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Home My WebLink About205-125Image 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. a,~~- ~~~ Well History File Identifier Organizing (aone> RE CAN Color Items: ^ Greyscale Items: o,.o,aaa iuuiuiiiimuu DIGITAL DATA Diskettes, No. ^ Other, No/Type: „Ae=~a~~eede, iiuiuiuiuiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria) Date: ~,,~ ~ ~ (, ~ /s/ I ~ r ~~ Project Proofing II I II ~~ II ~ (III I I III BY: Maria Date: O /s/ Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES ^ (Count does not include cover sheet) BY: Maria Date: tJ ~ /s/ ~ Production Scanning III IIIIII IIII II III Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation : ~ YES NO BY: Maria Date: ~, , ~ C.J ~ /s/ Y ~/I 1-' YI Stage 1 If NO in stage 1, pages} 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 ReScanned II I II IIII (IIII (IIII BY: Maria Date: /s/ Comments about this file: Quality Checked I II I III II II I III III ) 10/6/2005 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 5LANNED FEB 2 4 nIZ December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission a OS-- 333 West 7 Avenue Anchorage, Alaska 99501 V I Fs — Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, K.7 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10.404) MPS -Pad 10/112011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ I Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/302011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 -'"---> MPS-10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS-15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7292011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS -20 2022410 , 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS-41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS MAY -~ ~ 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Af1~1PATCH Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 205-1250 3. Address: P.O. Box 196612 Stratigraphic^ Service 0 6. API Numbed Anchorage, AK 99519-6612 50-029-23152-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-380110 ~ MPS-10A 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8915 feet Plugs (measured) 6047' 3/4/10 feet true vertical 4201.12 feet Junk (measured) None feet Effective Depth measured 8828 feet Packer (measured) 5620 6085 true vertical 4209.04 feet (true vertical) 4113 4207 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 211.5# A-53 32 - 112 32 - 112 Surface 2745 9-5/8" 40# L-80 31 - 2776 31 - 2475 5750 3090 Intermediate Production 6195 7" 26# L-80 30 - 6225 30 - 4210 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 - 8915 4207 - 4201 8430 7500 Liner Perforation depth: Measured depth: 5730 - 5830 6850 - 7350 8250 - 8550 True Vertical depth: 4146.37 - 4170.71 4199.07 - 4189.89 4209.02 - 4220.1 Tubing: (size, grade, measured and true vertical depth) 2-3/8" 4.7# L-80 30 - 6073 30 - 4207 Packers and SSSV (type, measured and true vertical depth) 2-3/8" Baker GT Dual Packer 5620 4113 5" Baker ZXP Top Packer 6085 4207 12. Stimulation or cement squeeze summary: Intervals treated (measured): r ~ t= ~ '~~ ~ l ~ ~,~ ~ ~ t n , .,~ ~ ~ ~ 1~,9 Treatment descriptions including volumes used and final pressur ,».~~ e: :~~.p es 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: 943 950 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X 6. Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ Q 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: 310-054 Contact Gary Preble Printed Name Gary Prebl Title Data Manager Signature Phone 564-4944 Date 5/12/2010 vine iv-•+v+ r~cviac~a nwva ~~~M~ pUil 1 1V iY~~/) - V4UIIIII V111~111U1 iuy u MPS-l0A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY j 3/2/2010 E CTU #9 w/1.5" OD CT. Job scope -Fish patch, set IBP. «< Interact j publishing »>. POOH w/"G" spear assy. Cut 100' pipe. MU Wthf BHA #2. RIH. Pulled patch free. POOH. LD fish. RBIH w/ Wfd PRT and pull dower ER packer @ 5952' CTM, EOP flag @ 5938' corr. CTM. POH. LD Wfd. MU Baker BHA and 1-11/16" IBP (OAL 16.3'). RIH and set ' IBP at 6600'. Had 4k lbs overpull when pulling off bottom. POOH. .Setting tools looked normal. MU 1.5" JSN assy. RIH. Continued on WSR 03/03/2010. I 3/3/2010; CTU #9 w/1.5" OD CT. Job scope -Establish injection rate. RDMO. ~~~ «< Interact publishing »> Continued from WSR 03/02/2010. RIH to end of tubing and establish injection rate down backside. Inj rate 1 bpm @ 272 psi. Initial rate was 1 bpm @ 210 psi. POOH. MU Mem STP to see if the IBP has a good set. Perform stop counts from 5700' down to ;6550' down and up and POOH. OOH log data shows flow going past =~IBP. Call APE to discuss plan forward. Decided to pull IBP. RIH and tagged up at 6,056', could not get past obstruction. POOH to check tools. Continued on WSR 03/04/2010 3/4/10CTU #9 w/1.5" OD CT. Job scope -Pull IBP, set IBP. «< Interact =nublishin~ »> Continued from WSR 03/03/2010. POOH wBaker IBP 'retrieving tool string. Inspect tools, found marks on bottom of overshot. Filed bevel on overshot and straightened coil. RBIH. Tagged up at 6,056'. Could not work tool past tight spot. POOH. MU 1.74" od JSN 'assy. RIH and saw a light tag at depth & popped through. Made a few 'passes and they were clean. RIH to 6550' and back to 6000' clean. Call CT Schedular to discuss plan forward and we are going to POOH for a 'smaller OD SL overshot. Not able to find a housing for the grapple. MU 'original fishing BHA and RIH. Tagged at same depth, swapped to XS KCL and pumped at max rate and made it past. RIH to IBP set depth and 'nothing was there, continued in hole and dry tagged at 7497. PUH and pumped to activate centralizer and tried another dry tag then POOH. At surface we did not retrieve the IBP, plan forward is to perform and infectivity test with diesel, set an XN Plug and perform another 'infectivity test to compare rates. 'Injection rate down production tbg w/diesel - 3 bpm 300 psi, 37 bbls 'pumped. Dropped 1.875" od (packing) "XXN" plug w/no keys, from surface, chased to "XN" nipple. Tagged "XXN" @ 6047 ctm. Set down 4k lbs x 2. POOH. Perform inj test @ 3 bpm @ 1220 psi. RDMO. Job 'complete. FLUIDS PUMPED • BBLS 372 60/40 METH 142 XS KCL 65 DIESEL 579 Total _, Tree: CIW 2 1/16" SM Dual string M P U S 10a i Wellhead:11" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112` 9-5/8" 40 #/ft, L-80 BTC 2,776' 2,996' 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 300' Hole angle passes 50° @ 2775` Hole angle passes 70° @ 5600` Hole angle passes 8C~ @ 5950' 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,610' 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,630' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,643' Tubing tail / WLEG ~ Keyless XXN plug set in long string XN 3i4!10~~ 6,138' 7" Halliburton Float Collar PBTD 6,225' 7" Halliburton float shoe Perforation Summary Size Spf Interval (TVD) 3 3/8" 6 OA sands 5,730' - 5,830' OB d 4,146' - 4,170' 2 7/8" 6 san s 6,850' - 7,350' 4,199' - 4,189' 2 7/8" 6 8,250' - 8,550' 4,209' - 4,220' Guns : 3406PJ, HMX, 60 deg. phase 2906PJ, HMX, 60 deg, phase DATE REV. BY 06/22/02 MDO 06/11/03 MDO 10/20/05 MDO ~ Isolated /Trig. KB Elev. = 73.05 Orig. GL Elev. = 38.90 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,994' NOTE :Well sidetracked 10/20/05 Kick-off @ 2839' and NOTE: There is a tbg patch set at 5851'. ID through the patch is 0.877". There is a tbg patch set at 5938. ID through the patch is 0.868" 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,606' 7" x 2-3/8" Baker "GT" Ret dual kr 5 620' . p . , 1.945" ID. °oo Holes in the long string 5838' - 5960' 2-3/8" HES XN-Nipple (1.875" pkg. bore) 6,062' No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub 6,068' " (2.00 pkg. bore) No-Go Locator sub @ 6,082' 6 095' , 7" Tie Back Sleeve 7"x 5" HRD ZXP Liner pkr. 6,085` 7"x 5" HMC Liner Hng. 6,073' 1 11/16" Baker IBP (Failed to set 3/4/10) @ 7497'(?) ctmd (did everything move down the hole?) Top of CaC03 Sluggits dumped @ 7444' ctmd 1 11/16" Baker IBP (Set 6/13/09) @ 7500'ctmd 4.5" Baker Landing Collar g,g2g~ 4.5" HES Float Collar 8,870' 4.5" HES Float 8,915' COMMENTS Drilled by Cased Doyon 141 Completion Rig Doyon 14 Sidetrack & Completion Doyon - 14 BP EXPLORATION (AK) MILNE POINT UNIT WELL No.: S-10i API : 50-029-23152-01 f~~~ ~~ dl° PROAcrivE DiAgNOSric SemncES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical eta Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. ~ ~- Attn: Robert A. Richey (,J~ L' ~bS - ~ S 130 West International Airport Road Suite C ~~ ~ L(a I Anchorage, AK 99518 Fax: (907) 245-8952 1) Temperature /Spinner 03-Mar-10 MPU S-10A BL / EDE 50-029-23152-01 2) Signed : ~ Date : ' ! _ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL _--- --2";^ _ --- - WEBSITE _ _~~e C:`Documents and Setdna lt7ixne Wilfia[ns~Des6YOp\Trnnsmit_BP.doc~ • Mr. Chidi Igbokwe Production Engineer BP Exploration (Alaska) Inc P.O. Box 196612 Anchorage, Alaska 99519-6612 • d~ ~ ~ ~~ Re: Milne Point Field, Schrader Bluff Pool, MPS- l0A Sundry Number: 310-054 Dear Mr. Igbokwe: 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 Su has been requested. DATED this .~~day of February, 2010. Encl. „ D `O STATE OF ALASKA r~~,ti~. ,v~~ ALASK~L AND GAS CONSERVATION COMMISSI~ FEB 2 2 2010 .~' APPLICATION FOR SUNDRY APPROVALS Alaska Q~ & bas Cans. Commission 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^ Chan rogram ^ Suspend ^ Plug Pertorations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Well ^ Stimulate^ Alter Casing ^ Operation Shutdown ^ Re-enter Susp . SET PLUG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-1250 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23152-01-00 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 ^ MPS-10A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-380110 MILNE POINT Field / SCHRADER BLUF 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): 8915 4201.12 8828 4209.04 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 211.5# A53 32 112 32 112 Surface 2745 9-5/8" 40# L-80 31 2776 27 2475 5750 3090 Intermediate Production 6195 7" 26# L-80 30 6225 30 4210 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 8915 4207 4201 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5730 - 5830 4146.37 - 4170.71 2-3/8" 4.7# L-80 30 6073 6850 - 7350 4199.07 - 4189.89 8250 - 8550 4209.02 - 4220.1 Packers and SSSV Tvoe: 2-3/8" Baker GT Dual Packer Packers and SSSV MD and TVD (ft): 5620 4113 5" Baker ZXP Top Packer 6085 4207 ,t 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: y Detailed Operations Program ^ BOP Sketch ^ yy Exploratory ^ Development ^ Service ^~ 14. Estimated Date for it 15. Well Status after proposed work: Z /O Commencing Operations: Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: Z.t$•!o WINJ ~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: S~w f .` GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing ' true and correct to the best of my knowledge. Contact Chidi Igbokwe Printed Name Chidi Igbokwe Title P E Signature Phone Date. ~ 564-4795 2/22/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY witness Sundry Number: ~/V -~ ~~ roval: Notif Commission so that a re resentative ma Conditions of a y y pp p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: i /~' `~° `~ Subsequent Form Requ red: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: RBDMS FEB 2 5 2010 R 1 G I ~l A L Z.Z3.lo ~~~ ~. z-L• ,~ Form 10-403 Revised 12/2009 %Y" Submit in Du~l~ate I~ U by '~2i ~~~ Revision #2 r~~~~~~ To: M. 0' Malley/ N. Leonard MPU Well Operations Supervisor From: Chidiebere (Chidi) Igbokwe MPU Schrader Pad Engineer Subject MPS-10Ai (Long String) Patch PulllTTP Set (Requires 1.5" Coil) Type Desc. Comment • Memorandum Date: December 22, 2009 AFE: MSSPDWLIO-C Est. Cost: $ 80,000 IOR: 400 ~ ...Done 01 /04/2010 C Pull lower patch @ 5938' ctmd C Seta 1-11/16" IBP @ 6600' and (Long String), Verify IBP set with injectivity test on the long strip re & ost IBP set not exceedin WHIP of 1200 si Current Status: Injector Last Test: NA Max Deviation: 94 deg @ 6565' MD (70 deg @ 5636' MD) Min. ID: 0.868" @ 5838' slm (Weatherford patch) Last Downhole Ops: 12/21/2009: SL set WFD test tool for PT of tubing Latest Tag: 10/25/2009: E-line tag lower patch assembly @ 5891' Latest H2S level: < 2 ppm AMPS-10A is an October, 2005 rig sidetrack completed as a dual string (2-3/8") injector to support producers in the Schrader Bluff OA and OB sands of HU 15. On 7/12/2006 memory gauges run in both tubing strings (long string and short string) of this dual string injector validated communication between both strings. This necessitated a leak hunt that revealed leak points @ 5858', 5899' and 5950' and in the long string (below the upper completion packer @ 5620' md). Patches were set in the long string (LS) @ the following intervals 5838'- 5866' slm (10/20/09) and 5938' - 5960' ctmd (06/13/09) however, it appears some form of communication still exist between the two strings. MPS-10A also has a known MBE (which in its most severe case is characterised by WHIP going on vacuum corresponding with increased injectivity and bottom hole injection pressure equilibrating with producer FBHP) presumably in the OB sand (long string). An IBP set @ 7500' above the lower set of the OB perforation (6/7/09) ahead of patch set was not able to mitigate the MBE to the OB sands. Upon completion of patch set in the long string, the short string "only" was put on injection but went on vacuum shortly afterwards. The recent behaviour raises suspicion of communication to the lower OB sand via a leak points in the long sting and/or packer leak (lower liner packer). A recent MIT-T of the L.String PASSED, eliminating possible existence of a leak point above the upper patch. In order to regain injection in the short string, the patches in the L.String need to be pulled to progress a TTP set in this highly deviated LS. MPS-05 an 800 bopd well is shut-in awaiting support from S-10. For questions please call Chidi Igbokwe @ 564-4795 (V11) or (206-790-2449 (M) Gc: ' Well File • lsala9ed Tree: ~IVd 2 1?16" 5PA Cw~l stri€~q Wet=head: # ~"'r, ? _'.^a" Sfir1 F1~1~ dual str7t~g [-[an0er thread ~ ?. E' Eau E 1t~p and IBT t~tir 26" x 34° ins~laled~ 295I,~: S3 91~` 9-518" 46 L_86 BTC 2,776` Short Strirta ~eig. ~B Ei~~_ = 73.Q5 (=1rVJ. tai... EI~Y. = 38.JIQ 2x996` 2-315" F1E5 ?