ used ~DF elev. = 45.3-ft Orig. GL. elev.= 11-ft 20" 91.1-Iblft H-40 Conductor @ 114` 4.5" HES X-Nit 10.75-in 45.5-Ib/ft L-80 BTC Casing @ 6726` TMD 4.5" 12.6# L-80 TCII tubing KOP @ 300` Max hole angle in tubing = 67 degree .S X-Nipple ' x 4.5" S-3 Packer 10900` Top 4-1/2" Liner 11,040' ZXP Liner Top Packer 7.625-in 29.7-Ib/ft L-80 BT( Casing @ 11,190` TMD Perforated Kuparuk A-sands 4-1/2-in 12.6# L-t Liner @ 11,857 ~ lulu D ATF_ 01-June-05 REV. BY I COMMENTS DAJ ~ Proposed Kuparuk Injector ES XN-Nipple 3 MILNE POINT UNIT WELL MPF-89 API NO: 50-029- BP EXPLORATION ~AK~ 11~IPF-S~ Pl~nne~l Location o ~ ooa zaoo F~~t 1:12,444 ASP Zone 4 NAD 27 + LCU Marker Pick MPF-89 wp03 Q Hydraulic Units Well Status M Abandoned Gas Injector Or Gas Producer Shut-In Miscible Injector Operating ~~ Miscible Injector Shut-In ~ Not Yet Completed ! Td Not Yet Reache o NulllUnknown ~ Oil Producer Flowing ~ Oil Producer Gas lift ~ Oil Producer Hydraulic Pump ~ Oil Producer Shut-In Oil Producer Submersible O Oil Suspended ~ Oil Well o Plugged Back For Redrill O Suspended Water Injector Water Injector Injecting Water Injector Shut-In ~ Water Producer Flowinq Isr Am«° I)i1 Calulation MttIW: Mutimum C'anmve E'mr Svattn. ISCN'SA Sun INM°d: Tm. CytiMer NoM Ert°r Surface. Dligiral ~ Ca~g W'm~ting Mtth°d: Rules Bucd Start Dv 1/IlNY:3011'MD. 300TVD 1-~ Start Dtr 11100' :600' MD, 599.86"fYD Start Dir 3/1(10': 1300' MD, 128ZSITVD REFERENCE INFORMATION Coadi,ut (N/E) Ref Well Ceram: Plan MPF$9, Tme North ~ Vertcal (tVDl Refemac J13~1145.)0 Sectbn (VS)0.ef Slol- (O.OON.O.OOE) MeaswM Deph Re(eenu: 34.3 ~ I I 15.70 GkuWian Mttlnd: Me®mi Camaae - SURVEY PROGRAM Plan: MPF-89 wp03 (Plan MPF-89/MPF-89) Degh Fm Deph To Srvvry/Plan Tool Ctnted By: Digital Business Clirnt Uses Date: 5221105 34.70 12?9.00 Planed: MPF-89 wpD3 V78 Cn-GYRO-SS Cke cked: Date: 1229 q1 IIfl36.16 Phwed: MPF-89 ap03 V28 MWD~ffR+MS Revi ewed: Date: SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 600.00 3.00 25.00 599.86 7.12 3.32 1.00 25.00 7.85 4 1300.00 17.00 25.00 1287.51 117.01 54.56 2.00 0.00 129.09 5 1866.67 34.00 25.00 1797.11 337.30 157.28 3.00 0.00 372.13 6 2388.83 34.00 25.00 2230.00 601.93 280.68 0.00 0.00 664.09 7 2988.83 51.57 30.86 2668.79 958.65 473.72 3.00 15.00 1069.27 8 4588.83 51.57 30.86 3663.27 2034.60 1116.64 0.00 0.00 2317.86 9 5411.03 67.03 24.30 4082.10 2660.32 1439.80 2.00 -21.82 3021.87 10 9595.44 67.03 24.30 5715.09 6171.65 3025.11 0.00 0.00 6873.10 Il 11163.09 20.00 24.30 6820.30 7128.04 3456.92 3.00 180.00 7922.07 MPF-89 Tl wp03 12 11335.28 14.83 24.33 6984.54 7174.99 3478.13 3.00 179.91 7973.57 13 11656.76 14.83 24.33 7295.30 7249.99 3512.04 0.00 0.00 8055.85 MPF-89 T2 wp03 14 11856.76 14.83 24.33 7488.63 7296.65 3533.13 0.00 0.00 8107.04 End Dv :1866.67' MD, 1797.11' TVD }Start Dv 3/100' :2388.83' MD, 2230'IVD - -~_ [ End Dir :2988.83' MD, 2668.79' T VD ~t-, Start Dir LI00' :4588.83' MD, 3663.27'7'VD c_ 10.' 8 L a u Z F TARGET DETAILS Name TVD +N/-S +E/_W Northing Easting Shape MPF-89 Fault( 6745.30 7123.88 3306.68 6042754.99 544940.04 Polygon MPF-89 TI wp03 6820.30 7128.04 3456.92 6042759.99 545090.04 Clrcle (Radius: 200) MPF-89 Fault 2 7077.30 7546.78 3689.29 6043179.99 545320.(M Polygon MPF-89 T2 wp03 7295.30 7249.99 3512.04 6042882.23 545144.47 Circle (Radius: 200) Name M/.S *F/-W NoMmg Ea~ng ladoide Ira®mde Sla PW MPF-89 3617.19 9881.15 rA35613.7] 51167).50 70°31r29.578N Id9°79'32.509W NIA .4082.1' TVD - - ~ CASING DETAILS No. ~ ~ 1 TVD MD Name Size • I 4595.30 6726.06 10 3/4" 10.750 - ~- -- ~ ~ ~ 2 ~ 6845.30 11189.63 7 5/8" 7.625 _ ~ ~--..t..~---~~f i - , 3 7000 7487.90 11856.00 41/2" 4.500 DIr 3/100' :9595.44' MD, 5715.09'FVD FORMATION TOP DETAILS No. TVDPeth MDPath Formation 1 1895.30 1965.11 BPRF 2 3401.30 4167.35 TUZC 3 4055.30 5344.10 SBFI-NB '-89 Feult l 4 4207.30 5731.84 OA 5 6845.30 I 1189.63 KLGM 7 5/8" 6 6975.30 11325.72 TKUD 7 7095.30 11449.86 TKUC ' End Dv :11335.28' MD, 6984.54' TVD 8 7120.30 11475.73 TKUB 9 7190.30 11548.14 TKUA 10 7200.30 11558.48 TKA3 MPF-89 Fault 2 I 1 7215.30 11574.00 TKA2 12 7240.30 11599.86 TKAI 13 7295.30 11656.76 TMLV ' MPF-89 TZ 3vp03 MPF-89 wp03 4 I/2" MPF-89 i 0 1300 2600 3900 5200 6500 7800 9100 10400 11700 Vertical Section at 25.84° [1300fUinJ z 0 5 r°n ltMlrANr t1E1 AaJ REFERENCE IM1FORMATION SURVEY PROGRAM Plan: MPF-89 wp03 (Plan MPF-89/MPF-89) (1! ' BP Amoco CoaNkum (N/E) Itef We0 CeoOe' Pbn MPF-g9, Tme Nanh Depth Fm begh To SurveyiPlm Tool Created By: Dig081 Business Client Uea Date: SRl2005 Valid (TVD) R~ :74.3 + I 145.30 Celadatlon Metlnd: Mmmv®Curvrme S~ation (VSI R<fanre: Sbt- (O.ODN.O OOE) 34-70 IZi9.OD PWv~eA MPF-89 wpO3 V28 CBGYRO-SS Checked: Dete: Ener Syaem ISCWSA Meawrtd DcpN Re( ce: 34.3 t I I 43.30 1229.00 I Ig56.76 Phmad MPF-89 wp07 V28 MWD+IFR+MS Suo Method: Tnv CylvNa North Cakulslien Metlmd: Mmmimn Cim~we Etmr Surace: Fllryarel+CBdng Waning Mehod: Rules Based WELL DESMIS Narc +N/-S +Fj-W Nalshmg FmNtg Latlmde LangiNdt Sbt PIai MPF-(t9 8611.19 9884.15 6035617.37 541673.50 7(1°7029.578N 149'3972.309W NIA FORMATTON TOP DETAO-.S No. TVDPath MDPath Formation '. ~ ''~ MPF~89~I Feult 2 ~ ! ' ', 1 1895.30 1985.1 I BPRF i i ~, 2 3401.30 4167.35 TUZC I I i! 4`/~" ', I tiIPFi89 i i 3 4055.30 5344.10 SBFI-NB j ~ i I i MPF•89 I i I 4 4207.30 5731.84 OA 5 6845.30 11189.63 KLGM ' 1 I ; 7 5 .. i 6 6975.30 11325.72 TKUD ota , i ep 3' ID ~ ~, 7 7095.30 11449.83 TKUC 8 7120 30 4 i I I -- --. I ' .. MPF-89 TI 3 ~ - -- ~ i I 11 75. UB I. ~~1PF89 Fault 1 li 7 ~, I ~ i - - - - - I I ~I 9 7190.30 11548.14 TKUA _ _ 10 7200.30 11558.48 TKA3 i, ~ i ~ i ~ Ih500 i ~ d: Dir 1 11335.28 Mb, 6984:54' TVD ~' - -- - - I 11 7215.30 11574.00 TKA2 f ~~ ~ 1/ ~ I I 12 7240.30 11599.86 TKAI i 13 7295.30 11656.76 TMLV ~! i i I i _ j i I , 1 - -- ~ ~ I ~ ~~ MPF-89 T2wp03 I I f ?~ !- I ~ ~ ~ CASING DETAILS I' I I I I ' -- 1 - - -- - -- ~ ~- I I I i I i No. TVD MD Name Size - - ~ i 1 , --- - - - - -- I i : ,- 1 4595.30 6726.06 10 3/4" 10.750 -- iI ~ ~ i SthrtD7F 3 100' `.9595.44' MD, 5715. TVD '• i 2 6845.30 11189.63 7 5/8" 7.625 -- -- - _ ~ i 5 i j , ~ ., +- t---. ~ 3 7487.90 11856.00 4 1/2" 4.500 ! TARGET DETAII-S ( , ! ~ _ i I i ; I Name TVD +N/-S +FJ-W Northing Easting Shape --- - - - I I ~ -~--~ ;__~..