~C~1s1i le X1.875° pk~_ bore) K1~ P t~c~? 3l~£Y' k{O#~ 3f~{~9~ pc~SSeS 'cI' 2775` Hr31e i11~~ pe't~sSeS 7CF ~'j~' r~~ 1-~a1e ~itji~ pa1SSeS tbt~ .cC :sy5f1` 7" 26'R1, L-86, BT9~C C~sang ~dtih d = F 151, ~c ~ p.= .Q383 2-i,~,~.7#r`i L-"G.16T9ubir adrift id = 1.9171, ~ ~;: ~ _D ~ 387 5,616` ?-31'8" I.1E~S ~C-i~ippl~ ~i~$a5° C9- Ewe) 5,636` 2-316" 1iE5 X9~-~+lippie 81.875" pkg. bore; hl~a-Go i .7'~ 1" 5,643" Tubing tsii A 5h'LEia 8138° 7' 1131 i::~r#~rt F9oat C011ar PBT97 6f225` --~, ~ Burton Paalshoe Per#a~ atlon Summery size a~f lrrtervat (®~ t?A sands 3 3Y 6 5„73# - 5,$36' '' 4,'146° - 4,176' d3B sand 2 7t8" 6 6,856' - 7x356` 4,1'99` - 4,189' 2 718" 6 8.56` - 8x656' 4,269` - 4,220' duns 3-10€P3 HR~X, 66 cam. phase as~e~F~=. ~sro~, 66 ~, pt~ PATE RE~l. BY 06122?02 ~Ai7d7 vft 1 1;'03 1u91}O '0r2G,0~ Po1C10 2-318" 1iES ~4-1Vi1sple {1.875 pkg.. bore} 2,991` NOTE :tr5/r~li sidetracked 10/27/05 I~i~k-offi ~n> 2839- and ~{~~~: T^ere is a :1 y~ patch set a# `~51`. 1D ti`~rough the patch is 0 ~77'- There is a tlx7 paml-~ set tit S$3B`_ f€3 ttarr~uglt #h.e J3IGt1 iv t~i_b Cw~ 2-318•" t9ES ~C-hli~sple (9.875" pkg. b[~tej 5.,61}6' 7° x 2_3,"8:, baker "~T" B. dual pkr. 5,6~Q` 1.945°' 1La , Viteatherf~ra Fach's ;.G.3E_3°rrtirt {[3) `~~1 - 3~ 5~ S-n0.. 2-3!'6" I-1E5'r J ~ ~ ; le 1.875~Sfcs~~ b~cel E,06 f~to-Go 1.791° 318" Baker "E' H>dr~ Tri Su~~ " 6,063` pkcl- harts) X2.66 i~0-~.'iO ~6~3tC~f SU:? L'_l~,'. ~~~ft?'. Tie Back ~I~ Eve 6,6'95`- %'x 5" FtRC _x:P Lutist pkr. 6.685' 7°x 6~ ;-!1•.tti~ L"tn~ Ht~g_ 6"07~` 3fiR.f~ls. /t..~ n+..9 ~le~w ,~ Yza O,/~' s~'ND. Tip of ~Ct ~f ~s d~rtpe~i :~° 7~~i~#° 1 11P16" Baker 9BP (het 6,.13,03'1 ~ 7~,0~7 ~.`:: 6akar ~andi~~~ :al.alr ~ g^3, 4.5' HtS Fk~a1 ~5a tar $.870' 4.5° HES Float9 3~,fr 15' C(?M1@J1EhTB 11~ILNE PnIi+IT UNIT C: N led i:p Cased 17oyo~ t ~1 WELL NO.: 5-9411 Con:plefiion Rig Doyon 14 #"SsPI : 5Q-(129-2~'E-#~U Sidetrack & Corr~ple9ia~~ Coyan - 14 BP EX~L4?RATl471~i ~A~l y Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 23, 2010 2:26 PM To: 'Igbokwe, Chidiebere' Subject: RE: MPS-10 IBP Set Sundry Approval Chidi, I spoke with Commissioner Foerster and she gave verbal approval to go ahead with the procedure on MPS -10A. Guy Schwa-tz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) _ _ From: Igbokwe, Chidiebere [mailto:Chidiebere.Igbokwe@bp.com] Sent: Tuesday, February 23, 2010 2:23 PM To: Schwartz, Guy L (DOA) Subjects MPS-10 IBP Set Sundry Approval Guy, As discussed, can we get a verbal approval to commence the IBP set on MPS-10 injector pending when we recieved the signed copy of the approved 10-403. Thanks, Chidiebere (Chidi) Igbokwe by ACT-MPU Schrader B/E/C & L P~ 900 E.Benson blvd Anchorage,+1 (907)-564-4795 /Fax 564-~chidiebere.igbokwe@bp.com igboc0@bp.com 2/23/2010 STATE OF ALASKA ALAS LAND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ TUBING PATCH Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ 5851'-5891' Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 5938'-5960' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 205-1250 3. Address: P.O. Box 196612 Stratigraphic^ Service Q API Number: Anchorage, AK 99519-6612 50-029-23152-01-00 8. Property Designation (Lease Dumber) : 9. Well Name and Num ber: r'~/~ i ~ ADLO-380110 ~~ MPS-10A l ~~ C 10. Field/Pool(s): \ MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: ~I&~~ Total Depth measured 8915 feet Plugs (measured) 7500 6/13/09 feet ~~~~ true vertical 4201.12 feet Junk (measured) None feet Effective Depth measured 8828 feet Packer (measured) 5620 6085 true vertical 4209.04 feet (true vertical) 4113 4207 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 211.5# A53 32 - 112 32 - 112 Surface 2745 9-5/8"40# L-80 31 - 2776 31 - 2475 5750 3090 Intermediate Production 6195 7" 26# L-80 30 - 6225 30 - 4210 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 - 8915 4207 - 4201 8430 7500 Liner Perforation depth: Measured depth: 5730 - 5830 6850 - 7350 8250 - 8550 _ _ True Vertical depth: 4146.37 - 4170.71 4199.07 - 4189.89 4209.02 - 4220.1 _ _ Tubing: (size, grade, measured and true vertical depth) 2-3/8" 4.7# L-80 30 - 6073 30 - 4207 Packers and SSSV (type, measured and true vertical depth) 2-3/8" Baker GT Dual Packer 5620 4113 5" Baker ZXP Tog Packer 6085 4207 12. Stimulation or cement squeeze summary: Intervals treated (measured): ({y{ r Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 834 800 Subsequent to operation: 567 11 14. Attachments: .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: 309-186 Contact Chidi Igbokwe Printed Name Chidi Igb kwe Title P.E. Signature Phone 564-4795 Date 2/22/2010 Form 10-404 Revised 7/2009 RBDMS FEB 2 5 2010 ?.~/~ ,~„ ~_ ~ i ~ Submit Original Only MPS-10A 205-125 FLUIDS PUMPED BBLS 100.9 DIESEL 635 1 % KCL 16 50/50 METH 12.5 HEC GEL 5 RED DYE 51 60/40 METH 821.4 Total We1lServiceReport • WELL SERVICE REPORT Page 1 of 2 WELL JOB SCOPE UNIT MPS-1 O PACKERS/BRIDGE PLUGS (NRWO) CTU #s DATE DAILY WORK DAY SUPV 6/10/2009 PULL MECHANICAL PLUG; SET INFLATABLE BRIDGE IMM PLUG COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N DS-WAGONER SCARPELLA MIN ID DEPTH TTL SIZE 1.791 " 6062 FT 0 " CTU #9 w/1.5" CT Job Scope: Pult PXN, Drift, Set IBP, Log, Set Patch «<InterAct Publishing»> .....Continue from w5K on 6/09/09..... Finish RU. RIH w/ 2" JDC Pulling tool. Pulled prong and plug body from 6042 CTM. MU and RIH with 1.70" JSN wash liner from tubing tail down to 7600' with 1 % KCL at max pump rate. Recip three times 100' above and below planned setting depth of 7500' RIH w/1.69" IBP Serial #10159549 FN = 1.188" Push 200# down to equilize, pull 5520# to release ...Continue WSR on 6/11/2009.... 09/30/09: IBP MONTHLY RENTAL FOR 07/11/09 - 09/11/09. MOs 2 &3 (TL 12/23/09: IBP MONTHLY RENTAL FOR 09/11/09 - 12/11/09. MOS 4, 5, & 6 LOG ENTRIES Init Tb , IA, OA 933 0 21 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Continue from WSR on 6/9/09 00:10 0 .3 0 Flood lines 00:16 0 0 3511 .2 2 PT CTC and MHA 00:20 0 Put rest of tools on. 00:40 0 Stab on well. 01:00 0 .5 2 Flood lines 01:01 0 311 297 .5 5 LPT to 311 si 01:07 0 3992 3970 0 6 HPT to 3992 si 01:15 0 Stand b for o erator to o en SSV 01:28 0 933 779 O en swab valve 12-1/2 turns. 01:45 0 Rih w/ 1.70" x .29' CTC, 1.70 x 1.71' MHA (DCV & 9/16" Disco), 1.70" x .6' Circ Sub, 1.75" x 7.75' DA Jars, 1.69" x .58' X-over, 1.85" x 1.20' JDC Pullin Tool. OAL = 12.13' 01:55 0 941 Bleed well down because we can't snub in well due to new ackoffs 02:15 0 Set down on flan e. T several times to et b flan e. 02:20 0 337 1 6 Online with pump to see if we can get by flange above the swab valve. 02:32 0 89 15 Pum down backside to see ff we can et b flan e. 02:33 0 Cannot et b flan e. 02:35 0 23 21 m Swa to methanol. 02:38 0 0 27 Shut down um 02:41 0 Swab valve closed 12-1/2 turns 02:45 0 Po off well. 02:50 0 Reverse bend coil. 03:12 0 Stab back on well. 03:20 0 27k Flood lines 03:23 0 325 29 LPT to 325 si 03:28 0 30 HPT to 3965 si 03:34 132 O en swab valve 12-1/2 turns 03:36 123 Rih w/ 1.70" x .29' CTC, 1.70 x 1.71' MHA (DCV & 9/16" Disco), 1.70" x .6' Circ Sub, 1.75" x 7.75' DA Jars, 1.69" x .58' X-over, 1.85" x 1.20' JDC Pullin Tool. OAL = 12.13' 03:39 119 Set down on flan e. 03:42 116 30 Online with pump to see if we can get by flange above the swab valve. 03:44 0 35 Got b flan e. Continue RIH. Shut down um . 04:16 2900 101 wt ck = 7k riw = 1.5k 04:54 6020 159 wt ck = 12.4k riw = 2k 04:57 6042 167 Sat down. PUH 1.5k ove ull POOH. 05:50 0 85 OOH Close swab valve 12-1/2 turns 06:04 0 Pron and lu bod was recovered. 06:13 0 Secure well for PE Chan a out. http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=8125C4BB3F784B61... 2/22/2010 We1lServiceReport • • Page 2 of 2 17:22 0 Be in makin u 1.7" JSN BHA. 17:29 0 Zero tool strip . 17:50 0 580 430 0 PT low 17:57 0 4000 4000 7.5kc1 PT Hi h 18:08 0 RIH with 1.70" x 0.29' CTC, 1.70" x 1.71' MHA (Dual checks and Hyd. Disconn 9/16" Ball), 1.70" x 0.60' Circ Sub with 5k rupture disc, 1.5" x 0.33' XO, 1.5" x 5.8' Stinger, 1.5" x 5.8' Stinger, 0.71' x 1.70" JSN. OAL = 15.24' 19:26 6000 874 0 Wt ck 13k, riw 2k 19:29 6080 875 0 Ran through xn nipple with no problems. 1.70" JSN/1.791" no-go in xn ni le 19:36 6100 892 3343 2.1 Ok Line up down CT w. 1 % KCL and start washing liner down to 7600' at max rate 19:58 7600 1185 3546 2.1 64 At target depth 100' below setting depth of IBP, PUH focusing on 200' area of liner 100'/100' 20:11 7400 1152 3601 2.1 91 At to of to eted area reci back down for second ass washin 20:16 7600 1267 3513 2.1 102 At bottom reci back u 20:45 7400 1234 450 157 POOH w. um s off 21:20 0 621 0 BHA surface close swab valve 12.5 turns 21:32 0 In'ectoroff well, brake down BHA & drift MHA w. 1/2" ball 21:57 0 165 Fill CT and ressure test MHA to 3500 si 22:11 0 MU settin tool and 1 11/16" IBP 22:23 0 165 Pressure test surface a ui ment u backside of CT 22:25 0 LPT 263 si 22:32 0 HPT 2000 si 22:42 0 166 RIH w. IBP Serial #10159549 FN = 1.188" Push 200# down to e uilize ull 5520# to release 23:50 6000 635 0 Wt ck 13k, riw 2k 23:59 6400 Continue WSR on 6/11/2009 Final T IA, OA 203 bbls of 1 %KCL 6 bbls of 50/50 methanol Performed daily inspection of tanks and secondary containment Visually inspected space between outer and inner hauls on return tank #93092 http://apps2-alaska.bpweb.bp.corn/awgrs-wellservicereport/default. aspx?id=8125C4BB3F784B61... 2/22/2010 WellServiceReport • • Page 1 of 3 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-1 O PACKERS/BRIDGE PLUGS (NRWO) CTU #s DATE DAILY WORK DAY SUPV SET INFLATABLE BRIDGE PLUG; INJECTIVITY TEST; 6/11/2009 JEWELRY LOG-DEPTH CONTROL; PATCH TUBING / DISBROW CASING COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N DS-WAGONER SCARPELLA MIN iD DEPTH TTL SIZE 1.791 " 6062 FT 0 " CTU #9 w/1.5" CT Job Scope: Set IBP, Log, Set tubing patch «<Inter ct u is mg»> ... on roue m on ... Pump ball down to inflation valve on BOT IBP setting tool and wait 2 1/2 hours for fluid temp to stabilize. Continue inflation process per BOT recommendations. Running tool disconnect sheared @ 1100 psi, 500 psi overbalanced with KCL in coil, stack down 1k and picked up clean from IBP leaving top of IBP @ 7500' (Element @ 7505') MU and RIH with couple stingers, 1.5" BDN. Lay in sluggits on top of IBP. Top of sluggits at 7444' ctmd. POOH and perform 150 Bbl infectivity test. Pumped 1, 2, and 3 BPM down long string, well on vac after test. MU and RIH with PDS memory GR/CCL. Begin logging up at 6050' ctmd. Flag pipe. Log to 5500' ctmd. POOH with logging tools, download data. No correction needed. MU and RIH with WFD ER lower packer for patch. Stop at flag on coil and correct depth to element on ER lower packer. Run past setting death and nick up to 5960' corrected depth. Drop 3/8" ball into reel to set lower packer ...Continue WSR on ...6/12/2009... LOG EN TRIES Init Tb , IA, OA 788 0 55 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:00 0 Continue WSR from 6/10/2009 00:01 6000 868 0 Wt ck 12.2k riw 2.2k 00:30 7530 845 PUH to ood launchin sition on CT reel 00:31 7527 845 Sto , PJSM 00:38 7527 845 Load 1/2" steel ball into reel 00:40 7527 842 2000 Ok Stall um and launch ball into stria 00:42 7527 841 473 .8 1 PUH to set de th for IBP wt 12.2k 00:43 7508 851 808 1.1 2 Stopped at setting depth, increase pump rate to get ball over ooseneck. To of IBP 7500', center of element 7505' 00:48 7508 957 883 1.1 7 Cau ht fluid in coil, tem of 1 %KCL bein um is 82 d . F 00:57 7508 993 871 1.1 15.1 Ball heard oin over ooseneck 00:59 7508 970 122 .3 19 Reduce rate to min 01:17 7508 834 289 24.3 Ball on seat shut down pump and wait 2 hours. Fluids pumped were at 84 de . F BHT around 80 de . F from ast SIBHPS 03:52 7508 811 64 24.3 Continue inflation of IBP rollin um at min rate 03:54 7508 811 342 24.3 Sto um and hold for 5 min 03:59 7508 811 645 24.3 Increase ressure in IBP and hold for 5 min 04:04 7508 811 1100 24.4 Running tool disconnect sheared, stack down 1 k (original riw was 2.2k 04:07 7498 811 0 24.4 Looks ood, PUH 10' and aint fla EOP 7483' 05:07 0 408 BHA surface, close swab valve 12.5 turns 05:18 0 Brake down BHA and recovered 1/2" steel ball 05:23 0 MU assembly for dumping of sluggets. 1.7" x .29' dimple connector, 1.5" x .25' x-over, two 1.5" x 5.83' stingers, 1.5" x 8.5" BDN w/.6" hole OAL=13' 05:36 0 24.4 Flood surface ui meat for testin 05:40 0 30 LPT 244 si 06:00 0 32" HPT 3988 si 06:10 0 760 35 O en swab 12.5 turns and RIH 07:16 3960 740 37 PU WT = 9.5k, Dwn Wt = 1.5k 08:04 7496 797 54 Reach fla ,mechanical at 7495'. 08:06 7490 797 75 PU six feet to ut nozzle at 10' above IBP. 08:14 7490 790 50 Cementers on location. Ri u van to standin iron. 08:29 7490 787 1036 1.3 0 Pum down coil to test in'ectivi - flood s stem 08:41 7490 810 760 1.0 13.5 Establish infectivity, continue pumping. Circ pressure varying from 690 to 780 si 08:45 7490 810 87 0 18kc1 Off um s 09:34 7490 795 932 1.2 0 Switch over standing iron from coil to Cementers. Cementers flood s stem 09:39 7490 794 102 0 2wtr Cementers are down on um http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=C750923DB69B44C7... 2/22/2010 We1lServiceReport • • Page 2 of 3 09:42 7490 793 96 0 Cementers PT to 4000 si 09:44 7490 793 1463 1.5 0 Pum lead el 09:46 7490 799 77 0 3 el Com lete um in lead. 09:49 7490 787 71 1.0 0 Batch up 4 bags CaC03, begin pumping. Cement van engines shut down. Trouble shoot. 09:50 7490 787 0 1.5s1u Continue troubleshootin cement van en fines - not startin . 10:31 7490 Pre are to swa out trucks. 11:06 7490 Cement van from Kuparuk arrives. Transfer dirty slurry and gel from broken down van to re lacement van. 11:31 7940 Cannot et Ku aruk unit to start. Troubleshoot. 11:56 7940 Unit started. Pre are to um slu it slur 12:27 7940 811 1415 1.0 0 Pump sluggit slung. Density of sluggit slurry reading 8.9 Ib/gal on the coil MM. 12:28 7940 811 1475 1.1 5sluny Complete pumping sluggit slurry, 9 bags CaC03 sluggits mixed in slurry mixture. SLB lost count while mixing, mixed 9 bags instead of 8. 12:29 7940 812 1432 1.1 0 Switch to clean el 12:31 7940 817 1309 1.1 3 el/0 Switch to water 12:35 7940 817 3039 1.7 5wtr/0 Switch to KCL 12:43 7940 836 1450 1.0 25 Reduce rate 12:45 7940 835 1055 1.0 27 Slurry at nozzle, PU laying in sluggit slurry at 1:1 (66 fpm pumping 1b m 12:49 7610 835 875 1.1 32 Slu exits nozzle 12:56 7203 823 525 0.3 40 Reduce rate 13:46 150 546 52 0 58kc1 Come off um s, ull to surface. Pre are for in'ectivi test. 14:26 0 535 516 1.2 0 Bring pumps back on for infectivity. Pumping 1 %KCL down long strin . 14:43 0 34 350 2.0 18 Increase um rate 14:49 0 34 311 3.0 30.5 Increase pump rate, discuss with town the results of the infectivity test. Continue on. 15:25 0 34 250 3.0 139 Continue um in 15:30 0 34 240 0 150kc1 Down on um .Close swab 12.5 turns. 16:13 0 MU PDS GR /CCL BHA for coil fla run. 16:14 0 0 Flood a ui ment for PT 16:15 0 2 PT low to 379 si 16:19 0 2.7kc1 PT hi h to 4125 si 6 0 RIH with 1.70" x 0.29' CTC, 1.70" x 1.71' MHA (Dual Checks and 16:22 0 - Hyd Disconn), 1.65" x 0.46 XO, 1.688" x 0.35' XO, 1.5" x 0.75' KJ, 1.688" x 1.54' Battery, 1.688" x 2.14' Mem Sub, 1.688" x 1.93' GR, 1.688" x 1.54' CCL, 1.688" x 0.23' . OAL = 10.94'. 17:21 4000 -6 -25 PU Wt = 8.3k, Dwn Wt = 2.8k. 17:48 6050 -6 -5 Reach bottom to ed de th. Pause. 18:05 6050 -7 -10 Be in to in u at 40 m. 18:10 5900 -6 -33 Fla i at 5900' ctmd electronic 5898' mechanical. 18:14 5900 -7 -33 Continue to in 40 m u . 18:25 5500 -6 -32 Com lete to in .Pause. 18:31 5500 -6 -32 POOH with PDS memo GR/CCL 19:11 0 At surface close swab 12.5 turns, break off lubricator. 19:31 0 Data retrieved. 20:08 0 Logs reviewed by both PEs, PDS, and coil supervisor. Agree no correction needed. Coil flag log is on depth with Reference log: SLB RST / Waterflow Lo dated 14 Dec 2006. 20:32 0 B in RU of WFD BHA for settin lower ER acker for atch. 21:15 0 PT down back side Low 200 si 21:20 0 PT hi h to 2000 si. 0 RIH with 1.58" x 0.29' CTC, 1.78" x 1.69' MHA (Dual Checks and 21:28 Hyd Disconn), 1.69" x 7.06 HST setting tool, 1.78" x 0.65' Setting ada ter, 1.80" x 2.24' WFD ER Packer. OAL = 12.02'. 22:34 5901 -5 -20 Reach flag at 5900.3' electronic ctmd, 5899' mechanical. Corrected to center element on WFD ER packer, change depth to 5901.5'. 22:51 5972 -5 2220 0.8 0 Launch 3/8" ball. 22:59 5960 -3 1945 0.7 8.4 Pull into osition to set acker. 23:14 5960 -3 200 0.3 19 Reduce rate after um in 70% coil volume 23:47 5960 0 344 .3 29 Looking like ball may be hung up in checks, start working pump to et ball on seat 23:59 5960 0 878 .7 32.8 Continue WSR on 6/12/2009 ~ Final Tbq IA OAI I I I //apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=C750923DB69B44C7... 2/22/2010 We1lServiceReport • . Page 3 of 3 294 bbls of 1 % KCL 100 bbls of fresh water 12.5 bbls of HEC gel for 400# slugget slurry Performed daily inspection of tanks and secondary containment Visually inspected space between outer and inner hauls on return tank #93092 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=C750923DB69B44C7... 2/22/2010 We1lServiceReport WELL SERVICE REPORT U L~ Page 1 of 3 WELL JOB SCOPE UNIT MPS-1 O PACKERS/BRIDGE PLUGS (NRWO) CTU #9 DATE DAILY WORK DAY SUPV SET INFLATABLE BRIDGE PLUG; JEWELRY LOG-DEPTH DISBROW 6/12/2009 CONTROL; PATCH TUBING /CASING COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N DS-WAGONER SCARPELLA MIN ID DEPTH TTL SIZE 1.791 " 6062 FT 0 " __ CTU #9 w/1.5" CT Job Scope: Set IBP, Log, Set tubing patch «<InterAct Publishing»> ...Continue from W on ... Continue attempting with getting ball on seat. Ball on seat 7 bbls past CT volume. Ball may have been stuck in check valves. Continue wfth setting process per Weatherford specialist. Had problems with pressure bleeding off of setting tool. Sat down 2k and POOH. Broke down BHA completely and inspected all components for signs of trash, none found. HST running tool sent to shop for complete inspection and redressed before using again for setting of spacer and upper packer assembly. MU and RIH with WFD ER packer with spacer pipe and stinger to latch into lower ER patch packer set at 5960' corr. Stop at 5780' ctmd for pick up weights and to begin launching ball. Pump 5 BBLs KCL to launch ball. Ball in coil reel, come down on pumps, could not pick up or run in hole. Decision made to set packer where it was, then go back in to fish. Resume pumping ball. Set ER packer and spacer pipe. Top of ER packer at 5749' ctmd. POOH, broke down BHA and wait on WFD fishing tools. 3/8" steel ball recovered from BHA....Continue WSR on 6/13/2009..... LOG ENTRIES Init Tb , IA, OA 0 0 100 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 5960 0 200 .7 32.7 Continue WSR from 6/11/2009 00:07 5960 0 961 35.2 Ball on seat, must have been caught in checks, shut down pump and hold 5 min 00:13 5960 0 961 35.2 Continue with ressurin u on HST w/ ER lower acker assembl 00:15 5960 0 1195 35.3 Shut down and hold for 5 min 00:20 5960 0 1427 35.3 Continue with pressuring up on HST in 200 psi incroments until HST shears 00:30 5960 0 2560 35.4 Seen circ pressure fall 500 psi like something shifted, then caught and continue ressurin u 00:33 5960 0 4000 35.5 Pressure 1400 si over were it should have sheared? 00:35 5960 0 4030 35.5 Push down 1 k on ER lower packer to varify set. Setting tool may have not com letel shifted. 00:39 5960 0 4431 35.5 Continue ressurin u to 4500 si with 1.5k down 00:43 5960 0 4474 35.5 Slowl bleed down coil ressure 00:50 5960 0 0 35.5 Come on line with um ressurin u fast as ossible 00:56 5960 0 4344 36.3 Slowl bleed down coil ressure 00:58 5960 0 0 36.3 Come on line with um ressurin u fast as ossible 01:00 5960 0 4488 36.7 Slowly bleed down coil pressure to 500 psi, looking at yesterdays AWGRS report we had problems with pump while pumping sluggets we may have dislodged any residual in inner real iron when launching ball into reel which may have plugged ports in setting tool down hole 01:06 5960 0 500 36.7 PUH slow) and look for movement 01:07 5960 0 500 36.7 Looked like we started moving stop and go back down, ports appear to be lu ed u in rennin tool 01:12 5960 0 500 36.7 Set trips on UDAC and come on line hard and fast again hoping shock of tri s oin off will et iston to shift in tool 01:15 5960 0 4488 37 Hold ressure and discuss o tions 01:32 5960 0 4318 37 Bleed down pressure on CT and call Weatherford dispatcher... explain situation, and make sure that there is nothing that we are missing before PU off lower packer assembly ... set down 2k and continue discussion... 01:47 5960 0 0 Slowly PU 10' and run back in 5' to varifiy that we are released from ER lower acker. 01:52 5950 0 0 Slowly RIH 5' weight leveled off appears we are released, POOH slow) 02:01 5620 0 0 Throe h acker with no indication of roblems 02:02 5600 0 0 Throe h HES X-Ni le with no roblems... continue out of hole 02:50 0 BHA surface, close swab 12.5 turns and bleed down 02:56 0 PJSM tra ed ressure 03:10 0 Po off well and brake down BHA http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=A6959ASF81224249... 2/22/2010 WellServiceReport ~~ J Page 2 of 3 03:14 0 3/8" steel ball recovered 03:23 0 Broke all tools down and inspected for trash, no obvious signs, take HST rennin tool to sho and redress 03:33 0 LPT 255 si 03:39 0 HPT 3899 si 03:45 0 4081 1.4 37 Flush CT at max rate to ensure iron and coil are clear of any debries 03:58 0 4115 1.4 58 Watchin returns and all seem to be clean so far 04:05 0 4121 1.4 65 Coil volume pumped no sign of any soild or trash form coil or inner reel iron. 04:20 0 80* Shut down um and back off well 04:28 0 Off well, MU MHA 04:32 0 Pressure test MHA to 3500 si, ood 04:45 0 Shut down equipment and check fluids, standing by on HST ins ection and redress 07:45 0 WFD arrives with redressed HST tool. MU BHA 08:02 0 While stabbing on to well the BHA was lowered with the coil and sat down on a lip just inside the lubricator to BOP connection. Sat down approx 2k on the lip and bent the patch spacer pipe at the connection between the stinger and spacer pipe. Will get parts for re lacement from Deadhorse. 10:26 0 WFD arrives on location with replacement tools. MU WFD lower atch s acer i e and stin er. 10:48 0 Hold PJSM, dropped objects and pinch points discussed. Operations discussed were how to safely get the patch through the tree without re eatin the roblem from the last run. 11:04 0 PT low on the backside to 445 si. 11:09 0 PT hi h on the backside to 2208 si. 11:20 0 38 54 Open master to get in well 12.5 turns. RIH with 1.58" x 0.29' CTC, " x 1.69" x 1.78' WFD MHA (Hyd Disconn - 9/16", Dual Checks), 1.69 7.06' HST setting tool, 1.78" x 0.65' Setting adapter, 1.80" x 2.24' WFD ER packer, 1.341" x 8.30' Spacer Pipe, 1.341" x 9.0' Spacer Pie 1.80" x 1.62' Sna Latch Seal Ass . OAL = 30.94' 12:47 5850 38 57 PU Wt = 11.5k, Dwn Wt = 3.3k 12:59 5870 38 854 0.6 0 Launch 3/8" steel ball. Ball can be heard rollin in coil. 13:07 5870 39 124 0 5 Pump ball into reel with KCL. Caught fluid at 4.9 Bbls away, pressure climbed to 1400 psi, then dropped off. RIH to sting into lower ER acker. 13:09 5870 39 56 0 5 Cannot move down, cannot move u .Sat down 3k, icked u 8k. 14:53 5872 39 57 0 5 Picked u to 6.5k over, sat down 3.5k. No movement. 14:54 5872 39 1990 1.0 5 Discuss situation with town, decide to pump ball and set ER packer where it is, and fish. Be in um in ball. 14:55 5872 72 4029 1.2 6.5 Increase rate, ressure u coil 15:02 5870 3000 3765 0 13 WH ressure increases shut down um s. 15:34 0 51 2751 0.6 13 O en u backside to tank, be in um in ball a ain. 15:40 5870 51 3328 0.7 19.8 Ball still in coil -close to leavin reel. Returns = 0.5 BPM. 15:47 5870 51 3642 0.7 21.8 Ball heard leaving reel. Returns = 0.5 BPM. Did not hear ball fall back. 15:50 5870 50 1850 0.4 23.6 Reduce rate. Coil wt is neutral. 16:02 5870 51 3704 0 28.8kc1 Pressure increase, ball on seat. Spike to 3700 psi, drop off immediatl to 100 si circ ressure. 16:04 5870 39 61 Pick up off packer. PU to 13.5k, then broke over to 12k. Coil is movin .POOH. 16:56 0 38 50 Reach surface, close swab 12.5 turns. Be in ri down of BHA. 17:08 0 3/8" steel ball recovered. 17:30 0 WFD off location. 23:59 0 Continue WSR on 6/13/2009 Final Tbg, IA, OA l%ll/GV 1 t~ http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=A6959ASF81224249... • Page 3 of 3 bbls of 1 Performed daily inspection of tanks and secondary containment Visually inspected space between outer and inner hauls on return tank #93092 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereportldefault. aspx?id=A6959ASF81224249... 2/22/2010 We1lServiceReport WellServiceReport WELL SERVICE REPORT Page 1 of 2 WELL JOB SCOPE UNIT MPS-1 O PACKERS/BRIDGE PLUGS (NRWO) CTU #s DATE DAILY WORK DAY SUPV 6/13/2009 FISH; PATCH TUBING /CASING DISBROW COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N DS-WAGONER SCARPELLA MIN ID DEPTH TTL SIZE 1.791 " 6062 FT 0 " CTU #9 w/1.5" CT Job Scope: Fish preset upper Weatherford ER packer/spacer then run new and set. «<InterAct publishing»> ...Continue from WSR on 6/12/09... MU and RIH w. ER packer pulling tool on G-Spear. Latch fish at 5850' ctmd. POOH, fish retrieved intact. MU and RIH with WFD ER packer /spacer pipe /and stinger. Launch 3/8" steel ball. RIH and sting into lower WFD ER packer at 5960'. Pull 1.5k over, verify stung in. Pump ball onto seat and set packer. Top of Hacker at 5938'. POOH. Patch set, 3/8" steel ball recovered. RDMO. ***Job Complete*** LOG EN TRIES Init Tb , IA, OA TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Continue WSR from 6/12/2009 03:20 0 Weatherford on location with tools for fishing of upper section of ER atch, PJSM 03:31 0 Visually inspect all tools to be used during fishing operation and drift all com onets with 3/8", 1/2" and 9/16" balls 03:32 0 Pull test dim le connector to 15k 03:34 0 Start MU of fishin BHA 03:39 0 29 Fluid ack CT 03:55 0 38 Pressure test BHA to 3500 si 04:03 0 MU G-S ar and ER ullin tool 04:16 0 In'ector on wellhead, flood surface ui ment for testin 04:21 0 LPT 317 si 04:26 0 40 HPT 3855 si 04:32 0 Open swab valve 12.5. turns and RIH w/ 1.5" dimple connector, 1.7" DCV's, 1.7" Disco (9/16" ball), Circ Sub (112" ball), 1.7" Dual Acting Jar, 1.75" G-Spear, ER pulling tool. OAL = 13.56' Fish is 21.16' Once fish recovered OAL will be 34.72' 04:44 0 Having problems at SSV suspect ER being floppy on the end of the G-S ar. Line u down back side of CT 04:48 0 On line w/ pump... RIH past SSV no problems shut down pump and continue in hole 06:25 5850 Set down 2k at 5850'. PU 6k over then wei ht dro ed off. 06:28 5860 RIH and set down. Put 3k down on fish. PU 3k and weight dropped off. 08:34 5864 PU and RIH 40 m and set down 4k. 06:36 5864 Jar down and set down 2k. PU and begin to POOH. See weight bobbles while POOH. 06:48 5608 Pull 6k over at X-Nipple, weight dropped off immediatly. PU no more ove ull. 11.5k u wei ht. 06:50 5604 RIH at 40 fpm, set down 4k, relatch. POOH seeing occasional wei ht bobbles. 08:29 0 Bum u .Close swab 12 1/2 turns. 08:35 0 Verify fish retrieved. Nothing left in hole. Fish intact. No unusual markin s noted. 08:47 0 Break down ER acker / s aver i e / stin er 09:02 0 0 Fill coil for MHA PT. 09:07 0 8.1 PT MHA to 3730 si. 09:10 0 8.1 MU WFD MHA / ER acker / s acer i e / stin er 10:06 0 15.1kc1 PT down backside Low 364, Hi h to 2007 si. 10:20 0 Open master to get in well 12.5 turns. RIH with 1.58" x 0.29' CTC, 1.69" x 1.78' WFD MHA (Hyd Disconn - 9/16", Dual Checks), 1.69" x 7.06' HST setting tool, 1.78" x 0.65' Setting adapter, 1.80" x 2.24' WFD ER packer, 1.341" x 8.30' Spacer Pipe, 1.341" x 9.0' Spacer Pie 1.80" x 1.62' Sna Latch Seal Ass . OAL = 30.94' 12:06 5850 2 789 0 PU Wt = 10.5k, Dwn Wt = 4k. Launch ball. 12:28 5835 1 2.8kc1 Ball launched pumping 0.4 BPM, just into the coil. Come off pumps http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=180A21 F3A9514A53... .2/22/2010 WellServiceReport ~ • Page 2 of 2 RIH to stin into lower acker. 12:32 5954 1 34 Set down 2k. PU 1.5k to confirm stin in. Slack off to neutral wt. 12:36 5951 2 550 0.5 0 Brin on um sand be in to um ball. 12:39 5951 1 923 0.7 4.1 Increase rate. 12:45 5951 1 1570 0.6 5.1 Catch fluid, reduce rate. 13:17 5951 1 441 0.4 24.3 Ball heard oin over oose neck. Reduce rate. 13:32 5951 1 2602 0.4 30.8 Ball on seat, ressure u ,then dro ed to 1675 si. 13:37 5951 1 47 0 31.5kc1 Come off um s to allow settin tool to stroke and relax. 