~ ~ + MPF-89 Faultl 6745.30 7123.88 3306.88 6042754.99 544940.04 Pol on + ' Yg : ~ i -- -- i ~ - : MPF-89 TI wp03 6820.30 7128.04 3456.92 6042759.99 545090.04 Circle (Radius: 200) I ~ i ' i , I ~ _ MPF-89 Faut 7077.30 7546.78 3689.29 6043179.99 545320.04 Polygon I i ~ -- I I ~ ~ _ MPF-89 T2 wp03 7295.30 7249.99 3512.04 6042882.23 545144.47 Circle (Radius: 200) i ~ j ~ ]0314" I i ~ ~ ~ ' I I '~ SECTION DETAILS ~~~ Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target j _ _ ~ ~ ~ . ~~ I, ~ ~ 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 ' , '~ 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 j - - ~ 1500 - ` _ _ I _ 3 600.00 3.00 25.00 599.86 7.12 3.32 L00 25.00 7.85 - _ ! j _ ~ ~ ~, 4 1300.00 17.00 25.00 1287.51 117.01 54.56 2.00 0.00 129.09 5 1866.67 34.00 25.00 1797.11 337.30 157.28 3.00 0.00 372.13 I~ II/1 I 6 2388.83 34.00 25.00 2230.00 601.93 280.68 0.00 0.00 664.09 1 ~ '', '. '~ I ~ I ' - '~ - 8 4588.83 51.57 30.86 3663.27 2034.60 116.64 0.00 10.00 2067.86 9 5411.03 67.03 24.30 4082.10 2660.32 1439.80 2.00 -2L82 3021.87 ' i 1- i '~ - 10 9595.44 67.03 24.30 5715.09 6171.65 3025.11 0.00 0.00 6873.10 F~Dv :541 .03' MD, 4082.1' TVI'J i ~ I 1 I 1163.09 20.00 24.30 6820.30 7128.04 3456.92 3.00 180.00 7922.07 MPF-89 TI wp03 112 11335.28 14.83 24.33 6984.54 7174.99 3478.13 3.00 179.91 7973.57 JI 13 11656.76 14.83 24.33 7295.30 7249.99 3512.04 0.00 0.00 8055.85 MPF-89 T2 wp03 _ - ~~I ~ ', I- ~ 14 11856.76 14.83 24.33 7488.63 7296.65 3533.13 0.00 0.00 8107.04 ~ ', Qsnie tD:r x',9/7 M' ~ id RAT' AAII Tfl.9 ~9'TVI1 '. '~. West(-)/East(+) [1300ft/in] 9100 10400 Il Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/2/2005 Time: 13:27:08 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-89, True North Site: M Pt F Pad Vertical ('f VD) Reference: 34.3 + 11 45.3 Well: Plan MPF-89 Section (VS) Reference: Well (O.OON,O.OOE,25.84Azi) Wellpath; MPF-89 Survey Calculation Method: Minimum Curvature f Db: Oracle Plan: MPF-89 wp03 Date Composed: 10/7/2004 Version: 28 Principal: Yes Tied-to: From Well Ref. Point 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: bggm2004 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 Fasting: 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$9 Slot Name: Nolan Well Position: +N/-S 5613.19 ft Northing: 6035613.37 ft ~ Latitude: 70 30 29.578 N +E/-W 9884.15 ft Fasting : 541673.50 ft ~ Longitude: 149 39 32.509 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole$ize Nsme ft ft in in 6726.06 4595.30 10.750 13.500 103/4" 11189.63 6845.30 7.625 9.875 75/8" 11856.00 7487.90 4.500 6.750 4 1/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction n' n ~g dey 1985.11 1895.30 BPRF 0.00 0.00 4167.35 3401.30 TUZC 0.00 0.00 5344.10 4055.30 SBF1-NB 0.00 0.00 5731.84 4207.30 OA 0.00 0.00 11189.63 6845.30 KLGM 0.00 0.00 11325.72 6975.30 TKUD 0.00 0.00 11449.86 7095.30 TKUC 0.00 0.00 11475.73 7120.30 TKUB 0.00 0.00 11548.14 7190.30 TKUA 0.00 0.00 11558.48 7200.30 TKA3 0.00 0.00 11574.00 7215.30 TKA2 0.00 0.00 11599.86 7240.30 TKA1 0.00 0.00 11656.76 7295.30 TMLV 0.00 0.00 Targets Map Map <-- Latitude --> <-- Longitude -> Name Description TV1D +N/-S +E/-W Northing Eastiag Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPF-89 Fautt 1 6745.30 7123.88 3306.88 6042754.99 544940.04 70 31 39.632 N 149 37 55.022 W -Polygon 1 6745.30 7123.88 3306.88 6042754.99 544940.04 70 31 39.632 N 149 37 55.022 W -Polygon 2 6745.30 6333.79 4197.54 6041969.99 545835.04 70 31 31.857 N 149 37 28.778 W -Plan out by 139.86 at 6745.30 7101.52 3444.94 6042733.40 545078.21 70 31 39.411 N 149 37 50.952 W MPF-89 T1 wp03 6820.30 7128.04 3456.92 6042759.99 545090.04 70 31 39.672 N 149 37 50.598 W -Circle (Radius: 200) -Plan hit target MPF-89 Fault 2 7077.30 7546.78 3689.29 6043179.99 545320.04 70 31 43.789 N 149 37 43.742 W -Polygon 1 7077.30 7546.78 3689.29 6043179.99 545320.04 70 31 43.789 N 149 37 43.742 W -Poygon 2 7077.30 6779.17 4140.04 6042414.99 545775.04 70 31 36.238 N 149 37 30.466 W -Plan out by 403.11 at 7077.30 7197.38 3488.25 6042829.50 545120.98 70 31 40.354 N 149 37 49.674 W MPF-89 T2 wp03 7295.30 7249.99 3512.04 6042882.23 545144.47 70 31 40.871 N 149 37 48.972 W .c t Sperry-Sun BP Planning Report Companyd BP Amoco Date: 5/2/2005 Time: 13:27:08 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-89, True North Site: M Pt F Pad Vertical (TVD) Reference: 34.3 + 11 45.3 We11: P lan MPF-89 Section (VS) Reference: Well (O.OON,O. OOE,25.84Azi) Wellpath: MPF-89 : Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude -> <- Longitude -> Name Descriptlon TVD +N/-S +E/-W Northing Fasti ng Deg Min Sec Deg Min Sec Dip.: Dlr. ft ft ft ft ft -Circle (Radius: 200) -Plan hit target Plan Section Information MD Incl Aum TVI) +N/~ +E/-W DLS Bnild Tura TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 3.00 25.00 599.86 7.12 3.32 1.00 1.00 0.00 25.00 1300.00 17.00 25.00 1287.51 117.01 54.56 2.00 2.00 0.00 0.00 1866.67 34.00 25.00 1797.11 337.30 157.28 3.00 3.00 0.00 0.00 2388.83 34.00 25.00 2230.00 601.93 280.68 0.00 0.00 0.00 0.00 2988.83 51.57 30.86 2668.79 958.65 473.72 3.00 2.93 0.98 15.00 4588.83 51.57 30.86 3663.27 2034.60 1116.64 0.00 0.00 0.00 0.00 5411.03 67.03 24.30 4082.10 2660.32 1439.80 2.00 1.88 -0.80 -21.82 9595.44 67.03 24.30 5715.09 6171.65 3025.11 0.00 0.00 0.00 0.00 11163.09 20.00 24.30 6820.30 7128.04 3456.92 3.00 -3.00 0.00 180.00 MPF-89 T1 wp03 11335.28 14.83 24.33 6984.54 7174.99 3478.13 3.00 -3.00 0.02 179.91 11656.76 14.83 24.33 7295.30 7249.99 3512.04 0.00 0.00 0.00 0.00 MPF-89 T2 wp03 11856.76 14.83 24.33 7488.63 7296.65 3533.13 0.00 0.00 0.00 0.00 Survey MD Intl Azlm TVD Sys TVD N!S E1W DLS MapN MapE Tool/Comme t ft deg deg ft ft R ft deg/100ft ft ft 34.30 0.00 0.00 34.30 -11.00 0.00 0.00 0.00 6035613.37 541673.50 CB-GYRO-SS 100.00 0.00 0.00 100.00 54.70 0.00 0.00 0.00 6035613.37 541673.50 CB-GYRO-SS 200.00 0.00 0.00 200.00 154.70 0.00 0.00 0.00 6035613.37 541673.50 CB-GYRO-SS 300.00 0.00 0.00 300.00 254.70 0.00 0.00 0.00 6035613.37 541673.50 Start Dir 1/100 400.00 1.00 25.00 399.99 354.69 0.79 0.37 1.00 6035614.16 541673.86 CB-GYRO-SS 500.00 2.00 25.00 499.96 454.66 3.16 1.48 1.00 6035616.54 541674.96 CB-GYRO-SS 600.00 3.00 25.00 599.86 554.56 7.12 3.32 1.00 6035620.50 541676.78 Start Dir 2/100 700.00 5.00 25.00 699.61 654.31 13.44 6.27 2.00 6035626.84 541679.69 CB-GYRO-SS 800.00 7.00 25.00 799.06 753.76 22.91 10.68 2.00 6035636.34 541684.05 CB-GYRO-SS 900.00 9.00 25.00 898.08 852.78 35.52 16.57 2.00 6035648.98 541689.86 CB-GYRO-SS 1000.00 11.00 25.00 996.56 951.26 51.26 23.90 2.00 6035664.76 541697.11 CB-GYRO-SS 1100.00 13.00 25.00 1094.37 1049.07 70.10 32.69 2.00 6035683.65 541705.79 CB-GYRO-SS 1200.00 15.00 25.00 1191.39 1146.09 92.03 42.91 2.00 6035705.63 541715.89 CB-GYRO-SS 1300.00 17.00 25.00 1287.51 1242.21 117.01 54.56 2.00 6035730.67 541727.40 Start Dir 3/100 1400.00 20.00 25.00 1382.34 1337.04 145.76 67.97 3.00 6035759.50 541740.64 MWD+IFR+MS 1500.00 23.00 25.00 1475.37 1430.07 178.97 