13:38 5951 1 45 PU off tool, PU wt = 12k. Pull up 10', RIH and set down on packer. Set down 2k. Packer in lace. 13:42 5900 1 47 Pull u hole, PU wt = 12k, RIH to re-ve ' to . 13:46 5952 1 36 Set down 2k, PU wt = 12k. POOH. Top of packer at 5938' (depth based on lower acker set at corrected de th of 5960' . 14:47 0 -7 20 2 0 Ta u at surface. FP well down backside. 14:53 0 -16 18 0 10m Down on um s. 14:54 0 Close swab 121/2 turns. Be in RD of WFD BHA 15:34 0 Patch set. 3/8" steel ball recovered. B in RD of unit. 18:00 0 RD corn lete. Travel to Z ad. Final Tb , IA, OA 0 0 50 59 bbls of 1 % KCL 10 bbls 50/50 MEOH 07:30 Performed daily inspection of tanks and secondary containment 07:30 Visually inspected space between outer and inner hauls on retui http://apps2-alaska.bpweb.bp.corn/awgrs-wellservicereportldefault.aspx?id=180A21 F3A9514A53... 2/22/2010 WellServiceReport WELL SERVICE REPORT CJ Page 1 of 1 WELL JOB SCOPE UNIT MPS-1O ANN-COMM UNKNOWN DATE DAILY WORK DAY SUPV 6/25/2009 AGBLEED KRUSKIE COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-I UNKNOWN UNKNOWN MIN ID DEPTH TTL SIZE 0" 0 FT 0" JOB COSTS SERVICE COMPANY -SERVICE CH2MHILL LABOR TOTAL FIELD ESTIMA http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=109BC 1139A014320... 2/22/2010 WellServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-1O ANN-COMM UNKNOWN DATE DAILY WORK DAY SUPV 6/26/2009 AC-BLEED KRUSKIE COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-I UNKNOWN UNKNOWN MIN ID DEPTH TTL SIZE 0" OFT 0" http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=C314FFEF 1 C4B41F... 2/22/2010 DAILY SUMMARY T/I/O 250/0/830 Bleed down OA from 830 psi in 8 min. all fluid 2.0 bbls ending T/I/0= 250/0/100 We1lServiceReport WELL SERVICE REPORT n ~1 J Page 1 of 1 WELL JOB SCOPE UNIT MPS-10 INJECTIVITY TEST LRS 64 DATE DAILY WORK DAY SUPV 6/30/2009 PUMP REA COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-R LRS-FOWLER BYARS MIN ID DEPTH TTL SIZE 0" OFT 0" T/I/0=0/30/380 Red Dye Test Pumped 125 bbls produced water and 5 gals. red dye down tubing. wen test unit testes wen MPS-05 during pump job and received dye at 112 bbls away. Pumped 5 bbls 60/40 methanol to flush lines. FWHP=0/0/120 Master. IA. OA. SSV. and Winq open. Swab closed. ~ n~ e~~ro~oc Init-> 0 30 380 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 18:00 Start Ticket. 18:27 Load Produced Water. 19:38 Arrive Location. PJSM. 20:00 MIRU. PT to 3000 si. 21:01 1.09 start h2o 110*F 150 30 380 Start um in down tubin . 21:08 1.09 7 150 30 380 21:18 1.09 18 150 0 320 21:30 1.09 30 150 0 280 21:47 1.09 49 150 0 240 22:05 1.09 69 150 0 200 22:23 1.09 89 150 0 180 22:41 1.09 108 150 0 150 22:55 1.09 125 150 0 140 Shut down. Swa to 60/40 methanol. 22:57 1 start 60/40 35*F 100 0 140 Start 60/40 methanol. 23:02 1 5 100 0 140 Shut down. RDMO. 23:59 End Ticket. Finales 0 0 120 al. Red Dye hlc Rfl/d(1 me+hannl http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=E5230761409B46A1... 2/22/2010 We1lServiceReport • ~ Page 1 of 1 . WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 64 DATE DAILY WORK DAY SUPV 8/18/2009 FREEZE PROT IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N LRS-MURPHY PERL MIN ID DEPTH TTL SIZE 0" OFT 0" Inita 0 0 260 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 10:30 Start ticket 10:46 Load 60/40 meth 11:10 PJSM, RU to LS Tb , PT-2500 11:44 1.5 0 60/40 40" 350 0 260 Start um in down LS Tb 11:52 1.5 12 350 0 260 SD RD Slickline on well at de arture 12:59 End ticket Final-> 0 0 260 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=B62D31114D 1 F422D... 2/22/2010 i nr_ ~~TQ~Gc . We1lServiceReport ~ ~ Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWCP #05 DATE DAILY WORK DAY SUPV 8/18/2009 DRIFT TUBING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N SWCP-COPE PERL MIN ID DEPTH TTL SIZE 1.791 " 6062 FT 0 " ***WELL S/I ON ARRIVAL""" (Dntt/ I eg) ««««cc«<LUIVh s I Kln-v»»»»» RUN KJ, 5' x 1.25" STEM, 1.75" LIB S/D @ 5936' SLM IMPRESSION APPEARS TO BE FISHING NECK ***WELL S/I ON DEPARTURE*** (Dso Notified) LOG ENTRIES Init Tb IA OA -> 100 0 0 TIME COMMENT 11:01 MOVE FROM MPI-02 TO MPS-10 «««««««<LONG STRINNG»»»»»»» 11:35 11:40 AOL, SPOT IN EQUIPMENT INSPECT LOC, HOLD JSA AND PJSM LRS SPOTS IN FREEZE PROTECT TUBING.R/U EQUIPMENT TOOL STRING: (1.5" RLS W/ 1.65" WHLS) RS, 10', KJ, 5', OJ, KJ, SSS 12:08 LRS R/D MOVE OUT OF WAY. GAIN CONTROL OF WIRE, STROKE SSV. 13:08 STAB ONTO WELL WAIT FOR BLEED TANK 13:25 BLEED TANK ARRIVES, PT LOBE 200 GAS, 300/3000 DIESEL, GOOD TEST 13:46 RIH W/ QC, KJ, 5' x 1.25" STEM, 1.75" LIB, S/D @ 5936' SLM. OOH SIBD, IMPRESSION APPEARS TO BE FISHING NECK 16:00 BEGIN R/D OF EQUIPMENT 16:59 MOVE TO MPJ-17 Fin al Tb IA OA -> http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=OAl D2288FC5 34BC... 2/22/2010 We1lServiceReport ~ • Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWS 2320 DATE DAILY WORK DAY SUPV 8/18/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N SWS-SIMONES PERL MIN ID DEPTH TTL SIZE 0" OFT 0" INITIAL T/I/O: 700/0/0 RU ELINE TO SET LOWER ELEMENT OF WEATHERFORD 40' PATCH. RIH WITH PATCH. ***** !^l1hITIAl11C n~ni~oc nni ~o_ni in_no***** LOG ENTRIES Init Tb IA OA -> 700 0 0 TIME COMMENT 20:30 ARRIVE ON LOCATION, SPOT EQUIPMENT, HOLD PJSM. 21:05 RU ELINE TO SET LOWER ELEMENT OF PATCH 22:45 STAB UNTO WELLHEAD, PT WHE, LOW 300, HIGH 3000. PT GOOD 23:22 RIH WITH TOOSTRING: HEADNVEIGHT BAR/CCUFIRING HEAD/SETTING TOOULOWER PKR. LENGTH: 19', OD: 1.69" Final Tb IA OA a http://apps2-alaska.bpweb.bp. com/awgrs-wellservicereport/default. aspx?id=AD32F7C4FDF0412... 2/22/2010 FLUID SUMMARY 1 BBL DIESEL TO PT WHE We1lServiceReport ~ • Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 64 DATE DAILY WORK DAY SUPV 8/19/2009 PUMP IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N LRS-TRAMMELL PERL MIN ID DEPTH TTL SIZE 0" OFT 0" FV1/HP's=750/0/0 E-Line Pumped 4.5 bbls diesel down Tbg. DSO notified SLB E-Line on well upon 1 A(, ENTRIES Init-> 800 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 Start ticket Load diesel Road to location 00:30 S t unit, PJSM, RU, PT lines to 3500 si 00:58 0.30 st diesel 50' 800 0 0 Start um in diesel down T 01:02 0.30 1.2 750 0 0 SD, Standb 01:14 0.30 1.2 750 0 0 Start um in 01:16 0.30 1.6 750 0 0 SD, Standb 01:18 0.30 1.6 750 0 0 Start um in 01:21 0.30 2.4 750 0 0 SD, Standb 01:23 0.40 2.4 750 0 0 Start um in 01:25 0.50 3.4 750 0 0 Increase rate 01:27 0.50 4.5 750 0 0 SD, Standb 03:00 RDMO 03:59 End ticket Final-> 750 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=D7E8037FAB2C4582... 2/22/2010 We1lServiceReport WELL SERVICE REPORT U Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWS 2320 DATE DAILY WORK DAY SUPV 8/19/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N SWS-SIMONES PERL MIN ID DEPTH TTL SIZE 0" OFT 0" *****CONTINUE AWGRS FROM 18-AUG-09***** ***WELL SHUT IN UPON ARRIVAL*** INITIAL T/I/O: 700/0/0 SET LOWER PACKER OF A 2 3/8" WEATHERFORD 40' TUBING PATCH. MID ELEMENT SET AT 5891'. TOOL HAD TO BE PUMPED DOWN BY LRS FROM 5840'-5910'. FINAL T/I/O: 600/0/0 LOG ENTRIES Init Tb IA OA -> 700 0 0 TIME COMMENT 00:16 SET DOWN AT 5841' DUE TO DEVIATION. CALL FOR LRS TO PUMP US DOWN. 00:32 LRS ON LOCATION, HOLD PJSM, RU LRS TO PUMP DEISEL DOWN TUBING. 01:35 LRS PUMPED DOWN TUBING AT 0.5 BPM. SET WEATHERFORD 2 3/8" LOWER PACKER MID ELEMENT AT 5891'. GOOD INDICATION AT SURFACE, POOH WITH TOOLSTRING. 02:17 REACH SURFACE, UNSTAB RD ELINE. Final Tb IA OA -> 600 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=AD32F7C4FDF0412... 2/22/2010 FLUID SUMMARY 1 BBL DIESEL TO PT WHE SEE LRS AWGRS FOR PUMPING DETAILS We1lServiceReport WALL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWCP #05 DATE DAILY WORK DAY SUPV 8/19/2009 ATTEMPT IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N SWCP-MENDEZ PERL MIN ID DEPTH TTL SIZE 0" 0 FT 0" RAN 2" GS & 25.77' WEATHERFORD SLICK STICK TO 5936' SLM (LOWER ER PACKER SHOULD HAVE BEEN AT 5891' ELMD) POOH W/SLICK STICK AND LOWER PACKER, APPEARS LOWER PACKER NEVER STARTED SETTING. RIG DOWN SLICKLINE, WEATHERFORD INVESTIGATING WHY PACKER DIDNT SET ***JOB INCOMPLETE, RDMO*** ***REPLACEMENT FOR LOST REPORT*** LOG ENTRIES Init Tb IA OA -> TIME COMMENT 12:01 21:00 Final Tb IA OA -> http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=51 F4A23 SB 1 CC48C5... 2/22/2010 WellServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWS 2266 DATE DAILY WORK DAY SUPV 10/25/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON N1GHT SUPV MSSPDWLIO-N SWS-HOWE PERL MIN ID DEPTH TTL SIZE 1.875 " 2994 FT 0 " vvCLL rLV YV nvv yr v~~ r~~~~.~vr.~ ~~-~~~.~. ~ ,.. ... .~ ~~.... ~. ........ ~~ INITIAL T/I/O = 0/0/350. SET WEATHERFORD LOWER PATCH ASSEMBLY MID ELEMENT AT 5891', LRS USED TO PUMP DOWN. POSITIVE VERIFICATION FROM SURFACE LOWER PACKER SET ***JOB IN PROGRESS CONTINUED ON 26-OCT-2009 WSR*** LOG ENTRIES Init Tb IA OA -> 0 0 350 TIME COMMENT 11:00 ARRIVE ON LOCATION, BEGIN SPOTTING EQUIPMENT. LRS ON LOCATION. 11:34 WAITING ON DSO TO SIGN PERMIT 11:48 LRS PULLED OFF LOCATION TO SLICK LINE JOB, CONTINUE WAITING ON DSO 12:26 DSO SIGNS PERMIT, WEATHERFORD ON LOCATION. 12:37 HOLD SAFETY MEETING W/ CREW AND WEATHERFORD. 12:49 CONTINUE RIG UP. 13:43 ASSEMBLY STRING AND TEST FIRE AND THEN WAIT FOR LRS. 14:42 PE ADVISES TO GO AHEAD W/O LRS; THEY WILL FREEZE PROTECT WHEN COMPLETE. 15:16 15:33 TOOL MADE UP, STABBED ON. BEGIN PRESSURE TEST 500 PSI LOW, 3000 PSI HIGH PT GOOD, DSO SHUT INJECTION IN AT MANIFOLD, WING CLOSED, OPEN SWAB AND RIH WITH HEAD(4x3) / ERS / 1-11/16" WT BAR /CCL / ESIC /BAKER E5-05 / 1.8" OD PLUG. TOOL LENGTH = 20', MAX OD = 1.8", WEIGHT = 100 LBS 16:38 TOOL CORRELATED TO XNIP AT 5606. TRY TO GET DOWN 17:14 TOOL COULD NOT GET DOWN, WAIT FOR LRS 18:46 LRS ARRIVES ON LOCATION 20:14 SAFETY MEETING WITH SLB NIGHT CREW BP PE, LRS, AND WEATHERFORD 20:34 LRS PT HOSES AND START FREEZE PROTECT 21:21 FREEZE PROTECT PUMPED START CORRELATION PASS 22:47 23:01 PULL INTO POSITION SET PLUG AT 5891' CCL TO ME=13.9' CCL STOP DEPTH = 5877.1' GOOD INDICATION ON SURFACE PKR SET, DROP DOWN TO TAG POSITIVE TAG. POOH 23:59 ***JOB IN PROGRESS CONTINUED ON 26-OCT-09 WSR*** Final Tb IA OA a 0 0 http://apps2-alaska.bpweb.by.com/awgrs-wellservicereport/de - - - - ~ WellServiceReport ' WE'LL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 68 DATE DAILY WORK DAY SUPV 10/25/2009 PUMP IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N LRS-BRENNY TOM UNKNOWN MIN ID DEPTH TTL SIZE 0" OFT 0" T/I/0= 0/0/0 Assist E-Line -freeze protect and assist down hole (Set 40' patch over tubing leak in long string below production packer) Pumped 2 bbls 60/40 methanol from flowline back to header. Pumped 32 bbls 60/40 methanol down tbg while assisting a-line. FWHP's=0/0/0 E-line on well at departure __ 1 AG ENTRIES -- - -----_-_ Inita 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 18:00 start ticket ,load 60/40 on F- ad 18:50 sot unit, meet w/ e- line 19:10 RU to LS in divert skid 20:38 Pt surface line to 3500 si 20:43 .4 start 60/40 40* Pum in down flow line back to header 20:45 .4 2 SD/ Swa to um down LS in well 20:52 .4 start vac 0 0 Pum in down LS 21:15 .25 12 vac 0 0 SD/ SEL ullin u 21:34 .25 12/st vac 0 0 Continue um in 21:40 0 14 vac 0 0 SD 21:50 .25 14/st vac 0 0 Continue um in 22:00 .35 17 vac 0 0 Increase rate 22:01 0 17 vac 0 0 SD 22:04 .35 17/st vac 0 0 Continue um in 22:08 0 18 vac 0 0 SD 22:14 .3 18/st vac 0 0 Continue um in 22:24 .5 21 vac 0 0 Increase rate 22:26 0 22 vac 0 0 SD 22:33 .6 22/st 100 0 0 Continue um in 22:37 .8 25 200 0 0 Increase rate 22:38 1.0 27 300 0 0 Increase rate 22:39 0 27 vac 0 0 SD 23:29 .8 27/st vac 0 0 Continue um in 23:32 1.0 30 300 0 0 Increase rate 23:33 .5 31 50 0 0 Slow rate 23:34 0 32 vac 0 0 SD 23:44 RD 23:59 End ticket Final-> 0 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=CC7096B6681 D413B... 2/22/2010 WellServiceReport • • Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWS 2266 DATE DAILY WORK DAY SUPV 10/26/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N SWS-HOWE PERL MIN ID DEPTH TTL SIZE 1.875 " 2994 FT 0 " *** JOB IN PROGRESS CONTINUED FROM 24-OCT-09 WSR *** (E-LINE: PATCH) (LONG STRING) AT SURFACE VERIFY PATCH ASSEMBLY SET RIG DOWN ELINE FINAL T/I/0=0/0/0, NOTIFY DSO OF VALVE POSITIONS WING/SWAB=CLOSED, SSV/MASTER=OPEN, IA/OA=OTG ***JOB COMPLETE LEAVE LOCATION*** LOG ENTRIES I nit Tb IA OA a 0 0 350 TIME COMMENT 00:09 ***JOB CONTINUED FROM 24-OCT-09 WSR*** 00:34 AT SURFACE BLEED DOWN AND UNSTAB, VERIFY PATCH ASSEMBLY SET 01:50 RIG DOWN ELINE FINAL T/I/0=0/0/0, NOTIFY DSO OF VALVE POSITIONS WING/SWAB=CLOSED SSV/MASTER=OPEN, IA/OA=OTG 01:58 ***JOB COMPLETE LEAVE LOCATION*** Final Tb IA OA a 0 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=E6BD85E4718A4269... 2/22/2010 WellServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWCP #05 DATE DAILY WORK DAY SUPV 10/29/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N SWCP-MENDEZ PERL MIN ID DEPTH TTL SIZE 0" 0 FT 0" *** WELL S/I ON ARRIVAL *** (set tbg patch) »»> LONG STRING ««< RIH W/ 2" GS (full brass) & 27' SLICKSTICK,LATCHED INTO PACKER @ 5866' SLM.JARRED FOR 1 HOUR UNABLE TO SHEAR OFF. R/U LRS,ON LINE @ 2 BBLS A MINUTE,JARRED FOR ONE MORE 1 HOUR.NO LUCK SHEARING OFF.BRASS PIN WAS SLIGHTY WORKED. RIH W/ 2" GS (half alm) & 27' SLICKSTICK. *** CONTINUE ON 10-30-09 *** LOG ENTRIES Init Tb IA OA -> 950 TIME COMMENT 03:00 TRAVEL OVER FROM F-PAD. 03:20 ARRIVE ON LOC.HELD PJSM,INSPECT LOC.SPOT EQUIPMENT,START R/U. 05:30 C/O TO GOERDT, PJSM, JSA. 06:15 BEGIN R/U 08:30 WEATHERFORD ON LOC. PJSM. CONT W/ R/U,CRANE NOT TALL ENOUGH TO COVER ALL TOOLS. 12:00 RECONFIGURE EQUIPMENT. R/U 30',20' & 2-5'.5" RISERS.TOTAL OF 61' OF 4.5" LUB. T.S.= 3' x 1-1/2" r.stem 1.7" whls , 5' x 1-1/2" tun sten, 3' x 1-1/2" r.stem 1.7" whls , OJ, KJ, LSS 14:00 PT LUB 250/2500. RIH W/ 2" GS (brass), 26.77' SLICKSTICK X 1.80" O.D.JARRED FOR ONE HOUR,POOR JAR ACTION. 15:50 SD @ 5866' SLM. JAR DOWN SEVERAL TIMES BEFORE SLICKSTICK LATCHED IN PACKOFF. JAR DOWN FOR 1 HR. UNABLE TO SHEAR GS. CALL FOR LRS.STBY. 17:33 C/O TO MENDEZ.HELD PJSM,INSPECT LOC.STBY FOR LRS. 20:18 LRS ON LOCATION.HELD PJSM,R/U & P/T HOSE. 20:46 22:14 PUMP ON LINE @ 1 BBL A MINUTE THEN INCREASED TO 2 BBLS.START JARRING DOWN.PICK UP @ 5864' SLM.JARRED FOR 1 HOUR,UNABLE TO SHEAR OFF.JARRED UP TWICE,PULLED FREE.POOH. OOH W/ TOOLS & PATCH.BRASS PIN SLIGHTY WORKED ON GS.CONSULT W/ REP.RUN HALF ALM.CUT OFF 200' .125 WIRE.TESTED WIRE. 23:36 RIH W/ QC,2" GS half alm & 26.'