83.46 3.00 6035792.79 541755.94 MWD+IFR+MS 1600.00 26.00 25.00 1566.35 1521.05 216.55 100.98 3.00 6035830.47 541773.25 MWD+IFR+MS 1700.00 29.00 25.00 1655.04 1609.74 258.40 120.49 3.00 6035872.41 541792.53 MWD+IFR+MS 1800.00 32.00 25.00 1741.20 1695.90 304.39 141.94 3.00 6035918.52 541813.72 MWD+IFR+MS 1866.67 34.00 25.00 1797.11 1751.81 337.30 157.28 3.00 6035951.51 541828.87 End Dir :1866 1900.00 34.00 25.00 1824.74 1779.44 354.19 165.16 0.00 6035968.45 541836.66 MWD+IFR+MS 1985.11 34.00 25.00 1895.30 1850.00 397.32 185.28 0.00 6036011.69 541856.53 BPRF 2000.00 34.00 25.00 1907.64 1862.34 404.87 188.79 0.00 6036019.25 541860.00 MWD+IFR+MS 2100.00 34.00 25.00 1990.55 1945.25 455.55 212.43 0.00 6036070.06 541883.35 MWD+IFR+MS 2200.00 34.00 25.00 2073.45 2028.15 506.23 236.06 0.00 6036120.87 541906.69 MWD+IFR+MS 2300.00 34.00 25.00 2156.36 2111.06 556.91 259.69 0.00 6036171.67 541930.04 MWD+IFR+MS 2388.83 34.00 25.00 2230.00 2184.70 601.93 280.68 0.00 6036216.81 541950.78 Start Dir 3/100 2400.00 34.32 25.15 2239.24 2193.94 607.61 283.34 3.00 6036222.50 541953.40 MWD+IFR+MS 2500.00 37.23 26.43 2320.36 2275.06 660.23 308.80 3.00 6036275.26 541978.56 MWD+IFR+MS 2600.00 40.15 27.54 2398.41 2353.11 715.92 337.17 3.00 6036331.10 542006.62 MWD+IFR+MS 2700.00 43.08 28.52 2473.17 2427.87 774.52 368.39 3.00 6036389.87 542037.50 MWD+IFR+MS ~ ! Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/2!2005 Time: 13:27:08 Page: 3 Field: Mil ne Point Co-ordinate(NE) Reference: Well: Plan MPF -89, True North .Site: M Pt F Pad Vertical (TVD) Reference: 34.3 + 11 45.3 Well: Plan MPF-89 Section (VS) Reference: Well (O.OON,O.OOE,25.84Azi) cWellpatlc MPF-89 Survey CaMnlation Method: Minimum Curva ture Db: Oracle Survey MD Inc! Azim TVD Sys TVD N!S E/W DLS MapN MapE TooUComroe t ft deg deg ft ft ft ft deg/100ft ft ft 2800.00 46.01 29.41 2544.43 2499.13 835.88 402.37 3.00 6036451.41 542071.13 MWD+IFR+MS 2900.00 48.95 30.21 2612.01 2566.71 899.82 439.01 3.00 6036515.55 542107.42 MWD+IFR+MS 2988.83 51.57 30.86 2668.79 2623.49 958.65 473.72 3.00 6036574.57 542141.79 End Dir :2988 3000.00 51.57 30.86 2675.73 2630.43 966.16 478.21 0.00 6036582.10 542146.23 MWD+IFR+MS 3100.00 51.57 30.86 2737.89 2692.59 1033.41 518.39 0.00 6036649.57 542186.03 MWD+IFR+MS 3200.00 51.57 30.86 2800.04 2754.74 1100.65 558.57 0.00 6036717.03 542225.84 MWD+IFR+MS 3300.00 51.57 30.86 2862.20 2816.90 1167.90 598.76 0.00 6036784.50 542265.64 MWD+IFR+MS 3400.00 51.57 30.86 2924.35 2879.05 1235.15 638.94 0.00 6036851.96 542305.44 MWD+IFR+MS 3500.00 51.57 30.86 2986.51 2941.21 1302.39 679.12 0.00 6036919.43 542345.24 MWD+IFR+MS 3600.00 51.57 30.86 3048.66 3003.36 1369.64 719.30 0.00 6036986.89 542385.04 MWD+IFR+MS 3700.00 51.57 30.86 3110.82 3065.52 1436.89 759.49 0.00 6037054.36 542424.84 MWD+IFR+MS 3800.00 51.57 30.86 3172.97 3127.67 1504.13 799.67 0.00 6037121.82 542464.64 MWD+IFR+MS 3900.00 51.57 30.86 3235.13 3189.83 1571.38 839.85 0.00 6037189.28 542504.44 MWD+IFR+MS 4000.00 51.57 30.86 3297.28 3251.98 1638.63 880.03 0.00 6037256.75 542544.24 MWD+IFR+MS 4100.00 51.57 30.86 3359.44 3314.14 1705.88 920.21 0.00 6037324.21 542584.04 MWD+IFR+MS 4167.35 51.57 30.86 3401.30 3356.00 1751.17 947.28 0.00 6037369.65 542610.85 TUZC 4200.00 51.57 30.86 3421.59 3376.29 1773.12 960.40 0.00 6037391.68 542623.84 MWD+IFR+MS 4300.00 51.57 30.86 3483.75 3438.45 1840.37 1000.58 0.00 6037459.14 542663.64 MWD+IFR+MS 4400.00 51.57 30.86 3545.90 3500.60 1907.62 1040.76 0.00 6037526.61 542703.44 MWD+IFR+MS 4500.00 51.57 30.86 3608.06 3562.76 1974.86 1080.94 0.00 6037594.07 542743.24 MWD+IFR+MS 4588.83 51.57 30.86 3663.27 3617.97 2034.60 1116.64 0.00 6037654.00 542778.60 Start Dir 2/100 4600.00 51.78 30.75 3670.20 3624.90 2042.12 1121.13 2.00 6037661.55 542783.04 MWD+IFR+MS 4700.00 53.64 29.83 3730.78 3685.48 2110.82 1161.25 2.00 6037730.46 542822.78 MWD+IFR+MS 4800.00 55.51 28.96 3788.75 3743.45 2181.81 1201.24 2.00 6037801.67 542862.36 MWD+IFR+MS 4900.00 57.38 28.12 3844.02 3798.72 2255.02 1241.04 2.00 6037875.09 542901.75 MWD+IFR+MS 5000.00 59.26 27.31 3896.53 3851.23 2330.35 1280.61 2.00 6037950.64 542940.89 MWD+IFR+MS 5100.00 61.14 26.54 3946.23 3900.93 2407.72 1319.90 2.00 6038028.22 542979.75 MWD+IFR+MS 5200.00 63.03 25.79 3993.03 3947.73 2487.03 1358.87 2.00 6038107.74 543018.26 MWD+IFR+MS 5300.00 64.92 25.07 4036.90 3991.60 2568.18 1397.45 2.00 6038189.10 543056.39 MWD+IFR+MS 5344.10 65.76 24.76 4055.30 4010.00 2604.53 1414.34 2.00 6038225.54 543073.07 SBF1-NB 5400.00 66.82 24.37 4077.78 4032.48 2651.08 1435.62 2.00 6038272.20 543094.08 MWD+IFR+MS 5411.03 67.03 24.30 4082.10 4036.80 2660.32 1439.80 2.00 6038281.47 543098.21 End Dir :5411 5500.00 67.03 24.30 4116.82 4071.52 2734.98 1473.51 0.00 6038356.31 543131.50 MWD+IFR+MS 5600.00 67.03 24.30 4155.85 4110.55 2818.90 1511.39 0.00 6038440.42 543168.91 MWD+IFR+MS 5700.00 67.03 24.30 4194.87 4149.57 2902.81 1549.28 0.00 6038524.54 543206.32 MWD+IFR+MS 5731.84 67.03 24.30 4207.30 4162.00 2929.53 1561.34 0.00 6038551.33 543218.23 OA 5800.00 67.03 24.30 4233.90 4188.60 2986.73 1587.17 0.00 6038608.66 543243.73 MWD+IFR+MS 5900.00 67.03 24.30 4272.92 4227.62 3070.64 1625.05 0.00 6038692.78 543281.14 MWD+IFR+MS 6000.00 67.03 24.30 4311.95 4266.65 3154.55 1662.94 0.00 6038776.89 543318.55 MWD+IFR+MS 6100.00 67.03 24.30 4350.98 4305.68 3238.47 1700.82 0.00 6038861.01 543355.96 MWD+IFR+MS 6200.00 67.03 24.30 4390.00 4344.70 3322.38 1738.71 0.00 6038945.13 543393.38 MWD+IFR+MS 6300.00 67.03 24.30 4429.03 4383.73 3406.30 1776,60 0.00 6039029.25 543430.79 MWD+IFR+MS 6400.00 67.03 24.30 4468.05 4422.75 3490.21 1814,48 0.00 6039113.36 543468.20 MWD+IFR+MS 6500.00 67.03 24.30 4507.08 4461.78 3574.13 1852.37 0.00 6039197.48 543505.61 MWD+IFR+MS 6600.00 67.03 24.30 4546.10 4500.80 3658.04 1890.26 0.00 6039281.60 543543.02 MWD+IFR+MS 6700.00 67.03 24.30 4585.13 4539.83 3741.96 1928.14 0.00 6039365.72 543580.43 MWD+IFR+MS 6726.06 67.03 24.30 4595.30 4550.00 3763.83 1938,02 0.00 6039387.64 543590.18 10 3/4" 6800.00 67.03 24.30 4624.15 4578.85 3825.87 1966.03 0.00 6039449.83 543617.84 MWD+IFR+MS 6900.00 67.03 24.30 4663.18 4617.88 3909.78 2003.91 0.00 6039533.95 543655.25 MWD+IFR+MS 7000.00 67.03 24.30 4702.21 4656.91 3993.70 2041.80 0.00 6039618.07 543692.66 MWD+IFR+MS 7100.00 67.03 24.30 4741.23 4695.93 4077.61 2079.69 0.00 6039702.19 543730.08 MWD+IFR+MS 7200.00 67.03 24.30 4780.26 4734.96 4161.53 2117.57 0.00 6039786.30 543767.49 MWD+IFR+MS 7300.00 67.03 24.30 4819.28 4773.98 4245.44 2155.46 0.00 6039870.42 543804.90 MWD+IFR+MS Sperry-Sun BP Planning Report Company: BP Amoco Dste: 5!2/2005 Time: 13:27:08 Page: 4 Feld: Mil ne Pant Co-ordinate(NE) Refereuce: Well: Plan MPF-89, True North Site: M Pt F Pad Vertical (TVD) Reference: 34.3 + 11 45.3 Well: Plan MPF-89 5ectlon (VS) Reference: Well (O.OON,O.OOE,25.84Azi) Wellpath: MPF$9 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 7400.00 67.03 24.30 4858.31 4813.01 4329.36 2193.34 0.00 6039954.54 543842.31 MWD+IFR+MS 7500.00 67.03 24.30 4897.33 4852.03 4413.27 2231.23 0.00 6040038.66 543879.72 MWD+IFR+MS 7600.00 67.03 24.30 4936.36 4891.06 4497.19 2269.12 0.00 6040122.77 543917.13 MWD+IFR+MS 7700.00 67.03 24.30 4975.38 4930.08 4581.10 2307.00 0.00 6040206.89 543954.54 MWD+IFR+MS 7800.00 67.03 24.30 5014.41 4969.11 4665.02 2344.89 0.00 6040291.01 543991.95 MWD+IFR+MS 7900.00 67.03 24.30 5053.44 5008.14 4748.93 2382.78 0.00 6040375.13 544029.37 MWD+IFR+MS 8000.00 67.03 24.30 5092.46 5047.16 4832.84 2420.66 0.00 6040459.24 544066.78 MWD+IFR+MS 8100.00 67.03 24.30 5131.49 5086.19 4916.76 2458.55 0.00 6040543.36 544104.19 MWD+IFR+MS 8200.00 67.03 24.30 5170.51 5125.21 5000.67 2496.43 0.00 6040627.48 544141.60 MWD+IFR+MS 8300.00 67.03 24.30 5209.54 5164.24 5084.59 2534.32 0.00 6040711.60 544179.01 MWD+IFR+MS 8400.00 67.03 24.30 5248.56 5203.26 5168.50 2572.21 0.00 6040795.71 544216.42 MWD+IFR+MS 8500.00 67.03 24.30 5287.59 5242.29 5252.42 2610.09 0.00 6040879.83 544253.83 MWD+IFR+MS 8600.00 67.03 24.30 5326.61 5281.31 5336.33 2647.98 0.00 6040963.95 544291.24 MWD+IFR+MS 8700.00 67.03 24.30 5365.64 5320.34 5420.25 2685.86 0.00 6041048.07 544328.65 MWD+IFR+MS 8800.00 67.03 24.30 5404.67 5359.37 5504.16 2723.75 0.00 6041132.18 544366.07 MWD+IFR+MS 8900.00 67.03 24.30 5443.69 5398.39 5588.08 2761.64 0.00 6041216.30 544403.48 MWD+IFR+MS 9000.00 67.03 24.30 5482.72 5437.42 5671.99 2799.52 0.00 6041300.42 544440.89 MWD+IFR+MS 9100.00 67.03 24.30 5521.74 5476.44 5755.90 2837.41 0.00 6041384.54 544478.30 MWD+IFR+MS 9200.00 67.03 24.30 5560.77 5515.47 5839.82 2875.30 0.00 6041468.65 544515.71 MWD+IFR+MS 9300.00 67.03 24.30 5599.79 5554.49 5923.73 2913.18 0.00 6041552.77 544553.12 MWD+IFR+MS 9400.00 67.03 24.30 5638.82 5593.52 6007.65 2951.07 0.00 6041636.89 544590.53 MWD+IFR+MS 9500.00 67.03 24.30 5677.84 5632.54 6091.56 2988.95 0.00 6041721.01 544627.94 MWD+IFR+MS 9595.44 67.03 24.30 5715.09 5669.79 6171.65 3025.11 0.00 6041801.29 544663.65 Start Dir 3/100 9600.00 66.89 24.30 5716.87 5671.57 6175.47 3026.84 3.00 6041805.12 544665.35 MWD+IFR+MS 9700.00 63.89 24.30 5758.51 5713.21 6258.33 3064.25 3.00 6041888.18 544702.29 MWD+IFR+MS 9800.00 60.89 24.30 5804.84 5759.54 6339.09 3100.71 3.00 6041969.13 544738.29 MWD+IFR+MS 9900.00 57.89 24.30 5855.75 5810.45 6417.52 3136.12 3.00 6042047.75 544773.26 MWD+IFR+MS 10000.00 54.89 24.30 5911.10 5865.80 6493.42 3170.39 3.00 6042123.83 544807.10 MWD+IFR+MS 10100.00 51.89 24.30 5970.72 5925.42 6566.57 3203.41 3.00 6042197.17 544839.72 MWD+IFR+MS 10200.00 48.89 24.30 6034.47 5989.17 6636.78 3235.11 3.00 6042267.55 544871.02 MWD+IFR+MS 10300.00 45.89 24.30 6102.16 6056.86 6703.86 3265.40 3.00 6042334.78 544900.92 MWD+IFR+MS 10400.00 42.89 24.30 6173.60 6128.30 6767.61 3294.18 3.00 6042398.69 544929.34 MWD+IFR+MS 10500.00 39.89 24.30 6248.62 6203.32 6827.87 3321.39 3.00 6042459.09 544956.21 MWD+IFR+MS 10600.00 36.89 24.30 6326.98 6281.68 6884.46 3346.94 3.00 6042515.82 544981.44 MWD+IFR+MS 10700.00 33.89 24.30 6408.49 6363.19 6937.24 3370.77 3.00 6042568.73 545004.97 MWD+IFR+MS 10800.00 30.89 24.30 6492.92 6447.62 6986.06 3392.81 3.00 6042617.67 545026.74 MWD+IFR+MS 10900.00 27.89 24.30 6580.04 6534.74 7030.79 3413.01 3.00 6042662.51 545046.68 MWD+IFR+MS 11000.00 24.89 24.30 6669.61 6624.31 7071.30 3431.30 3.00 6042703.11 545064.74 MWD+IFR+MS 11082.64 22.41 24.30 6745.30 6700.00 7101.52 3444.94 3.00 6042733.40 545078.21 MPF-89 Fault 1 11100.00 21.89 24.30 6761.38 6716.08 7107.48 3447.63 3.00 6042739.38 545080.87 MWD+IFR+MS 11163.09 20.00 24.30 6820.30 6775.00 7128.04 3456.92 3.00 6042759.99 545090.04 MPF-89 T1 wp 11189.63 19.20 24.30 6845.30 6800.00 7136.15 3460.58 3.00 6042768.12 545093.66 7 5/8" 11200.00 18.89 24.31 6855.10 6809.80 7139.24 3461.97 3.00 6042771.21 545095.03 MWD+IFR+MS 11300.00 15.89 24.32 6950.52 6905.22 7166.47 3474.28 3.00 6042798.52 545107.18 MWD+IFR+MS 11325.72 15.12 24.33 6975.30 6930.00 7172.74 3477.11 3.00 6042804.80 545109.98 TKUD 11335.28 14.83 24.33 6984.54 6939.24 7174.99 3478.13 3.00 6042807.06 545110.98 End Dir :1133 11400.00 14.83 24.33 7047.10 7001.80 7190.09 3484.96 0.00 6042822.19 545117.73 MWD+IFR+MS 11431.24 14.83 24.33 7077.30 7032.00 7197.38 3488.25 0.00 6042829.50 545120.98 MPF-89 Fault 2 ' 11449.86 14.83 24.33 7095.30 7050.00 7201.72 3490.21 0.00 6042833.85 545122.92 TKUC 11475.73 14.83 24.33 7120.30 7075.00 7207.76 3492.94 0.00 6042839.90 545125.61 TKUB 11500.00 14.83 24.33 7143.77 7098.47 7213.42 3495.50 0.00 6042845.58 545128.14 MWD+IFR+MS 11548.14 14.83 24.33 7190.30 7145.00 7224.65 3500.58 0.00 6042856.83 545133.16 TKUA Sperry-Sun BP Planning Report • Company: BP Amoco bate: 5/2/2005 Time: 13:27:08 Page: 5 1F`etdc` Milne Point Co-ordinate(NE) Reference: Well: Plan MPF-89, True North Site: M Pt F Pad Vertical ('I'VD) Reference: 34.3 + 11 45.3 Well: Plan MPF-89 Section (VS) Reference: Well (O.OON,O.OOE,25.84Azi) Wellpat6: MPF-89 Survey Gakulation Method: Minimum Curvature Db: Oracle Survey MA ft Incl deg A73m deg TVD ft Sys TVD ft N!5 ft E/VV ft DLS deg/100ft MapN ft MapE ft TooUComme t 11558.48 14.83 24.33 7200.30 7155.00 7227.06 3501.67 0.00 6042859.25 545134.23 TKA3 11574.00 14.83 24.33 7215.30 7170.00 7230.68 3503.31 0.00 6042862.88 545135.85 TKA2 11599.86 14.83 24.33 7240.30 7195.00 7236.72 3506.04 0.00 6042868.93 545138.54 TitA1 11600.00 14.83 24.33 7240.43 7195.13 7236.75 3506.05 0.00 6042868.96 545138.56 MWD+IFR+MS 11656.76 14.83 24.33 7295.30 7250.00 7249.99 3512.04 0.00 6042882.23 545144.47 MPF-89 T2 w 11700.00 14.83 24.33 7337.10 7291.80 7260.08 3516.60 0.00 6042892.35 545148.97 MWD+IFR+MS 11800.00 14.83 24.33 7433.77 7388.47 7283.41 3527.15 0.00 6042915.73 545159.39 MWD+IFR+MS 11856.00. 14.83 24.33 7487.90 7442.60 7296.47 3533.05 0.00 6042928.83 545165.22 41/2" 11856.76 i 14.83 24.33 7488.63 ~ 7443.33 7296.65 3533.13 0.00 6042929.01 545165.30 MWD+IFR+MS M1ame Plan Mff4t9 WELL DETAILS ~N:/S ~E'-W ~oMmg Fmluig Witud< Longiauk Slor 5617.19 9riN3.15 60}561377 53167}.50 70°}tl'_9.57NA 119'79J_'.309H' ~'iA ANTI-COLLISION $ETTMGS Interpolation MethodMD Interval: 25.00 Depth Range From: 34.30 To: IIR56.76 Maximum Range: 1382.25 Reference: Plan: MPF-89 wp03 CL~MPMY DETAILS BP Amao Calculation Metlud: Mlnmwn Curvatwe Errs syaan: IscwsA Sun Meshod: Tnv ~hsrber b'oM Ermr Surf EII¢riul +Casing Wammg MerSod: Rules Bead Sl,'RVEY PROGRAM Depth Fm Degh Ta $urvayman Tool 74.30 122900 Flamed: Mff-89 wp03 V28 CB-0YRO-SS 12Mm I Ixs676 Plmmed: MPF-89 wp03 V'~ MWDrIFR~Ms WELLPATH DETABS g~ From Colow To MD Mff$' 5 34 500 Rig Ref Datum: 313 t I I 45.30fl SOO I OOO 33 ~ 0 1000 I SOO \ sax,n °'re°' .