.77" SLICKSTICK. 23:59 CONTINUE ON 10-30-09. Final Tb IA OA -> 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=523 8677A71834FF3... 2/22/2010 We1lServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 64 DATE DAILY WORK DAY SUPV 10/29/2009 PUMP IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N LRS-FOWLER PERL MIN ID DEPTH TTL SIZE 0" OFT 0" ------------ Inita 1,000 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 19:00 Start Ticket. 19:07 Load Diesel. 19:54 Arrive location. PJSM. MIRU. PT to 3500 si. 20:47 1 start diesel 60'F 1000 0 0 Start um in down tubin . 20:54 1 5 120*F 700 0 0 21:02 1.1 14 250 0 0 21:07 1.5 20 200 0 0 Increase Rate. 21:14 1.5 30 200 0 0 21:21 2 37 350 0 0 Increase Rate. 21:25 1 43 200 0 0 Cool down coils. 21:26 1 44 200 0 0 Shut down. Stand b for slickline to POOH. 23:59 End Ticket. Continue on next da wsr. Final-> wsr. 2/22/2010 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default. aspx?id=DCEC422F9737433 C 1 (lf: FNTRIFC We1lServiceReport WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 64 DATE DAILY WORK DAY SUPV 10/30/2009 PUMP IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N LRS-FOWLER PERL MIN ID DEPTH TTL SIZE 0" 0 FT 0" T/I/0=0/0/0 Assist Slicklline Continued ftom 10-29-09 WSR. Pumped remaining 16 bbls diesel @ 120*F down tubing to assist slickline with setting patch. Load andTransport diesel ftom Kuparuk. FWHP=O/0/0 Slickline in control of well upon departure. 1 A~•_ CAITDIGC _ Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 Start Ticket. 00:26 1 44/st diesel 90*F 100 0 0 Resume um in down tubin . 00:38 1 55 100 0 0 00:42 1 60 100 0 0 Shut down. 01:18 RDMO. 01:47 Travel to Ku aruk for diesel. 02:40 Load Diesel. 03:15 Travel to Milne Point 04:03 Offload Diesel MPB- ad. 04:29 End Ticket. Finala 0 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=SF57EB98606D4ESC... 2/22/2010 We1lServiceReport WELL SERVICE REPORT C~ C~ Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWCP #05 DATE DAILY WORK DAY SUPV 10/30/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N SWCP-MENDEZ PERL MIN ID DEPTH TTL SIZE 0„ OFT 0" *** CONTINUED FROM10-29-09 **" (set tbg patch) »»> LONG STRING ««< RIH W/ 2" GS (half alm) & 27' SLICKSTICK,SET @ 5866' SLM. RETURN ON LATER DAY TO SET TOP PATCH. *** WELL S/I ON DEPARTURE *** LOG ENTRIES Init Tb IA OA a 0 TIME 00:10 COMMENT CONTINUE RIH W/ PATCH.LOCATED PAKER @ 5864' LSM.JARRED DOWN FOR 10 MINUTES,000LD NOT GET SNAP LATCH TO LATCH.JARRED DOWN HARDER.PICKS UP CLEANLY,LOST 50 LBS.UNABLE TO PERFORM PULL TEST.APPEARS GS SHEARED,CONTINUEJARRlNG DOWN FOR 20 MORE MINUTES.POOH.FLUID LEVEL 1200' SLM. 01:00 OOH W/ TOOLS.GS SHEARED.R/D LRS.REPIN TOOL. 01:45 2" GS (half alm).LOCTED TOP OF PATCH @ 5838' SLM.TAPPED DOWN SEVERAL TIMES,GOOD RIH W/ QC , LATCH.PERFORMED TWO GOOD OVER PULLS,400 LBS OVER.JARRED DOWN FOR 10 MINUTES.PICKED UP CLEANLY,POOH.FLUID LEVEL 1200' SLM. 02:30 OOH W/ TOOLS.GS SHEARED.START R/D.RETURN ON LATER DAY TO SET TOP PATCH. 04:59 R/D COMPLETE.NOTIFY PAD OPR.TRAVEL TO E-PAD. Final Tb IA OA -> 0 http ://apps2-alaska.bpweb.bp.com/awgrs-wellservicereportJdefault. aspx?id=31 BF29D0678347AC... 2/22/2010 We1lServiceReport ~ • Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER SWCP #05 DATE DAILY WORK DAY SUPV 10/31/2009 PATCH TUBING /CASING IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N SWCP-MENDEZ PERL MIN ID DEPTH TTL SIZE 0.0868 " 5938 FT 0 " *** WELL S/I ON ARRIVAL *** (set tbg patch) »»> LONG STRING ««< RIH W/ HES ETD & 16' SLICKSTICK,SET @ 5838' SLM. `"-~ LRS ASSISTED WHILE SETTING PATCH. PUMPED A TOTAL OF 30 BBLS OF 90 DEG DIESEL. *** WELL LEFT S/I ON DEPARTURE *** LOG ENTRIES Init Tb IA OA -> 500 0 TIME COMMENT 06:00 TRAVEL FROM E-PAD TO S-PAD.»»» LONG STRING ««« 06:20 ARRIVE ON LOC.HELD PJSM,INSPECT LOC.SPOT EQUIPMENT,START R/U.RIGGED UP 30',13' (2-5' riser & 1- 3' riser & 30' LUB,OAL-63' LUB. 08:30 C/O TO GOERDT. PJSM W/ WEATHERFORD AND HALLIBURTON. JSA 09:11 CONT W/ R/U 10:00 BAD TESTS ON WIRE 14-16 W/ BAD BREAKS. 11:40 PULLED 2200' OF WIRE. LAST TEST WAS 30 TURNS., CONT. W/ R/U 13:20 LRS ON LOC. R/U ON PUMP-IN SUB PT. 13:58 UNSTAB FROM WELLHEAD ASSEMBLE FIRING HEAD AND PATCH. 14:12 BATTERY ENGAUGED IN FIRING HEAD 14:34 RIH W/ FIRING HEAD, W/ 16.34' PATCH. 15:30 LRS ONLINE W/ PUMP. 15:39 SD @ 5838' SLM, JAR DOWN FOR 15 MINS. 1 OVER PULL TO 700#. WAIT FOR TOOL TO FIRE. LRS DOWN ON PUMP, PUMPED TOTAL OF 30 BBLS OF 90 DEG DIESEL 16:00 R/D LRS 17:25 TOOL FIRED,PICKS UP CLEANLY OFF PATCH,LOST 50 LBS.POOH. 17:36 C/O TO MENDEZ.HELD PJSM,INSPECT LOC.CONTINUE POOH 200 FPM. 18:10 OOH W/ TOOLS.PATCH SET R/D HES.START R/D EQUIPMENT 19:59 R/D COMPLETE.NOTIFIED PAD OPR,TRAVEL TO F-PAD. Final Tb IA OA -> 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=37B98A436AB041 D... 2/22/2010 We1lServiceReport • WELL SERVICE REPORT • Page 1 of 1 WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS s4 DATE DAILY WORK DAY SUPV 10/31 /2009 PUMP IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-N LRS-ZIMMERMAN PERL MIN ID DEPTH TTL SIZE 0" OFT 0" Inita 600 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 12:00 Start ticket. Load diesel road to location. 12:27 On location. SIMOPS w/ slickline. Pre-heat diesel. 13:21 S t unit. RU to lubricator. 13:46 PT to 3500 si. 13:53 PJSM w/slickline. slickline to install patch, runnin tool on tool strip . 14:31 SL RIH. 15:27 0.5 St Diesel 90`F 600 0 Online down tubin . 15:29 0.75 1 600 0 Increase rate. 15:32 1.0 4 500 0 Increase rate. 15:35 1.5 7.5 450 0 Increase rate. SL settin atch. 15:39 1.5 12.5 400 0 15:44 1.5 19 300 0 15:51 1.5 30 250 0 Shut down. Patch artiall set. Ri down. 16:59 End Ticket. Final-> 250 0 0 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereportldefault.aspx?id=BEF75314959E44199... 2/22/2010 LOG ENTRIES WellServiceReport ~ • Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPS-10A PATCH TUBING /LINER LRS 6a DATE DAILY WORK DAY SUPV 11/2/2009 MIT-IA IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWLIO-N LRS-TRAMMELL PERL MIN ID DEPTH TTL SIZE 0" OFT 0" T/I/0=540LS/960LS/0/0 (Pre AOGCC) MIT IA PASSED to 2000 psi. Pumped 3.4 bbls diesel to reach test pressure. Lost 4u psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 60 psi in 30 min. Bled down psi. DSO notified Swab wing ssv shut, Master is oa open. FWHP's=540LS/960SS/0/0 LOG ENTRIES --- Inita 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 01:00 Start ticket, Road to location 01:30 S t unit, PJSM, RU, PT lines to 3500 si 02:08 1 st diesel 25* 0 0 Start um in diesel down IA 02:10 0.50 2 500 0 Decrease rate 02:13 3.4 2000 0 SD, Start MIT IA 02:28 1960 0 02:43 1940 0 Pass, Start bleedin down si 03:10 0 0 Shut in bleed, RDMO 03:59 End ticket Finales 0 0 TEST #1 REQUIRED TEST PRESSURE 2,000 TEST TYPE MIT-IA FLUIDS USED TO TEST DIESEL START TIME: 02:13 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 960 960 960 960 IA 0 2,000 1,960 1,940 PASS OA 0 0 0 0 COMMENTS Tb si indicated in test is the Short Strip .Lon strip Tb si maintained 540 si durin test. http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=1 BDA961 BC 86043 C... 2/22/2010 We1lServiceReport . ~ 1~VELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT MPS-1 O ANN-COMM LRS 64 DATE DAILY WORK DAY SUPV 11 /6/2009 MIT-IA REA COST CODE PLUS KEY PERSON NIGHT SUPV MSSPDWL10-I LRS-MURPHY PARKS MIN ID DEPTH TTL SIZE 0" OFT 0" I T/I/0=30/560/150 MIT-IA (PASSED) to 2000 psi. (AOGCC witnessed by Lou Grimaldi) Pressured up IA w/ 1.1 bbls diesel. IA lost 80 psi in 1st 15 min. IA lost zero psi in 2nd 15 min for a total loss of 80 psi in 30 min. Bleed IA down to 500 psi w/ 1.1 bbls diesel returned. Swab closed. Wina. Ssv. Mst.. I. O oven. Notified operator and tact well. FWHP= 30/500/140 LOG ENTRIES Inita 30 560 150 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 09:30 Start ticket 09:40 Road to Loc. 10:00 PJSM, RU, PT-3500 10:40 1 0 diesel 50* 30 600 150 Start um in down IA 10:42 1 1.1 30 2040 300 SD, Start 1st 15 min 10:57 30 1980 310 1st 15 min IA lost 80 si 11:12 30 1980 310 tad 15 min IA lost 11:14 30 500 140 Bleed IA down w/ 1.1 bbl return/Ta well 11:21 RDMO, Swab closed. Win ,Ssv, Mst., I, O o en 11:50 Road to MPB- ad to off load diesel 12:30 End ticket Final-> 30 500 140 JOB COSTS SERVICE COMPANY -SERVICE [ LITTLE RED LITTLE RED PLUS 20 PERCENT TOTAL FIELD ESTIMATE: TEST #1 REQUIRED TEST PRESSURE 2,000 TEST TYPE MIT-IA FLUIDS USED TL , ~~ ~ DIESEL START TIME: 10:42 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 30 30 30 30 IA 560 2,040 1,980 1,980 PASS OA 150 300 310 310 COMMENTS http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=526D0754DA494556... 2/22/2010 Tree: CIW 2 1/16" 5M Dual string Wellhead:11" x 2 3/8" 5M FMC dual Hanger thread 2 3/8" EUE top and IBT 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112' 9-5/8" 40 #/ft, L-80 BTC 2,776' MPU S-10ai ~g• KB Elev. = 73.05 Orig. GL Elev. = 38.90 2,996' 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 300` Hole angle passes 50° @ 2775` Hole angle passes 70r' @ 5600' Hole angle passes 8t7' @ 5950' 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.=.0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,610' 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,630' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,643' Tubing tail / WLEG i 6,138` 7" Halliburton Float Collar PBTD 6,225` 7" Halliburton float shoe Perforation Summary Size Spf Interval (TVD) 3 3/8" 6 OA sands 5,730` - 5,830' B d 4,146' - 4,170' 2 7/8" 6 Q san s 6,850` - 7,350' 4,199' - 4,189' 2 7/8" 6 8,250' - 8,550' 4,209' - 4,220' Guns : 3406PJ, HMX, 60 deg. phase ~ Isolated 2906PJ, HMX, 60 deg, phase DATE REV. BY 06/22/02 MDO 06/11/03 MDO 10/20/05 MDO COMMENTS Top of CaC03 Sluggits dumped @ 7444' 1 11/16" Baker IBP (Set 6/13/09) @ 7500' 4.5" Baker Landing Collar g,g2g~ 4.5" HES Float Collar 8,870' 4.5" HES Float 8,915' MILNE POINT UNIT Drilled by Cased Doyon 141 WELL No.: S-101 Completion Rig Doyon 14 API • 50-029-20152-00 Sidetrack & Completion Doyon - 14 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,994' NOTE :Well sidetracked 10!20/05 Kick-off @ 2839' and LoN4 Sni~4 NOTE: PArctFEr There is a tbg patch set at 5851'. ID through the patch is 0.877". ' I ,through the patch is 0.868 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,606' 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,620' 1.945" ID. 5 Weatherford Patch's (0.868" min ID) 5851 - 91' 5938 - 60' 2-3/8" HES XN-Nipple (1.875" pkg. bore) 6,062' No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub " 6,068' pkg. bore) (2.00 No-Go Locator sub @ 6,082` 7" Tie Back Sleeve 7"x 5" HRD ZXP Liner pkr. 6,095` 6,085' 7"x 5" HMC Liner Hng. 6,073' BP EXPLORATION (AK) MEMORANDUM To: Jim Regg ~~~~, il'3~ ~`(' P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 18, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-IOA MILNE PT UNIT SB S-l0A Src: Inspector NON-CONFIDENTIAL Reviewed By: ~~, . P.I. Suprv Comm Well Name: MILNE PT UNIT SB S-l0A API Well Number: 50-029-23152-01-00 Inspector Name: Lou Grimaldi Insp Num: mitLG091107050243 Permit Number: 205-125-0 Inspection Date: 11/6/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. S-l0A ~ T"~ ~ Well ~ Type Inj. TVD y--- -~-- ------ -~ ---- - - T eTest ~ -~ ---~ 2os12so i w I p SPT ~ TeSt Sl P T D~ 4] 13 ~' I,d~ ~ 560 ~ _ ----- --- - / ----- 1500 ~ QA ~ 150 ~ ~ 2040 1980 i _ _ __ - 300 310 1980 ~ - - 310 - 1 y p . . - ----~ --- ---~--`- --~ ----- -- -~---T- T bi 30 - - t 30 30_ 30 ~ -- Interval P/F ---P - - ng-- u ~ ---- ~ - -- ~--- --------- - Notes: 1.1 Bbl's pumped. Good test. Wednesday, November 18, 2009 Page I of I • • ~~`~, ~ ~~ ~ ~ r~ ~~~LL~ ~ ~! p"~~; ~~ ~`~ r~~ ~' ..~ ~~_; ~~ ~ r E ~~, ~ ~ ~ ~ ~ ~ ~d ~ ~ ~ ~ ~ ~ ~' ~ ~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~~ ~^,. ~i'.~.~ ~ ~~:..< ~~s ~' ~ Y_~ ~' W ~ i.~.~ ~~~s~ ~by -_ ~ . qqq~ ~~ ~ ~-7~ ~I~ tusi~ tit~-.7 ~ 333 W. 7th AVENUE, SUITE 100 CONSER~PATIOI~T COI~IIKIS51O1~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 s FAX (907) 276-7542 October 20, 2009 Mr. Harry Engel Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AL 99519-6612 .. ~ ~~ iil~ ~r .?:~ t~ L.LlVJ Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-02, MPS-09, MPS-10 and MPS-26 203-127, 202-020, 05-125 nd 203-061 BP Exploration (Alaska) Inc. Dear Mr. Engel: Enclosed are the work descriptions for subsurface well treatments in the listed wells that were erroneously submitted containing information and operational details proprietary to BP. These work descriptions have been replaced with the edited documents you supplied. Sincerely, ~ - ..~ Thomas E. Maunder, PE Sr. Petroleum Engineer Enclosures (4) ha co ~Zc 5 c~-~c~."~. ~~ ~~9` - " Anchorage, Alaska 99519-6612 {~~f ~~~ ~`~" Re: Milne Point Field, Schrader Bluff Pool, MPS- l 0A Sundry Number: 309-217 Dear Ms. Smith: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Cc~mmission 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. S ,t Chair DATED tYus / day of July 2009 Encl. (~ STATE OF ALASKA ~ ,. " ~~~ ALA OILAND GAS CONSERVATION COMMI N ~~~~~~ ~~~ ~~ ~ ~ ~~ ,~ APPL ATION FOR SUNDRY APPRO ALS~r ~ ~~ ~n nnr. ~~ ~an ~.1~~N ~' ~~p(1G 1. Type of Request: Abandon ^ Suspend ^ Operationai shutdown ^ Pertorate S [~ a ~ ~~ ,, Alter casing ~ Repair well Q Plug Perforations ^ Stimulate ^ Time E~n i '~ ~lry~'~+p~~~~, f~~; Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~"~ ~ ~. \ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 205-1250 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~, 6. API Number: Anchorage,AK 99519-6612 50-029-23152-01-00 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 ^ MPS-10A ` 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-380110 73.3 KB MILNE POINT Field / SCHRADEft BLUFF Pool . 