°°~ sumne A~ ~/s ~-W F19mrw lsoo zooo ' / 2000 2soo 25.84 tloo a.oo 347tl 3 a`, ~ r ~ zsoo 3000 - ,~ : ~,. ~ ~~ ~ 3000 3500 ~~'++ f~ ~ 3500 4000 ~ ~ 5 ~ = ~/ '~" 4 00 5000 LEGEnv 0 @ ~ ~" ~ X ~ ~ ~ 3t7 ~ SOOO SSOO ~ MPF-1](Mff-17),MpRisk ~ MPF-I7 (plan MPF-17 SSTk Meja Risk ~ MPF 17 PW MPF 17A M Ili k rt .Y `{ 1 r I / ~ SSOO '-_"~- " 6000 ( ) ajor s MPF IN (MPF INI Mja Risk ~ ~ ' r,, r/ ~ w ~ ~'~~ ~ ~'~r/ 6000 I IOOO I IOOO I I SOO . ~ MPF 221MPF 22) M N Rsk MPF 251 MPF 251. M Jo Rile /0 ~i ~ w."~ j 'L- f o ~ MPF-JOIMPF 701. M to Risk MPF-J31MPF 74) M Risk 3 g , ~ -~ , j ~ 11 S00 117SO , p MPF-J41PIan MPF-34 SSTk Maja Risk I I7SO 12000 ~ MPF-31(Plan MPF-34A1, Major Risk ;, s\ \~~ 12000 3000 13000 13SOO - MPF-3x IMPF Jx), Maw Risk MPF-311MPF117. Mapr Riak II ~~{jJ/ 'I 7• 1. ~ 1 1 SOO 14000 MPF-021MPF.72). xLp Risk MPF-0SIMPFd51. Malur Risk MPFJ6 (MPF-461. Mapr Rick S ~ ~ G ,a9 / " Ns' ~^F I I I T[~ ~/ / / : ,_ / OO I4SOO ~ MPF 5(1(MPF 501. Map Risk Mff-57 (MPF-SJ). IvLpr Rick ~ MPF SJOH (MPF-SIOHI. Mala Risk 7\ ~1 ~~ i- ~ ~ MPF %IMPF-%I. M+prRdc `~ MPF-611MPF-61 ), Major Risk ~-; MPFfi21MPFfi'_A Major Risk ~ MPFfiS IMPFfi53 Major Risk 13 . MPFfi6A IMPFL6A1. Afaja Risk MPFfi6IMPFfi6), Maja Risk -- MPF 66PBI MPFfibP81 Ri M k - ajor s - I 4 MPFfi91MPF-691. Maja Rek MPF-701MPF-701, Major Rck MPF-7J fMPF-711. klap Risk MPF-7J 1 MPF"]3A1 Major Rdc 0 L 270 y 90 . --- MPF-7JIMPF-]3APBIk NLIar Risk MPF-]3 (MPF-73APB '1 M er Risk ~ _ y . ~ ~~~ ~ MPF-7N (MPF 7NI. Ma Rek / ~ MPF-riI IMPF-ril 1. Major Rik ~ . MPF-N'_IMPF-ri2k Major Rink MPF-82 (MPF-ri2PB1 k Map Rek - MPf ri31Mff-87 ). Major Rssk 13 v ~ Mff-ri4 (MPF N3A ~ ~RRvk MPF-83 (MPFA/APBIk Major Risk MPF-tl4 (MPFA4B1. Major Rids -'- MPF-NSIMPF-N51, Major Rek - . ~ MPF-R6 (MPF-863. Major Rnk ' ~ MPF-tl7 (MPF-87), Mnja Rvk MPF-87 (MPF417A1 Ms r Rek p . MPF-NR (MPF-887. Major Rvk 5 ~ ~- MPF-90 (MPF-907. Maja Rck ' MPF-90 (MPF-90PBI ). Major Rsk 92 92 MPF MPF M Ri k ' - ( - ajor s 1. ~ MPF-941MPF-941. Major Risk ' MPF-9S (MPF-9s). Major Risk ~ Pl MPF91 MPF 91 M Ri k 3 p O ' ~ ~~ ~__ ~ an ( - aja s 1, ~ Plan Phelps (MPF-Phelps). Maja Risk - Plan Robyn (Robyn). M ja Risk ~ MPL-25 (MPL-251. Major Risk ~~O - /"~ l~o MPF-N9 MPF89 wp03 r "i :~ , ~ ~ ` _ ^~ 0 V.a .. f, ~ 3 ~ ~ • ••• ~K .' • ~ ~~~ ~ i f.~~~ I~" ~ ~` "~ ~ SECIiIJN DEfABS --s ~ _-s ~` ~ / ~ ue ~ yy ~ ` /~ „( " ~~ ~/ ~ ' ~ Sa MD Irc Ari 7VD M'/S ~EJ-W Dltg 7Fau VSec Tasgn r- _ - 2 ~~ -- " / - _'7r~ ~ 's~. f ~0 I sow o.oo z aooo o ro o.ao 34w om 7oouo o.oo o.BO o.ao o.oo oro oao o ao 0 00 oao ooo _ --- - ~ ~[ - / ~/ ~r . 3 3 6ooao 3.ao 4 13ao oo n ro ss.ao s99.N6 oo Iffi7 ss s1 . . 7.IZ 37z Lao ss.ao 7.Rs 117 01 sa sb zoo om 1M 09 ,75 _:. / ~~' . . s 1866.67 34.00 . . 35.W 1797.11 . . . 33730 137.28 7.00 0.00 372.13 J - ~ ~- ~ / 6 ]3Ba83 34.OD 25.00 227000 601.93 28D.68 0.00 OAO 664.09 ~ ~ ~ ~ 7 HBa83 SI.s7 30.86 2668.79 9x065 177.71 3.00 Is.00 106937 80 L. 8 438afl7 x1.57 3086 3663.27 2036.60 1116.61 0.00 O.OD 2317.86 10 9 5411.03 67.03 2430 aaR2.10 266072 1439.80 200 -21.82 3021.87 OO 10 9595.14 67.03 2470 571509 61]163 3025.11 000 0.00 6R7J.10 it II 163.09 20.00 24.70 6620.70 7128.07 3456.92 3.00 18000 792207 MPF-89 TI wp03 ravelling ylinder Azimuth (TFO+AZI) [d g] vs entre to Centre Separation [25Win] 12 11333.ffi 14.83 13 11656.76 11.83 H 11836.76 14.83 24.73 6984.5/ 2433 7295.311 2433 748867 7171.99 )478.11 3.00 179.91 797357 7249.99 7512.01 0.00 0.00 8055.85 A4PF-8977 wp03 7296.65 7537.13 0.00 000 8107.01 _J I J RE: Permit Application Subject: RE: Permit Application From: "Johnson, David A. (Fairweather)" <john23@BP.com> Date: Mon, 13 Jun 2005 10:00:04 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> • Tom, I agree, without a 100°lo assurance we will not take the risk. The revised cement program and revised wail plan schematic is attached. Dave From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 13, 2005 9:43 AM To: Johnson, David A. (Fairweather) Subject: Re: Permit Application Thanks Dave. A single stage might work, but that is a long way and if it doesn't then the recovery scenarios aren't very attractive. Tom Johnson, David A. (Fairweather) wrote: Tam, In answer to year questians. 1) There is some uncertainty about the hydraulic unit line. According to geology it is mare likely to the west than east. 2} The packer depth should have been +l-11,900' and not 11,080'. A corrected proposed completion diagram is attached, 3) The surface casing job will be done in two stages. The cement company believes it can be accomplished in a single stage but has not presented compelling data. I will send you the new program today. 4) The cement top for the 7-5/8" casing will be 1000' above the KLGM and not the TUZC. Dave From: Thomas Maunder [mailto:tom maunder@admin,state.ak,us] Sent: Monday, June 13, 2005 8:15 AM To: Johnson, David A. (Fairweather) Subject: Re: Permit Application Dave, Thanks for the map. I have included it in the file. It appears that the only well in the area is MPF-61 at the outer edge. A couple of questions. 1. Is there some uncertainty about the hydraulic units?? The well course is pretty well "on the line". 2. You are proposing to set the packer nearly 1000' above the liner top. What is the reasoning?? 3. Is the surface cement job still planned as a single stage?? 1 of 2 6/13/2005 10:07 AM 4. The statement for the TOC ~e 7-5/8" casing on page 3 says TUZC. B!I on your drawing, I believe it should say "KLGM". Call or message with any questions/comments. Tom Maunder, PE AOGCC Johnson, David A. (Fairweather) wrote: Tom, When the permit application for the injector MPF-89 was sent, the map showing surrounding wells was inadvertently not included. I attached the map and would appreciate it if you could include it with the application. Dave «MPF-89 Area.ZlP» Content-Description: MPF-89 Well Plan Schematic.ZIP .'.MPF-89 Well Plan Schematic.ZIP', Content-Type: application/x-zip-compressed Content-Encoding: base64 Content-Description• MPF-89 Revised Cement -Surface MPF-89 Revised Cement -Surface Casing.doc • Casing.doc Content-Type: application/msword Content-Encoding: base64 2 of 2 6/13/2005 10:07 AM • • by June 6`f', 2005 <' (',l / f Tom Maunder Alaska Oil & Gas Conservation Commission ,~_° 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 _ ~1 Re: Request for Exception to 20 AAC 25.035 (c) - - MPU F-Pad /MPF-89 Mr. Maunder: BP Exploration (Alaska) Inc. ("BP") hereby to 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-89, a Kupazuk A sand injector. The MPF-89 well plan includes 10-3/4" 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 hydrocazbon bearing zone in this hole section is the Schrader Bluff "O" sands. The Schrader Bluff "O" sands that underlie F-Pad aze 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 neazest 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 564-4171, or Dan Kaza at 564-5803. Dave Johnson Drilling Engir BPXA /ACT 1 46 00 W 1 1 I 149 44 00 W 149 42 00 W ,. 1 1491 ?0;,00 W ! 149 38 00 W ' 1 ~ 23 24 ~; q AIPU -9 O • y~ RIPV A--66 - q ~ ~~ - r AIPU(F 95 r ` I ' '~ 25 26 '; 30 t ,• ~ 1 ~ ~-ea f.IP ~ ~ ' I ( ~P -78 I fdPU F-90 ... ~ l ~ , 11 AIPU -21P -. ~ AIPU zs 5,1~, ~ PU F-9 + I f) f t,IPy~F-'l AIPUF i ~ , ~ ~~O O -' ~1 +~ 1 J ~'/~~~~• ~~~/Y~ ~~~I.~L._. ~t'~ ~ AI -45 , Z o +~' r ~ w MPU F- O ' ~~~ ~ l ~r I / /// ~// ~ N - ~, ~~ AIPV ~18 Iytt ~1 ,~ ,~ 6~ I +,IPU S•1 !j / ( „n~, ~ : ~ ~ 11 ~ ( ' ~ z -----~-- --- - `. ~,\ \ 'i C ,. ~ r,lq F _~'3 _`.,j / ~1~ II ~Y~- -_ IaP~ F32 ~~ ~ 35 PU 2 PU ~`~ I7~ V •~i, 1 ~ ~ A ~ ;'i J JJ % • ~ ~., ~~~ ` U f1 MIP'U`F$9 ~\ ~ ~4 _ ~o o f k AIPU F- ~~ ~ '~ I ' ~ Area of Review ~ \ 3 IPU ~ 3 '!~~' PU F~ 4 ~.~ l1 ~.. ( ~l • ,. , . ~,, '1 7 0 1 f I ,u_,, , q •, • ~ r u g - I ~. i • , • ~Alw~ c a ~ ~ AIPUF..~ti •I~PtIF_~UF~ ~RU.~b7•~, 'yti5 ~p f,l I ~ ,~'~4~ ~ __~ AIPV~..~. } ',,. \. \ r~a~~' ~ .' j,IrU I.-~„ Amu1 -19 ~~ ~ AIPU F 4 -u ,~r ~~~ ,- ~~' ,. 1 ;~~~ ~~ 13N '1~10E UM `~, AI~PP04A ° ~ ~ j i f), 1 ~ ~- -- ~ ---- _ ~ PUFF 77 ~ ~' ._~~ _ ~ I ,>, • . ~/ 0 1,000 2,000 3,000 4,000 ~~r~. ~~ ~, ,; 530,000 - 49;000. ~ I; ,IP I ~ 550,000 9 MPU F-89 Proposed Injector Kuparuk "A" Sand 2050900 Confidential wells are red SFD 6/0712005 89-611252 ~ 2g SONDRA D STEWMANNC ~~Mas~tercard Check" _ ._~~~ $P EXPLORATION AK DATE p0' BOX .196612 MB 7-5 ANCHORAGE, AK 99519-6612 $ ~~~` ~.., ~ C ~~ ~- pOLLARS PAY TO THE y ORDER OF ~ e J ~`(~~1~ "------""""'~ _ ~'~ -x First National B Alaska Anchorage, AK 99501 ~, ~-~ m ~~ MEMO 5 200060:99 i4~.~6 2 27~~~ L564u• O L 2q ~: L 2 • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /~ ~~~ ~ ~~ PTD# l~~r~~~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (ply records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 -Well Name: MILNE PT UNIT KR F-89 __ Program SER WeII bore seg ^ PTD#:205D9D0 Company BP EXPLORATION~ALASKA) INC Initial ClasslType SER 1 PEND _GeoArea 890 Unit 11328 OnlOff Shore On Annular Disposal ^ Administration 1 Permh-fee attached____________________________________ ___ Yes_ -- 2 Lease number appropriate- - Yes Surface location in ADL 025509, top-prod interval-&_TD in ADL 355017._ _ _ _ _ _ _ - - - _ 3 Unique well-name and number_____________________________ __--_--_Yes_ __.--__--_- -------------------------------------------------------------- 4 Well located in_a defined_pool. - - - . - - - - _ - Yes Kuparuk River Oil_ Pool, governed b Conservation Order No. 4320 _ _ - Y- ---------------------- 5 Well located proper distance from drilling unit_boundary_ Yes Conservation Order No. 4320 contains no spacing reskrictions with respect to drillin unit boundaries. - - - - - 9 6 Well located proper distance from other wells- - _ - - - - - Yes - - - - - . Conservation Order No. 4320 has no intenxell_spacing_restriction_s, 7 Sufficient acreage available in-drilling unit- . Yes - Conservation Order No. 4320 has no in_terwell_spacing_restrictions, Wellbo[e will be_more than 50Q from - - _ - _ _ 8 If deviated, is-wellbore platincluded - _ - - - _ _ Yes - . . - an_ external property line_where.gwnership or_landownersh~ changes. _ - - _ _ - ------------------- 9 Operator only affected parfy_____--___-________- _--_____-Yes_ -_____ - - - 10 Operator has appropriate-bondinforce______________-________ __-___..-Yes_ ________-_______._.__________._..____-- 11 Permit-can be issued withoutconservatienorder_-__________-___-- -_-___Yes_ __________________ --------------------------------------------------- Appr Date ' 12 Permitcanbeissuedwithoutadminist[ative_appr-oval---___________ _________Yes_ ________-_--______-__--__--__--_- -_-._ - - SFD 6/7/2005 13 Can permit be approved before 15-day wait Yes 14 WeII located within area and strata authorized by Injection Order # (put_1O# in-comments)-(For- Yes - . - .. -Area Injection Order No._ 106_ - - . - _ 15 All wells within 114_mile area of review identifed (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - . _ _ - - MPIJ F,41, L-25, F=65,-F-66, F-66A,-F-74, F-17,-F-61- . _ - - _ _ _ _ _ _ . _ _ , , _ -------------------- 16 Pre-produced injector; duration of preproduction less than-3 months_(Forseruice well only) _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ -- - 17 ACMP_Finding of Consistency-has been issued_for_this pr_oject_ _ - _ - _ - - _ _ NA_ -- Engineering 18 Conductor string-provided_____ __________________________ _________Yes _____ - - 19 Surface casing_p_rotectsoll known lJ$DWs - - - - - - - - - - - - - - - - - - - - Yes Surface casing will be cemented below Schrader Bluff.- Any_shallowQrzones_will be_isolated. - 20 CMT_vol_adequate_tocirculate-on conductor_&surf_csg______________ ________Yes_ __-__--________-__-.___ ______-- - - 21 CMT-vot adequate_to tie-in long string tosurf csg- No- _ N4 hydrocarbon- zones- known in this hole section.- - _ _ _ _ - - 22 CMT_willcoyerallknown-productiyehorizons_____________________ _________Yes_ __--_-Line_rplannedto be.cemented.____---_-______ - - 23 Casingdesynsadequatefo[C,T,B&_permafrost__________________ ____-___Yes _--__________--____________--______ -- 24 Adequate tan_kage_o_r reserve pit - - - - . _ Yes - Rig is-equipped with steel_pits. _ No reserve-pitplanned, All waste to-approved disposalwells._ _ - - _ _ 25 If_a_re-drill,has-a-10-403 for abandonment been approved______-_ -___-NA__ ____________________________________ 26 Adequate wellbore separation-proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ ____ __ _ _ _ _ _ _ Proximity analysis performed, Traveling cylinder path calculated, Close approached identifed._ Gyros planne4l _ _ 27 If_diverterrequired, does jt meet regulations- NA_ _ - - _ - _ BP has_applied far diverterwaiver.- No shallow problems have been reported- at F-pad.- Waiver-recommended.