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8915 - 4201.12• 8828 4209.04 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 211.5# A-53 32 112 32 112 Surface 2745 9-5/8" 40# L-80 31 2776 31 2475 5750 3090 Intermediate Production 6195 7" 26# L-80 30 6225 30 4210 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 8995 4207 4201 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - SS 2-3/8" 4.7# L-80 30 - 6073 LS 2-3/8" 4.7# L-80 30-6073 Packers and SSSV Type: Packers and SSSV MD (ft): 2-3/8" BAKER GT DUAL PKR 5620' 5" BAKER ZXP TOP PKR 6085' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ~ Development [] Service Q- 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/7/2009 Oil Gas ~ ^ ^ Plugged ~ Abandoned 17. Verbal Approval: Date; WAG ^ GINJ ^ WINJ Q WDSPL ~ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact pqIGE SMtTM Printed Name pAiGE SMITH T~t~e PRODUCTiOiV ENGIIVEER Signature Phone Date 564-4728 6/23l2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _Z ~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ~ Other: ~~ ~`,~` ll'~~~~~CSc ~S~ "~St.l\~S ~T~'~~.I~~ S~.1~S2 vC `~~ . ~ ~ . , . Subse uen q t Form Required. ~ t~ C~v~~ _ Y APPROVED BY q Approved by: COMMISSIONER THE COMMISSION Date: ~ 1 I ~ Form 10-403 Revised 0 Y Submit in Duplicate ~ ~~ ~U~ t~ ~ 2009,.~. ~ 3 ~ g ~ J ~ ~ ~... ~` .~j ~~~~~~ ~~~~~~ MPS-10A 205-125 PFRF OTTdCHMFNT ~ Sw Name Operation-Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS-10A 10/20/05 PER 5,730. 5,830. 4,146.37 4,170.71 MPS-10A 10/20/05 PER 6,850. 7,3~0. 4,199.07 4,189.89 MPS-10A 10/20/05 PER 8,250. 8,550. 4,209.02 4,220.4 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRQDDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . , ~ ~ Tree: CNV 2 1/16' 5AA Oual string We~flegd:i 1' x 2 318' 5M FMC dual sUing HanQer tlvead 2 318' EUE top and IBT bWh Z' CIW-H BPV pto5le 20" x 34' ir~sula~ed. 215 ti/R A-53 177 M PU S-10ai Orig. KB Elev. = 73.05 Orig. GL Elev. = 38.90 9~i/8" 40 #M, L-BO BTC 2.779' Short Strina 2,996' 2-3l8" HES X-Nipp{e (7.875' pkg- bore) KOP ~ 300' Hole an~e passes 50° ~ 2775' Hale angie pa~es 7~ 5600' Hole angie passes S~ ~ 5950' ~' 2H~, L-90. BTRC Cesinp (driR id = 8.151, cap = .0383 bpf) 2-38", 4.7 t6rlR L-80, IBT t~ing (driR id = 7_9U9, cap =.00387 bpf} 5.810' 2-38' HES X-Nipple (1.875" pkg. bore) 5,830' 2-31$' HES XN-07ippk (L875' pke_ bon No-Go 1791' 5,843' Tubing tai 1 WLEG 6,138' T H~I~~rio~ Float Collar PBTD 0.725' 7' Flaibur0on tloet stqe Petforation Summary 5ize Spf Ir~erval (TVD) 3 3!8' 8 ~ ~~~ 5,730' - 5,83U' 4,148' - 4,17a" 2 718' B ~ 8.850' - 7.350' 4.799' - 4.789' 2 7!6' 8 8.250' -@.550' 4,208" - 4,220' Lona Strina 23/8 HES X-Nippfe ~1 _H75' pkp_ bore) z.eea' NOTE : Well sidetradced 10/20/05 lGdc-of~ (~ 2839' md NOTE: rn~.~ ~5 8 me ~n ~e ~~s~. in n~,9n fhe pahi~ is D.888" 2-3/8' HES X-NipQle (1 _875' pkg- borel 5,808' 7' c 2-3f8' Baker "GT' Ret. dual pkr. 5,820' 1.945' ID_ VYeaU~erford Pe~h (D.868' min ID) ~~' ~ 2~18' HES XN-NipQle ( 7.875' pkg. bae) 0.062' No-Go 1.781' 2-3l8' Beker'E' F+ydm Trip Sub ' 8.088' ~ Cl.OQ Pk9- 6ore) No-Go LocaOor wb ~ 8,082' 9.095' 7' Tie Beck Sleeve 7'x 5' HRD ZXP Liner pkr_ 8.065" ` Tx 5" HMC Liner Fkig. 0.073' Top of CeCA3 Stuggits dumped ~ 7444' 1 11(t6' Baker 18P (Set 81131OB} ~ 750~' 4_5' Baker L.a~inp Cdar 8.828' 4.5 HES Float ColFar 8.870' 4.5' HES Ro~ 8,915' MILNE POINT U WELL No: 5-10i API : 50-029-20152-00 14 BP EXPLORATION (AK) COMMENTS Qr~ed try C~ed Dayon 141 Gomp~ Rig Dvyo~ 14 s-b~x a c«„p~aw, ooyo~ Guns : 3408PJ. f~IX. 00 dey. phsse 2908PJ. HMX. 80 de{~, phase DATE REV_BY D8I22102 MOO 08119I03 MDO 10l20/05 MDO • • f Q ` F ', ~ ~~ ~'; ~ '~ ~ ~ ~ ~ ~` SARAH PALIN, GOVERNOR ~~. ~~"~~ O~ ~ GA5 ~~ 333 W. 7th AVENUE, SUITE 100 C01~TSERQA'1`IO1~T COMI~TISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Preble Data Manager BP Exploration (Alaska) Inc. P.O. Box 196612 ~~'.,~ ~ ~, Anchorage, Alaska 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS- l0A Sundry Number: 309-186 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this , ~~day of June, 2009 Encl. `~' ~~~ . STATE OF ALASKA • _ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ' ~ APPLICATION FOR SUNDRY APPROVAL ~„ ~~,. ~~ ~Q„ G~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Oche Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ TUBING PATCH Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ ~~7E ~~` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 205-1250 3. Address: P.O. Box 196612 Stratigraphic~ Service ^~ 6. API Number: Anchorage, AK 99519-6612 S0-029-2315 . . 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes; MPS-10A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Poois(s): ADLO-380110 73.3 KB MILNE POINT Field / SCHRADER BLUFF OIL Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8915 4201.16 8828 4209 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 80 20" 2115.5# a53 32 112 32 112 Surface 2745 9-5/8" 40# I-80 31 2776 31 2475 5750 3090 Production 6195 7" 26# I-80 30 6225 30 4210 7240 5410 Liner 2842 4-1/2" 12.6# I-80 6073 8915 4207 4201 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - SHORTSTRING 2-3/8" 4.7# L-80 30 -5643 - - LONGSTRING 2-3/8" 4.7# L-80 30 - 6073 Packers and SSSV Type: 2-3/8" BAKER GT DUAL PKR Packers and SSSV MD (ft): 5620 5" BAKER ZXP TOP PKR 6085 13. Attachments: Descriptive Summary Proposal ,, 14. Weil Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 6/15/2009 OIL ^ GAS (] PLUGGED ~ ABANDONED 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pre Title Data Manager Signature Phone 564-4944 Date 6/1/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O Plug Integrity ^ BOP Test ^ Mechanical Integrity Test '~ Location Clearance ^ t `` __ Other: ~~~\ Cdv~~o`-~.~`~Q'M~+~~c-~~t't\C7~C~~'~~"~'`1`c~~~ps~.-~~d~~~s~ Subsequent Form Re fired: 1~g'li / APPROVED BY ~~f / ~ ((( Approved by: COMMISSIONER THE COMMISSION Date. ~Jf Form 10-403 Revised 06/2006 f~t~~'~s [~1i91~/ ORIGINAL ~%/ Submit in Duplipte ~~ • STATE OF ALASKA ~ ~~~~~~~'` ' - ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ 0 ~ zOD~ APPLICATION FOR SUNDRY APPROVAL ~n AAC; ~S ~~n ~las~ta Oil ~ f;s~r r,,.,.. r~___ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waive Othe Ariap~ Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ ime Extension ^ TITGING PATCH • Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-en Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory 205-1250 3. Address: P.O. Box 196612 Stratigraphic^ Service 6. API Numbe~3 /Sj --t~ ~_ Anchorage, AK 99519-6612 S~ ~ aL X50-029-23152- - 0 ~j- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Nam and Number: property line where ownership or landownership changes: MPS-1 OA . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Fi d/Pools(s): ADLO-380110 73.3 KB MILNE POINT Field / SCHRADER BLUFF OIL Pool 11. PRESENT WELL CONDITION MMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective D th TVD (ft): Plugs (measured): Junk (measured): 8915 4201.16 8828 4209 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 2115.5# a53 32 2 32 112 Surface 2745 9-5/8" 40# I-80 31 776 31 2475 5750 3090 Production 6195 7" 26# I-80 30 6225 30 4210 7240 5410 Liner 2842 4-1/2" 12.6# i-80 6073 8915 4207 4201 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing ize: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - S ORTSTRING 2-3/8" 4.7# L-80 30 - 5643 - - ONGST RI NG 2-3/8" 4.7# L-80 30 - 6073 - _ E ` ti'~LiP~~ - j l0 Packers and SSSV Type: 2-3/8" BAKER GT DU PKR Packers and SSSV MD (ft): 5620 5" BAKER ZXP TOP KR 6085 12. Attachments: Descriptive Summ Proposal ~ 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: 6/12/2 9 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ =[~ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the fore mg is true and correct to the best of my knowledge. Contact Paige Smith Printed Name i e ith Title PE Signature Phone .564-4278 Date 5/29/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: h,~ Form 10-403 Revised 06/2006 ~ ~ ~ ~ `'~~ ~ ~ Submit in Duplicate MPS-10ALS 205-125 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS-10ALS 10/20/05 PER 6,850. 7,350. 4,199.1 4,189.93 MPS-10ALS 10/20/05 PER 8,250. 8,550. 4,209.06 4,220.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE U REVISION #2 TWe1lyBgd: 1 `Ix 238' SM FMC dual sh:,g ~ P V S -1011 Hanger 9xead 2318' EUE top and IBT 2" C1VIr-Fi @PV prase Za"x34' ~ 215 fNlt Aa3 11r 458' 4D M/R, L-8D BTC 2,778• , Short String 2,41' 2~/8' HE (1-875' pkg. hare} KOP ~ 30D' Fide angle Pis SOa ~ 2775' Fide ar~ig~tee mosses eiP 5%0' T 2911. L-80, BTRC Casing (drdt id = 9.151. a~.= .0393 bpf) 2-3i8', 4.71 LSO, IBT homing (drift id =1-gD1, ~ =-OD387 bpi} 5.61[1' 2318' HES X~Fpple (1.875' Pkg. bore) Orig. KB Elev. = 73.05 Org. GL Elev. = 38.90 Lunn String 218' HES X-Nipple (7-875' pkg. bore} 2.994' NOTE : Well sideh'adced 70r2QJ05 IGdc-otf ~ 2839' tnd 2-318' HES X-Nipple (9-875" pkg- hart} 5,gpg• T x 2-318' Baloer'GT' Ret dual pkr. 5.620' 1.945' ID- 5.830' 2.1'!8'HESXN-Nipple{1-975'pkp.bon Nlo-Go 1-791' 5,843' Tubingl~lWL.EG 9,138' T Hallbkrbn Float Catlar PBTD 6,725' 7" Haihurion float shoe Peirtoration Summary Size Spf Intierval (TVD) 338' 9 ~saods 5,730'-5,930' 4,146'-4,17D' 2718' 6 ~ SYOdi 6,85D'-7,350' 4,1~-4,i9g' 2 719' 6 9,250' - 8,55D' 4,208' - 4,22D' Gars : 3406PJ, MN)C, 9D deg- phase 29DDPJ. HkiX, 9D deg, phase DATE REV-BY D9rrr1D2 klDo Od11A3 rmo 10120105 MDD 2-38' HES XH-FFppla (1.875' pkg. bore) 6.092' No-Go 1.791' 2-318' Baker'E' Hydro Trip Sub ' 6,D~' pkg. bore} (2.00 No-Go Loaahor sub ~ 6,D8r 9.095' T rre Back sleeve 7'x 5' HRD Z74' Liner pkr. 8,D85' Tx 5' HMG Liner Hng. 6,073' 4.5` Baker Larrdrg Cafar 8.828' 4.5" HES Fk~el Ca9ar 9.970' 4.5' HES Fk~ 8.415 OOMMENTS Dried by Cased Doyen 141 Compieliork li'g [)oyon 14 Sidetrack 8 Gampleiwr Doydr -14 M1LNE POINT UNIT WELL No.: S-10i ARI : 50-029-2~152~ BP EXPLORATION (AK) • • IWaUtlder ThQltlas ~ I~Q/4 From: Engel, Harry R [Harry.Engel@bp.com] Sent: Wednesday, August 12, 2009 7:49 AM To: Maunder, Thomas E (DOA) Subject: Revised Procedures for AOGCC re: MPU gel treatments Attachments: MPS-02 Gel Treatment.doc; MPS-09LS Gef Treatment.doc; MPS-10LS Gel Treatment.doc; MPS-26SS Gel Treatment.doc ao5 -~as ~~ ~~ `~~ ~~ MPS-02 Gel MPS-09LS G~i Mf a-iULS Gc'.I MPS-26SS Gel reatment.doe (lip .freatment.doc {11.,fr~atment.dQC (lU.. fre~tment.doc (85.. Good morning Tom- Enclosed are the procedures I propose for the Milne Pt. Sundries. Please review and let me know if these meet your needs, If so, I recommend we substitute these for what was previou5ly subznitted. Thanks for your assista~ce in this matter. Harry Engel Engineering Team Leader Alaska Drilling & Wells ~~;:~~~~'~=~ ~`~t; ~~ y ~ ~~~~ ~ ~~ C~ To: Mark O'Malley/Jerry Sharp MPU Well Operations Supervisor From: Paige Smith, MPU Schrader-S Pad Engineer ~ Subject: MPS-10LS Gel Job ~0 5 - ~~-S • Date: June 22, 2009 Step Unit Operation 1 SL Chan e out WFRV 2 O Shut in all offset producers and offset injector. Bullhead 10 bbl gel into MPS-10LS. 3 O Bullhead ~20 bbls gel into MPS-10LS. Leave well SI for minimum of 2 days. 4 O Bullhead 10 bbl el into MPS-10LS. 5 O Bullhead ~500 bbl gel down MPS-10LS. Keep well and offset producers and injectors shut in for minimum of 7 days and flow producers to a tank before returnin to production. OBJECTIVE 1. Divert water from its preferential path. Measure of success 1. Gel treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient (~850 psi for MPS- 10LS). • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant gel per guidance from the Environmental Team. PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset injectors and producers are SI 3. Spear in with 1-2 barrels of Methanol, pump 125 bbls produced water preflush, 10bb1 gel and 125 bbls produced water over flush. Pump at 1 bpm with a max pressure 3000 psi (frac pressure + estimated friction). Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. i • Stage 2. Low Volume Gel Treatment 5. Ensure offset injectors and producers are offline 6. Pump 63 bbls produced water preflush, ~20 bbls gel and 50 bbls produced water over flush followed by 10 bbls freeze protect. Pump at 1 bpm or a max pressure 3000 psi WHIP (frac pressure + estimated friction). However, injection pressure limits may be exceeded as necessary to avoid trashing the wellbore by leaving gel in the tubing or liner. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Keep well and offset injectors and produces SI for a minimum of 2 days. Stage 3. Injection Test 9. RU, hold pre-job safety meeting, PT surface lines 10. Ensure offset injectors and producers are SI 11. Spear in with 1-2 barrels of Methanal, pump 125 bbls produced water preflush, 10bb1 gel and 125 bbls produced water over flush. Pump at 1 bpm with a max pressure 1200 psi (frac pressure + estimated friction). Attempt to hold injection rate constant while adjusting pressure as needed. 12. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 4. High Volume Gel Treatment 13. Ensure offset injectors and producers are offline 14. Pump 63 bbls produced water preflush, ~500 bbls gel and 115 bbls produced water over flush followed by 10 bbls freeze protect. Pump at 1 bpm or a max pressure 1200 psi WHIP (frac pressure + estimated friction). However, injection pressure limits may be exceeded as necessary to avoid trashing the wellbore by leaving gel in the tubing or liner. 15. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 16. Rig down all equipment and hold post-job assessment meeting to capture learnings to be incorporated into future jobs. 17. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. ~ ~ Tf~e: ~GIW Z 1116' 5M Oual s4ing Wephead:t 1" x 2 3l8' 51~f FMC dual straig Fkanger fhread 2 318' EUE tap and 18T botk 2' CIW-H BPV pnoFile 20" x 34' irssu4ated. 215 ~IRt A-53 11 ~' 9-~l$` 40 #Ift, L-8U 8TC Z.7~8' M P U S-14a i Orig. KB Elev. = 73.U5 Orig. ~L Eiev. = 38.9H1 Short Strino 2.~6' 2-3t'S HES X-NiPpFe (1.875 pk~. borej KOP ~ 300' Fble angle pasaes 5~ ~ 2T75' Hole angis passes 7~ 5600' Hde arx~le passes 8{P ~ 5950' T 28#. L-BU. BTRC Gasing {~ift id = 8.751, cap = .0383 bpfa 2-3f8". 4.T #!Ft L~O. 9BT t~ing {driR id = 1.901. cap.=.~D387 bp5} 5,81D' 2~18" HES X-Nipple (1.875' pkg. bore) 5,83D' 2-3r8" HES XN-f~dppfe (1.875' pkg. bors) No-Go 1.791' 5,843` TubinBleillWLEG i 8.138' 7' Helhbvlon Float Collar PBTD 6,225' 7° HahburUon float slae Pertoration Summary Si~e Spf In~erval (ND) 3318' 8 ne ~.,.k 5,730'-5,839' 4,1#6'-4,170' 2 7/8" 8 06 ~a.,ds 8.859' - 7.350' 4.196' - 4.f89' 2 7/B' 6 8.250' - 8.550' 4.208' - 4.220' \ Guns : 34U8PJ, HlNX, BO deg. phase Isdated 29DBPJ. FiMX, 80 deg, phase C?ATE REV, BY UBJ23J02 MDO GBt19 Rk3 1.