- Appr Date 28 Drilling fluid program schematic 8 equip list adequate- - . - - . - _ Yes Maximum a ected formation pressure 7.8-EMW._ MW up to 9,3- tanned. - ~~ xp- p - TE 6113/2005 29 _B_OPEs,-do they meet regulation_____---_-__________________ __ ____ Yes_ -_______-_--__-______--__--__--___---,- -__-- 30 BOPE_press rating appropriate; test to_(put psig in comments)- - _ Yes - - - - - - MA$P calculatedat 2230 psi. Planned-BOP test 3000_psi. - _ - _ _ _ . - - ---- --------- lt'~ 31 _C_hake-manifoldcomp_liesw/APtRP-53(_May84)_-_-.-__- Yes_ _____________________________________ - - 32 Work will occur without operation shutdo_wn_______________________ ________Yes_ ___---________________ --_. -- 33 Is presence_of H2S gas probable- - - - - - - - - - - - - - - - - - Yes Minor_H2S_reported at F_pad._ Mud should preclude H2S- on-rig, Rig_has sensors and alarms.- _ - _ _ 34 Mechanical condition of wells within AOR verified (For_service well only) _ _ _ _ _ Yes - - MPF-61 only penetration in AOR. Cementing operation successful. _ _ Geology 35 Permit_ean be issued w!o hydrogen_sulfide measures - - - - . - - - - No_ H2$ has been-measured in_quantities_exceeding 20 ppm from MPIJ F-Pad_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 Data_presented on_ potential overpressure zones Yes _ - ..Expected pressure is 8.35 ppg EMW to_Kup47.85_in Kup; will be drilled with 8.8 r 9.3,Oppg mud. Maybe _ _ . - Appr Date ' 37 Seismic analysisofshallow gas_zones_ - _ _ - NA_ - - _ overpressured in Kup D._ More than 50 wells_have been drilled from the-MPU F-Pad without encounte[ing- - SFD 61712005 38 Seabed condition survey.(ifoff-shore) _ NA- hydrates or shallow gas. 39 Contact namelphone forweekly progress-reports [exploratory only/ _ - _ NA_ Geologic Engineering P c Commissioner: Date: Date Commissioner: C r Date ~;~ ~ ~ ~ 3l~ ,~~, ~-~~,s 6, ~ .~" C~ Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding inforration, 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 $ Thu Oct 20 09:36:58 2005 Reel Header Service name .............LISTPE Date .....................05/10/20 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name:.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................05/10/20 Origin ...................ST5 Tape Name ................UNKNOWN Continuation Numbe~r......01 Previous Tape Name;. ......UNKNOWN Comments .................STS LIS Writing Library • ~ 333 ~. ~,oa -~~lo Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: MPF-89 API NUMBER: 500292326800 OPERATOR: B.P. Exploration (Alaska), Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 20-OCT-05 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003856242 MW0003856242 MW0003856242 LOGGING ENGINEER: R. FRENCH R. FRENCH R. FRENCH OPERATOR WITNESS: E. VAUGHN E. VAUGHN E. VAUGHN MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0003856242 MW0003856242 LOGGING ENGINEER: C. ZAWADZKI J. BOBBITT OPERATOR WITNESS: D. GREEN D. GREEN SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 2162 FEL: 2888 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 33.68 GROUND LEVEL: 11.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) 1ST STRING 13.500 2ND STRING 9.875 3RD STRING 6.750 PRODUCTION STRING 4.750 REMARKS: SIZE (IN) DEPTH (FT) 20.000 106.0 10.750 6723.0 7.625 11186.0 5.500 11526.0 • 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 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 3 & 4 INCLUDED DGR AND PRESSURE WHILE DRILLING (PWD) RUN 3 ADDITIONALLY INCLUDED GEOPILOT ROTARY- STEERABLE BHA (GP) RUN 5 INCLUDED DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THERE IS A 4' +/- GAP IN EWR4 DATA BETWEEN RUNS 4 AND 5, DUE TO A DEPTH ADJUSTMENT. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPF-89 ON 8 OCTOBER 2005. THESE PDC DATA WERE PROVIDED TO SDS BY D.DORTCH (SAIC/BP) ON 14 OCTOBER 2005, AS AUTHORIZED BY MIKIE WEEKS (BP GEOSCIENTIST) LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 1 - 5 REPRESENT WELL MPF-89 WITH API#: 50-029-23268-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11795'MD/7424'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. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record • FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD, Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 61.5 11718.5 ROP 99.5 11773.5 FET 6683.5 11733.0 RPD 6683.5 11733.0 RPM 6683.5 11733.0 RPS 6683.5 11733.0 RPX 6683.5 11733.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 1.5 10955.0 10963.5 10995.0 11001.5 11014.5 11036.5 11061.5 11148.5 11169.0 11189.5 11210.5 11220.5 11230.5 11236.5 11307.5 11331.0 11338.5 11353.5 11381.0 11385.0 11407.0 11419.5 11437.0 11448.5 11488.0 11507.5 11512.5 11519.0 11535.5 11547.5 11553.5 11558.5 11562.0 11579.0 11580.5 11584.0 11588.5 11593.5 11603.5 11612.0 11618.5 11627,5 11638.5 11647,0 11653.0 11660.0 70.5 10964.0 10971.5 11005.5 11011.5 11022.0 11045.0 11071.0 11169.0 11191.0 11212.0 11232.0 11240.5 11252.0 11257.5 11329.5 11353.0 11362.0 11379.0 11406.0 11410.5 11429.0 11443.0 11459.5 11472.5 11511.5 11531.5 11536.5 11541.0 11557.0 11569.5 11576.0 11579.5 11585.5 11601.5 11604.0 11608.0 11612.0 11616.5 11627.5 11635.0 11640.5 11650.0 11662.0 11671.0 11674.0 11681.5 11666.0 11676.5 11773.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD 11688.0 11698.5 11795.0 BIT RUN NO MERGE TOP 1 70.5 2 4462.0 3 6735.0 4 11195.0 5 11528.0 REMARKS: MERGED MAIN PASS. MERGE BASE 4462.0 6735.0 11195.0 11528.0 11795.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value....... .............-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD OHMM 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 61.5 11773.5 5917.5 23425 61.5 11773.5 ROP MWD FT/H 0.09 2237.08 184.522 23349 99.5 11773.5 GR MWD OHMM 22.08 168.4 82.0804 23315 61.5 11718.5 RPX MWD OHMM 0.32 1925.47 6.41761 10091 6683.5 11733 RPS MWD OHMM 0.12 2000 9.1597 10091 6683.5 11733 RPM MWD OHMM 0.14 2000 13.8697 10091 6683.5 11733 RPD MWD OHMM 0.26 2000 29.8338 10091 6683.5 11733 FET MWD HOUR 0.16 90.52 3.12224 10091 6683.5 11733 First Reading For Entire File..........61.5 Last Reading For Entire File...........11773.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 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.......05j10j20 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 70.5 4418.5 ROP 108.5 4462.0 LOG HEADER DATA DATE LOGGED: O1-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4462.0 TOP LOG INTERVAL (FT) 70.5 BOTTOM LOG INTERVAL (FT) 4462.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 51.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 106.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 83.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3) 10.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 71.6 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 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 4462 2266.25 8784 70.5 4462 ROP MWDO10 FT/H 13.46 2237.08 212.405 8708 108.5 4462 GR MWDO10 API 22.08 118.08 65.2035 8697 70.5 4418.5 First Reading For Entire File..........70.5 Last Reading For Entire File...........4462 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 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.......05/10/20 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 GR 4419.0 6691.5 ROP 4462.5 6735.0 • LOG HEADER DATA DATE LOGGED: 02-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6735.0 TOP LOG INTERVAL (FT) 4462.0 BOTTOM LOG INTERVAL (FT) 6735.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.4 MAXIMUM ANGLE: 68.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TXPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 13.500 DRILLER'S CASING DEPTH (FT) 106.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 92.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3) 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 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 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 • r First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4419 6735 5577 4633 4419 6735 ROP MWD020 FT/H 0.09 398.21 145.969 4546 4462.5 6735 GR MWD020 API 31.58 127.02 83.4834 4546 4419 6691.5 First Reading For Entire File..........4419 Last Reading For Entire File...........6735 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 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.......05/10/20 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 GR 6692.0 11157.5 RPS 6692.5 11150.0 FET 6692.5 11150.0 RPD 6692.5 11150.0 RPX 6692.5 11150.0 RPM 6692.5 11150.0 ROP 6735.5 11195.0 LOG HEADER DATA DATE LOGGED: 09-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11195.0 TOP LOG INTERVAL (FT) 6735.0 BOTTOM LOG INTERVAL (FT) 11195.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 19.5 MAXIMUM ANGLE: 69.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 56933 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN}: 9.875 DRILLER'S CASING DEPTH (FT) 6723.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S) 57.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.400 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.290 143.6 MUD FILTRATE AT MT: 4.000 74.0 MUD CAKE AT MT: 2.200 74.0 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 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6692 11195 8943.5 9007 6692 11195 ROP MWD030 FT/H 0.2 361.88 194.242 8920 6735.5 11195 GR MWD030 API 45.86 137.61 94.0497 8932 6692 11157.5 RPX MWD030 OHMM 1.45 1797.04 5.67226 8916 6692.5 11150 RPS MWD030 OHMM 1.47 1441.48 5.3106 8916 6692.5 11150 RPM MWD030 OHMM 1.45 1439.82 4.05617 8916 6692.5 11150 RPD MWD030 OHMM 1.49 2000 13.1946 8916 6692.5 11150 FET MWD030 HOUR 0.16 90.52 1.55949 8916 6692.5 11150 First Reading For Entire File..........6692 Last Reading For Entire File...........11195 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 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.......05/10/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 11150.5 11488.0 RPS 11150.5 11488.0 RPM 11150.5 11488.0 FET 11150.5 11488.0 RPD 11150.5 11488.0 GR 11158.0 11481.0 ROP 11195.5 11528.0 LOG HEADER DATA DATE LOGGED: 13-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11528.0 TOP LOG INTERVAL (FT) 11195.0 BOTTOM LOG INTERVAL (FT) 11528.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 12.5 MAXIMUM ANGLE: 19.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73764 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 11186.0 • BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Lignosulfanate 9.90 65.0 9.0 20000 4.0 .270 70.0 .160 125.0 .180 70.0 .360 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11150.5 11528 11339.3 756 11150.5 11528 ROP MWD040 FT/H 0.24 8 63.25 50.3626 666 11195.5 11528 GR MWD040 API 54.39 168.4 131.117 647 11158 11481 RPX MWD040 OHMM 0.32 17 88.73 10.4377 676 11150.5 11488 RPS MWD040 OHMM 0.37 15 84.28 9.42259 676 11150.5 11488 RPM MWD040 OHMM 0.28 2000 78.8804 676 11150.5 11488 RPD MWD040 OHMM 0.91 2000 102.035 676 11150.5 11488 FET MWD040 HOUR 1.01 78.84 14.0044 676 11150.5 11488 First Reading For Entire File..........11150.5 Last Reading For Entire File...........11528 File Trailer Service name .............STSLIB.005 Service Sub Level Name... • Version Number...........1.0.0 Date of Generation.......05/10/20 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.......05/10/20 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 GR 11481.5 11740.5 RPD 11492.5 11754.5 RPM 11492.5 11754.5 RPS 11492.5 11754.5 RPX 11492.5 11754.5 FET 11492.5 11754.5 ROP 11528.5 11795.0 LOG HEADER DATA DATE LOGGED: 17-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11795.0 TOP LOG INTERVAL (FT) 11528.0 BOTTOM LOG INTERVAL (FT) 11795.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 13.8 MAXIMUM ANGLE: 15.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 EWR4 ELECTROMAG. RESIS. 4 171169 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.750 DRILLER'S CASING DEPTH (FT) 11526.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S) 61.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 13000 • FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) .330 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .200 116.0 MUD FILTRATE AT MT: .280 68.0 MUD CAKE AT MT: .670 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 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .1IN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Cha nnel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Ns am Reading Reading DEPT FT 11481.5 11795 11638.3 628 11481.5 11795 ROP MWD050 FT/H 5.27 158.87 63.798 534 11528.5 11795 GR MWD050 API 40.55 123.41 86.8025 517 11481.5 11740.5 RPX MWD050 OHMM 0.38 1925.47 13.7991 525 11492.5 11754.5 RPS MWD050 OHMM 0.12 2000 75.3208 525 11492.5 11754.5 RPM MWD050 OHMM 0.14 2000 110.953 525 11492.5 11754.5 RPD MWD050 OHMM 0.26 2000 230.193 525 11492.5 11754.5 FET MWD050 HOUR 0.32 85.85 16.4838 525 11492.5 11754.5 First Reading For Entire File..........11481.5 Last Reading For Entire File...........11795 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/10/20 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 • Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/10/20 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................05/10/20 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File