~0 1a12[7/05 MDO 2-31~' HES X-FiiPpfe R'1 A75' pkg. bare) 2,694' NOTE : Well ~detradced 10/2(}705 Kicic-off @ 2839' md NOTE: I ~fiere i5 a~bg peMche selt at 5838'. ID 11Mo~~tx j the patcfi is G.868" 2-3~8' HES }C-NiPple (1.875' pkg. bore) 5,BD8' i' x 2-375' Beker "GT Ret duai piv. 5~,82Q' 1.945' ID. weatne~~ R~ ~o.aas- ~an ioy d ~as - ~° 2-3f8' ~IES XN-Alipp{e (1.875' pke. borej 8.U82' No-Go 1.791' 2-3t8` Baker `E' Hydro Trip Sib ' 8A66" (2.00 pkg. bore) No-Go LocaDor wb ~ 8.082' 8.U95' 7' Tie 6ack Sleeve Tx 5" HRD ZXP Liner pkr. 8.~~~ ~ 7'x 5' HMC Liner Hr~. 8.473' Top of CaC03 Sluggils dumped ~ 7444' 1 71/19" Bakg 18P (Set &+73106) ~ 750U' 4.5' Baker Lar~d"mg Cdlar 8.8~~' 4.5" HES Float CoIlar B,&70' 4.5' HES Floe# B~A~`'~ COMMEHTS Drilled by Cased Doyon 941 Campkelion Rip Doyon 14 Sidetrack & Completion Doyon - 14 MILNE POINT UNIT WELL No.: S-70i API : 50-029-,20152-00 BP EXPLORATION (AK) 10-403 MPS-l0A Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 01, 2009 2:43 PM To: 'Preble, Gary B (SAIC)' Cc: 'Smith, Paige S.' Subject: RE: 10-403 MPS-10A (205-125) Page 1 of 2 Gary, I have spoken with Commissioner Foerster and she has given her oral approval for your request. I will look forward to the new form 10-403 tomorrow. As discussed, all that is needed is the duplicate copies of the form. Also, please check the API number. There is an -82- included in the sequence when the correct numbers are -01-. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, June 01, 2009 2:39 PM To: Maunder, Thomas E (DOA); 'Preble, Gary B (SAIC)' Cc: 'Smith, Paige 5.' Subject: RE: 10-403 MPS-10A Gary, I have spoken with Commissioner Foerster and she has given her oral approval to proceed. I look forward to the revised form 10-403 tomorrow. As discussed, all that is needed is the form in duplicate. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, June 01, 2009 1:17 PM To: 'Preble, Gary B (SAIC)' Cc: Smith, Paige S. Subject: RE: 10-403 MPS-l0A Gary and Paige, I just received the 10-403 and I need to ask you to resubmit the form. Several of the data fields have been altered/resized and while 1 can understand why this modification has been done, we cannot accept modified forms. It is possible that we may incorporate some of the changes you have proposed in a revised version of the form. It does appear that the proposed work plan is complete and I will speak with Commissioner Foerster regarding an oral approval. Call or message with any questions. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, June 01, 2009 9:51 AM To: Maunder, Thomas E (DOA) Cc: Smith, Paige S. Subject: 10-403 MPS-10A 6/1 /2009 10-403 MPS-l0A Page 2 of 2 Tom, I just rushed a 10-403 for well MPS-10A (tubing patch) over to you this morning. Due to some scheduling problems on the slope Paige has requested to get this 10-403 pushed thru the AOGCC for approval. I realize that this is not the normal way to handle 10-403's but it would be greatly appreciated if you could possibly help us out. Thanks Gary Preble Petrotechnical Data Team Coordinator Science Applications International Corporation Office 907.564.4944 Mobile 907.350.6879 preblegb~bp.com 6/1/2009 ~~ ~~~J ,/~-lT'~ DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051250 Well Name/No. MILNE PT UNIT SB S-10A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23152-01-00 MD 8915 TVD 4201 Completion Date 10/20/2005 Completion Status 1WINJ Current Status 1WINJ IC Y REQUIRED INFORMATION Mud Log No Samples No Directio al Surve DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DIR, IFR/CASANDRA, SCMT, GCL, NEU/DEN Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Typ~ Med/Frmt Number Name Scale Media No _t - ---_ -- ----- ----- ------- 5 Blu 1 ' ,'ED D Asc Directional Survey ~ / Y . D D A i E sc Direct onal Survey / I , ~ Cement Evaluation 5 Blu 1 I D C Las 14348 Induction/Resistivity Leak 5 Blu 1 C Pds 14501 Caliper log Gr~D C Lis 14513 Induction/Resistivity Rpt/~ 14513 LIS Verification le6g Injection Profile F~7 C Lis 15344 Induction/Resistivity /Well Cores/Samples Information: Interval Name Start Stop (data taken from Logs Portion of Master Well Data Maint Interval OH / \~ Start Stop CH Received Comments 2726 8915 Open 11/17/2005 Definitive 2726 8915 Open 11/17/2005 MWD 0 6053 Case 1/24/2006 CEMENT BOND LOG SLB TRACTOR/USIT/SGT- UCAL-Y 3682 6056 Open 1/22/2007 LIS VERI, GR, CCL 5700 6032 Case 1/29/2007 Compsite WFL, LDL, Spin, Temp, Pres, GR, CCL 15- Dec-2006 0 5954 Case 2/21/2007 Multi-Finger Caliper 3D Data & Viewer 11-Feb-2007 2735 8822 Open 3/16/2007 LIS Veri, GR, ROP, FET, NCNT, DRHO, NPHI 2735 8822 Open 3/16/2007 LIS Veri, GR, ROP, FET, NCNT, DRHO, NPHI 5700 6020 Case 6/11/2007 Injection Profile (REVISED) Spin, Temp, Pres, GR, CCL 7-May-2007 2735 8850 Case 8/23/2007 LIS Veri, GR, ROP, FET, FCNT, NCNT, RHOB, NPHI Sample Set Sent Received Number Comments a DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051250 Well Name/No. MILNE PT UNIT SB S-10A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23152-01-00 MD 8915 TVD 4201 ADDITIONAL INFORMAtT~ION Well Cored? Y / Chips Received? Y~~%~N"' Analysis Y ! N Received? Comments: Completion Date 10/20/2005 Completion Status 1WINJ C~,u,~rrent Status 1WINJ Daily History Received? ("~-""' Formation Tops ~%/ N UIC Y --- -- Compliance Reviewed By. _ _ _ _ __ __ Date: ~ __~~ WELL LOG TRANSNIITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-10A MPS-l0A Digital Log Images: 50-029-23152-01 August 8, 2007 AK-MW-3978051 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~' ~ ,1~7 Date: ~'°~'~ ~`" ~ ~, ri, ~ m~isaio~~ ~~,~~,~isc~~ BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: UlCo~bs-{a~ ~ 153~/~~ Schlumberger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r,_~~i IF,B i% d. 7~~~~ tlY18i3~6D' ~ .... n..~...:s:.... 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 nose a~ rt„L,. rn 06/07/07 L5-23 11733320 PRODUCTION PROFILE 04/30/07 W-38A 11660532 MEM PROD PROFILE 05102/07 Z-38 11660534 MEM PROD PROFILE 05!05(07 1 17-22 11745213 LDL 04/29!07 1 W-19A 11628772 MEM PROD PROFILE 05107107 1 Y-24 11630477 LDL 05/08/07 1 16-OSA 11686747 LDL 05120107 1 G-OS 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 65/08/07 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 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE 05/22/07 1 04-10 11594498 LDL 05119!07 1 B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROFIGLS 05102107 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A N/A LDL 05109107 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 PLEASE ACKNOWLEDGE RECEIPT 6Y SIGNING AND REI UKNING VNt GUYY tAGt1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~~ ~S -- (~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN Beth Received by: i O~ ~L ~I~ ,=- Ti~d4/~ISI~I/L ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 1 EDE MPU S - 10AI Caliper report 2) 3) 4) 5) 7) Signed Print Name: (~~1. r i~lt.e _ Gi,(~t, it, ~~ rt. ,~~ , ~. ~~, , _.~ __ ~. Date _ .n _ .. _ . ~ ~3~ s :e~~+a ~. _ ~ . -"._ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ~!?Sa1o~CHO~G~t~~i=?i3s?RY'~LG.~vS4 WEBSITE:Ln1!~~1~1.a4EPJ1~R"C~w.G.^.4Yi D:\Master_Copy_00_PDSANC-20xx\Z_Word\Dislribution\Transmittal_SheetslTransmit_Originat.doc 11-Feb-07 01/25/2007 Alaska Data & Consulting Services = ~, ~ ~ 2525 Gambell Street, Suite 400 `t ~' j ~ ~~~~~ ~ Anchorage, AK 99503-2838 ATTN: Beth , `° t e.,. ^ ~ a ~ a a t§ ~.`=1i ; t Well .Inh 8 i ..,. n......_:-.a:,._ NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 vwv~ vv Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12121106 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-OSA 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A S-02A 12-32 11539744 11285936 11536184 MEM INJECTION PROFILE MEM PROD PROFILE USIT 12106106 08/17/06 12/05/06 1 1 1 MPS-i0A 11486087 COMPOSITE WFL/LDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L1 11588700 MEM PROD PROFILE 12123106 1 E-11B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10/29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 - G-14A 11485777 SCMT 11/27/06 1 PI FARE ACKWrl1AIt Cr1/2C OC f^G~oT ov c~~nu wn wun .~. BP Exploration (Alaska) Inc. - - - - --_ -.-_ .-_. _.-.-'.-_ ...._ vv. ~...,,, , v. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 ATTN: Beth Received by: ~`0 ovzzizoo~ SChhlmberger Alaska Data & Consulting Services 2525 Gambe-1 Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII -Inh f! U~~ aoS- 1~5 1 nn flncrrintinn NO. 4112 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Fieid: Prudhoe Bay rl~tu RI f`nlnr !:A MPS-10A 11076475 CH EDIT SCMT (PDC-GR) 10117105 1 15-08CL1 10942196 CH EDIT JEWELRY (PDC-GR) 03/01/05 1 Z-12 11513657 RST 12/06/06 1 1 L3-11 11533392 RST 12/31/06 1 1 AGI-10A 11485869 USIT 11/09/06 1 GN{A2A 11485873 USIT 11/15106 1 GNI-02A 11485874 MDT 12/03!06 1 12-18 N/A USIT 11I17-O6 1 NGI-07A 11212892 USIT 10/13/06 1 DS 12-14AL1 11540230 CORROSION & CBL 12/18/06 1 01-23 11549351 USIT 12/16/06 1 WGI-09 11486172 USIT 12/03106 1 rLtASt AGKNVWLtUGt Ktlalrl I3Y SIGNING ANU RETURNING ONE GUPY EACH TD: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & ~ oatt~Llhng ~~vi~¢)s 2525 Gambell Stet/ ~+te~406 Anchorage, AK 99503-2638 ATTN: Beth o ~ ~ , r,' ~ ' Received by: r,-_. • • RE: MPS-l0i (PTD #2051250) MITIA r ~ Subject: RE: MPS-IOi (PTD #2051250) MITIA From: "NSU, ADW Well Integrity Engineer" <NSUADWWeIIInte~-ityEngineer@BP.coin> Date: Mon, 06 Nov 200Ei 11:29:19 -0900 'ho: "AOGCC - Winton :%~ubcrt (E-mail)" ~~~winton aubcrtiri a~lmin.statc.ak.us==, im_re«<~~(iadm i n.state.ak. us C'C: "NSU, :AD W' ~~%ell Operations Supervisor" ~ ?~~SUADWWe~110perationsSuper~~sor(rrBP.com~, ">v1PU, ~-Fell Operations Supervisor" ~_«'elloperationssupervisor(~i?L3P.com=>, "llughcs, An~jrca" <hu~~ha=t(~i)BP.com=, „C;hcsher, Jar~les R" ~~_james.chcshe.r~a~~BY.c~~rn>. ~~Sau~-e. ~~~tark A,~ "IV1ark.Sauvual3P.com=~, "NSl 1, ~,DW" ~,~~ell Integrity F,~n~~incer" -NSU ~'~D~~~'~~elllntegrityEn~tiincer(ci~BP.co~~1>, "NSt1, Ai~~~r ~~'i Tech" NSU:4DWWlTechra:BP.com=°, "!finders, Joe L" =~ani]crs22~~t.~Bl'.com~. "Austin. Pahl .A" ~~=PauI.A.Austini~i;BP_com ~~ Hi Winton, To fallow up with our conversation today, we have found pressure communication in MPS-10 (PTD #2051250) between the two tubing strings below the production packer. I have included a wellbore schematic as well as MITlA results showing that the communication is not in the tubing, production casing, or main production packer. «MPS-10ai.pdf» «MIT MPU S-10 10-20-06.x1s» PCease let me know if you have any questions. Thank you, .~nna {Dube Well integrity Coordinator GPB 1lVells Group Phone: {907) 659-5102 Pager: {907} 659-51UO x1154 From: Sauve, Mark A Sent: Tuesday, October 24, 2006 8:07 AM To: NSU, ADW We11 Integrity Engineer Cc: NSU, ADW Well Operations Supervisor; MPU, Well Operations Supervisor; Hughes, Andrea; Chesher, James R Subject: RE: MPS-10i Leak Detect Log Request Revision #1 Joe, A series of recent static pressure measurements indicated that there was pressure communication between the two tubing strings on this dual injector. However, there was never any pressure build-up on the IA so we figured the most likely communication path was below the production packer. The MIT-!A we recent pumped was just to absolutely confirm there were no integrity issues with this wellbore before we started to look for the leak path. I suspect the communication path is via the long string tubing seals where it stabs into the liner tap packer @ 6,073' MD or possibly behind pipe via poor cement across the 7" casing shoe. Since the pressure communication is entirely contained below the upper production packer do we really need to get the AOGCC involved is what is really zonal conformance issue? 1 of 3 11/6/2006 3:55 PM )ZE: MPS-l0i (PTD #2051250) MITIA ( Dope this clarifies the situation. Thanks for taking such a keen interest in our wails and please let me know if there are any regulatory(notification issues !missed during this process. « File; MPS-10ai.pdf » Mark Sauve Milne Point Artificial Lift & Production Coordinator BP Exploration -Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com From: NSU, ADW Well Integrity Engineer Sent: Monday, October 23, 2006 8:25 PM To: Sauve, Mark A Cc: NSU, ADW Well Operations Supervisor; MPU, Well Operations Supervisor; Hughes, Andrea; NSU, ADW Well Integrity Engineer Subject: RE: MPS-10i Leak Detect Log Request Revision #1 Hi Mark S. FYI, it appears the sbpe WlE's have not had any communication with the AOGCC regarding MPS-10. Looks like an MITIA passed on 10120106, not sure how this effects plans to troubleshoot tubing-tubing communication, Please let us knew if we can be of any assistance. Later, Joe From: Sauve, Mark A Sent: Thursday, October I9, 2006 12:37 PM To: G MPU Wellwork Programs Subject: MPS-10i Leak Detect Log Request Revision #1 Greetings All, Please add the enclosed request for an E-line leak detection log on MPS-10i to the WBL and delete the previous request sent out last Monday. This is dual-string injector well with confirmed pressure communication between the two tubing strings. This log is requested to find the exact source of the leak in order to design the most optimal repair. Please contact me if you have any questions. « File: MPS-10 E-line leak hunt rev#1.doc » Mark Sauve Milne Point Artificial Lift & Production Coordinator BP Exploration -Alaska 900 E. Benson Blvd Anchorage, AK 99519 2 of 3 11/6/2006 3:55 PM i RE: MPS-l0i (PTD #2051250) MITIA Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com Content-Description: MPS-l0ai.pdf j MPS-l0ai.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ _ _ _ _ __ ', Content-Description: MIT MPU 5-10 10-20-06.x1s 'MIT MPU 5-10 10-20-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 3 of 3 11/6/2006 3:55 PM STATE OF ALASKA Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD !UNIT /PAD: Milne Point Unit /MPU / S Pad DATE: 10/20/06 OPERATOR REP: Mel Iveson AOGGC REP: ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Packer Depth Pretest Initia{ 15 Min. 30 Min. Well MPS-10A Type Inj. W TVD 4,113' Tubing 1,000 1,000 1,000 1,000 Interval O P.T.D. 2051250 Type test P Test psi 1028.25 Casing 2,000 1,960 1,950 P1F P Notes: MITIA to confirm tubing, production casing, and OA 200 450 450 450 production packer integrity Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T=Test during Workover O =Other (describe in notes) MIT Report Form BFL 911105 - MIT MPU S-10 10-20-06-1.xls Tree: CIW 2 1/16" 5M Duals Orig. KB Elev. = 73.05 Wellhead:l1" x 2 3/8" 5M FM~{ string M P U S-10 a i Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 38.90 Z" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112' 9-5/8" 40 #/ft, L-80 BTC 2,776` Long Strina 2,996' 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 300' Hole angle passes 50° @ 2775' Hole angle passes 80° @ 5950' 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpi) 5,610' 2-3/8"HES X-Nipple (1.875" pkg. bore) 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,994' NOTE :Well sidetracked 10/20/05 Kick-off @ 2839` and 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,806` 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,620' 1.945" ID. 5,630' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,643` Tubing tail / WLEG 6,138' 7" Halliburton Float Collar PBTD 6,225' 7" .Halliburton float shoe Perforation Summary Size Spf Interval (TVD) 3 3/8" 6 OA sands 5.,730' - 5,830' 4,146' -4,170' 2 7/8" 6 OB sands 6,850' - 7,350' 4,199' - 4,189' 2 7/8" 6 8,250' - 8,550' 4,209' - 4,220' Guns : 3406PJ, HMX, 60 deg. phase 2906PJ, HMX, 60 deg, phase DATE REV. BY 06/22/02 MDO 06/11/03 MDO 10/20/05 MDO 2-3/8" HES XN-Nipple (1.875" pkg. bore) 6,062` No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub " 6,068` pkg. bore) (2.00 r ~ No-Go Locator sub @ 6,082` " 6 095' .~ 7 Tie Back Sleeve , ' T 7"x 5" HRD ZXP Liner pkr. 7"x 5" HMC Liner Hng. 6,085 6,073` COMMENTS Drilled by Cased Doyon 141 Completion Rig Doyon 14 Sidetrack & Completion Doyon - 14 4.5" Baker Landing Collar g,g2g~ 4.5" HES Float Collar 8,870` 4.5" HES Float 8,915' MILNE POINT UNIT WELL No.: S-10i API : 50-029-20152-00 BP EXPLORATION (AK) STATE OF ALASKA A ALA OIL AND GAS CONSERVATION COMI~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat Shutdown ~ Perforate ~ Re-enter Suspended Well ~ x" . m 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: ~ Name: Development Exploratory 1~' 205-1250 3. Address: P.O. Box 196612 Stratigraphic Service ~', 6. API Number: Anchorage, AK 99519-6612 50-029-23152-01-00 ~ u-~ :~ 7. KB Elevation (ft): 9. Well Name and Number: ~ ~ ~ m 73.3 KB MPS-10A ai ~ 8. Property Designation: 10. Field/Pool(s): ~ ~ ~ rn ADL-380110 Milne Point Field/ Schrader Bluff Oil Pool ~ 11. Present Well Condition Summary: ~. H Total Depth measured 8915 feet Plugs (measured) None true vertical 4201.12. feet Junk (measured) None Effective Depth measured 8828 feet true vertical 4209.04 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" X 34" 215.5# A53 32 - 112 32 - 112 Surface 2745 9-5/8"40# L-80 31 - 2776 31 - 2474.77 5750 3090 Production 6195 7" 26# L-80 30 - 6225 30 - 4209.91 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 - 8915 4207.13 - 4201.12 8430 7500 Perforation depth: Measured depth: 5730 - 5830 6850 - 7350 8250 - 8550 True Vertical depth: 4146.37 - 4170.71 4199.07 - 4189.89 4209.02 - 4220.1 Tubing: (size, grade, and measured depth) S hortstring 2-3/8" 4.7# L-80 30 - 5643 Longstring 2-3/8" 4.7# L-80 30 - 6073 Packers and SSSV (type and measured depth) 2-3/8" Baker GT Dual Packer 5620 5" Baker ZXP Top Packer 6085 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory Development Service ~~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas ~ WAG ~'~' GINJ ~ WINJ ^~'' WDSPL r 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: 306-009 Contact Sharmaine Vestal Printed Name Sharm ain e Vestal Title Data Mgmt Engr ~ ` Signat~~%~% ~Ls~i„~ Phone 564-4424 Date 3!21/2006 Form 10-404 Revised 04/2004 "i ~ g ~~I ~ Submit Original Only ~L MA~i ~ ~ 2006'- ~ ~¢~ 3/a/~ .6~ Sl•3~G • MPS-10A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY` 2/3/2006 Acid Treatment. CTU #9. Road unit from shop to location. MIRU. ***Continued on 2/4/06 WSR*** 2/4/2006 Acid Treatment. CTU #9. Continued from 2/3/06 WSR. Perform weekly BOP test. Good test. Pump 100 bbls 2% KCLMU / RIH with 1.5" JSN. Sat down at 1680' ctmd. Work and jet thru mung. Tag TD at 8584' CTMD. Treat interval 8250' - 8550' with 86 bbls 7.8% - 90:10 DAD acid. Treat interval 6850' - 7350' with 144 bbls of same. '`'`*Continued on 2/5/06 WSR*** Note: Program called for 12% Dad acid. 7.5% was loaded and brought to location. 2/5/2006 Acid treatment. CTU #9. Continued from 2/4/06 WSR. Complete treating upper perfs of OB sands with 7.8% Dad acid. Over flush with 60 bbls of 2% KCL. POOH. FP coil and well with 60/40 meth. RDMO. Notify Pad op of well status and to POI. Note: Coil pressure was high for the 2nd half of job. Found debris in nozzle. '`**Job Complete*** 2/6/2006 Flush surface lines w/ 10 bbls diesel @ 100*. 2/16/2006 SS/I/0=500/1000/0 Acid Teatment. Pumped 5 bbls meoh, 15 bbls 12% HCL Acid, 5 bbls meoh, 10 bbls diesel, 5 bbls produced water, and 5 bbls meoh down SS tubing. Pumped at 0.75 bpm @ 1100 psi. Final WHP=900/1000/230 FLUIDS PUMPED BBLS 307 2% KCL 129 60/40 Meth 205 12% DAD acid 90:10 40 7.8% DAD acid 20 Diesel 701 TOTAL ~chlum~erger Alaska Data 8 Consulting Services 2525 Garnbell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .InE, t! r ,... n,. ...:,, ~~~11~~D JAi~ 2 4 2006 ,~ ~ 8t GSS ~GIiS• COiT11T115S6t~ti 1~.11C~Gf a~ NO. 3668 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. 01/23/06 D-1 U 10913021 LDL 06/02/05 1 Z-24 11183454 LDL 12!29/05 1 DS 13-22 10987560 INJECTION PROFILE 01/05/06 1 G-11A (REDO) 11084277 RST-SIGMA 07/12/05 1 W-17A 10987549 USIT-PDCL 09/20/05 1 02-178 10928646 MCNL 09/13105 1 1 MPS-10A p~QGj~ ~a~ 11076475 SCMT 10/17/05 1 W-17A 10913044 USIT 09/03105 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, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . _ Received b/y l • • ~ ~ ~ ~~~- gas i~C?iA_NICAL INTEGRITY REPORT BUD D'.;~ : IOI~-OS" OPER ~ FIELD 1~~~ ~'t.1~~h~c ~©`~t~.~` :..G r5~~~..~. tO~~o`~S i;~LL Nt1i~IDER ~P`'~-~~ .~ t LL DAT ~_ TD : 15~.?~.. y~ ~ 'I'VD ; ?BTD : ~~S`1d ?~ ~aOS "i'VD ~~ Ces i^ ~ : Shoe : Co~aSr t-9~ t-la~0 TVD ; DJ : W R ?~ ~J'p. Tti~i --:,e.. ~~'~ ~ Shoe . ~,45'l~ '~ WaO~ T`TD ; '.GP . GO`13 ~.~ t-laO"1 ~" J v G, t l."~• co O~- ~ -moo'-='~ ;f45 Pacx.er 5~~~ '~ T~TD; Set et :ole Sice ~5 ra end ~ ~g ~ Perfs ~~~ to ~5`d~jU . ~~ R~ :.rCc~?~_C~-.T, INTEGRITY - ~a.RT #~ ~CS~~ 45'~`J~~..~ rnnulus Press Test• =~ 15 nin ~0 min Comments : :~'CHA?~ i Cc"1, INTEGRITY _ P~T #2 33~`~~ e o r e t i c a l T O C ~'. 3~Zc~ `l. S ~~ ,~. ~ c_ .~.~ ~`~,, r r~a~. ~ ~a ~s ~~'~ Cement Volumes: Amt. Liner bbt5 Cs~ t~b~S DV ~,~ C'YCC~~cu~~ vt~c~rocc,~t~ CWt -rol to cover aer=; 1~- pZ O~~ Q DJb~C~ 1," csS -- ~ 5 bb\ 5 '-1'!~` \~o..ec - 5 b'h\_5 ctc~.v~c,~c~ ~~ b~n~s CC~v~e•,.'~-~aror•..~~v~f ~oQ Cement Bond Log (Yes or No)_~.~; In AOGC~C~File CBL evaluation, zone above perfs ~~.~ ~ ~~n ~~ 6`~T U1 l ~ Production I.og: Type Evaluation t CONCLJS ~ Ot1S : ~ ?art #1 ?art T 2 : .~ ~ t (l3~ (o { - -- -- IBackup File -Folder Share Subject: IBackup File -Folder Share From: "Vestal, Sharmaine V (SAIL)" <Sharmaine.Vestal@bp.com> Date: Wed, 11 Jan 2006 15:21:37 -0900 To: tom maunder@admin.state.ak.us ***If you don't have PDSView then run the .exe before opening the USIT log.*** Let me know if you receive the data. Thanks, Sharmaine This is an email sent from IBackup on behalf of the sender.lt may contain links to the files/folders that the sender chose to share with you. Here are the links: 1. File: MPS-10A USIT 17OCT05 PRINT.PDS Secure Link: hops://www2.ibackup.comJgmanager/servletlshare?key=pkddv02850 2. File: PDSView30.exe Secure Link: https://www2.ibackup.comlgmanager/servlet/share?key=reibw42325 1 of 1 1/13/2006 3:54 PM Re: MPS-l0A • • Subject: Re: MPS-l0A From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 11 Jan 2006 11:14:54 -0900 To: "Mathews, William L" <Wiiliam.Mathews@bp.com> CC: Howard Okland <howard_okland@admin.state.ak.us>, Steve Davies <steve davies@admin.state.ak.us> Bill, Further to my looking at the sundry and this well's file, I realized that I need to do the "isolation assessment" since it is an injection well. We do have the completion report, however it does not appear that we have any logging information. We have directional surveys, but nothing regarding formation or cement evaluation. A colleague and I have checked material that is still awaiting filing and we didn't find anything for MPS-10A. Would you please look into this?? Thanks, Tom Maunder, PE AOGCC Mathews, William L wrote, On 1/11/2006 10:49 AM: Thanks Tom. We'll get it corrected. Hope you had a great Christmas and New Year Bill Sr. Production Engineer Milne Point Viscous Developments (907) 564-5476 office (907) 440-8496 cell -----Original Message----- From: Thomas Maunder [mailto January 11, 2006 10:41 AM To: Mathews, William L Subject: MPS-l0A Hi Bill, I only sent this to you since I don't have the other's eddresses. Just looking at the paperwork for the planned acid job(s). On the drawing that was included, the well name is listed as MPS-10i. MPS-l0i was P&Aed in October when MPS-lOAi was drilled. All the other information was correct for MPS-lOAi. Just helps keep everything straight. Best wishes for the new year. Tom Maunder, PE AOGCC tom maunder@admin.state.ak.us] Sent: Wednesday, 1 of 1 1/11/2006 12:56 PM William Matthews Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point, MPS- l0A Sundry Number: 306-009 Dear Mr. Matthews: FRANK M. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this f! day of January, 2006 Encl. _- ~.~..~ 06 RECEfVED STATE OF ALASKA ~, ,~ ALA OIL AND GAS CONSERVATION COMMI N \ " AN 1 ZOO6 APPLICATION FOR SUNDRY APPROVAL ~ rl ~ 20 AAC 25.280 Alaska 0d ons. Corrxnission 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ~~ p~a~ther Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate Q Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-1250V/ 3. Address: P.O. Box 196612 Stratigraphic ^ Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-23152-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.3 KB MPS-10A 8. Property Designation: 10. Field/Pools(s): ADL-380110 Milne Point Field / Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8915 4201.12 8828 4209.04 None None Casing Length Size MD ND Burst Collapse Conductor 80 20" X 34^ 215.5# A53 32 112 32 112 Surtace 2745 9-5/8" 40# L-80 31 2776 31 2475 5750 3090 Production 6195 7" 26# L-80 30 6225 30 4210 7240 5410 Liner 2842 4-1/2" 12.6# L-80 6073 8915 4207.13 4201 8430 7500 Pertoration Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5730 - 5830 4146.37 - 4170.71 Shortstring 2-3/8" 4.7# L-80 30 - 5643 6850 - 7350 4199.07 - 4189.89 Longstring 2-3/8" 4.7# L-80 30 - 6073 8250 - 8550 4209.02 - 4220.1 Packers and SSSV Type: 2-3/8" Baker GT Dual Packer Packers and SSSV MD (ft): 5620 5" Baker ZXP Top Packer 6085 12. Attachments: Descriptive Summary of Proposal 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: 1/24/2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact William L Mathews Printed Name ~" illiam athe Title petroleum Engineer Signature Phone 564-5476 Date 1/10/2006 COMM{SS{ON USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ~~~ "~ Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ Other: 3.5~ ~ psi w~tir\ ~ ~v ~ ~© ~7 ~S 1- . 1~~~~ ~A"~; al~~ F~. ~ 2OQ~ Subsequent Form Required: APPROVED BY / Approved b . COMMISSIONER THE COMMISSION Date: / / ~~~// V `~ ~ ~ Form 10-403 Revised 7/2005 ~ ~ ~ ~ ~ ~;~ ~ r i~ Submit in Duplicate • • by ~~. ~.~ ~Z: :~~ i~~•~;,~ To: D. Cismoski / J. Bixby, GPB Well Ops TL Date: Jan 5, 2006 From: Jessica Pedota, Wells Engineer Edited by J. Julian and B. Mathews Subject: MPS-10i DAD Acid Stim w/1.5" Coiled Tubing Est. Cost: $60M AFE: MSSPDWL10 IOR: 250 BOPD Attached is a CT acid stimulation job that includes the following major steps: 1 C Acid stimulation requires 1-1/2" CT, doesn't re uire test se arator Current Status: Injecting Injection rates: Short string (SS) 565 bwpd at 760 psi WHIP (01/05/06) Long string (LS) 842 bwpd at 909 psi WHIP (01/05/06) Max Deviation: 59 degrees @ 2,770' in SS 95 degrees @ 8,915' in LS Min. ID: 1.791" No-Go @ 5,630' in SS 1.791" No-Go @ 6,062' in LS Last deep TD tag: 5,638' SLM in SS 10/27/05 w/1.75" 5,824' SLM in LS 10/27/05 w/1.75" Last Downhole Ops: 10/27/05 SBHPS H2S Level N/A MPU S-10i is a dual completion injector. The well was sidetracked on 10/20/05 to reposition the OA sand injection point place a lateral into the OB sand. The sands were shot overbalanced with no flow back to clean up the perforations. As a result, injectivity is low. In order to increase injectivity, a CT acid stim is requested on both the long string (OB) and the short string (OA). This is not intended to be a full-bown matrix stimulation, but rather is designed to treat residual CaCO3 from drilling. If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (W), 274-0929 (H), 240-8037 (C) or Jessica Pedota at 830-2377 (C). cc: w/a: Well File B. Mathews J. Pedota • Stimulation Target Long String bottom perfs 8,250'-8,550' Long String top perfs 6,850'-7,350' Footage: 800' Wellbore Volume: 68 bbl Current injection rate in long string is 842 BWPD at 909 psi. Short String perFs: 5,730'-5,830' Total Footage: 100' Wellbore Volume: 23 bbl SS Current injection rate in long string is 565 BWPD at 760 psi. Wellbore Volume: 68 bbl LS and 23 bbl SS Acid design: 12 gpf 12% 90:10 DAD acid Fluid Requirements: 258 bbl of 90:10 DAD acid 350 bbl 2% KCI (no friction reducer) at least 110 F DAD Acid Stimulation -LONG STRING ~i RU 1.5" CT on the long string with a slim BHA w/ side jetting nozzle. The No-Go has an ID of 1.791" at 6,062' in the long string. 2. SI well at lateral and wing valves. 3. Load well with +/- 100 bbl 2% KCI both down the backside and down the CT at maximum rate at max pressure of 1000 psi while running in hole. Objective is to displace injected water from the Wellbore. Monitor the IA pressure during treatment. MIT IA passed to 2000 psi on 11/7/05. 4. While slowly reciprocating across pert interval, wash perforations with acid followed by KCI. Report pump rate, CT, and WHP at least every 10-20 bbls. Attempt to keep treating WHP below 1000 psi by controlling pump rate. However, this pressure may be exceeded to a maximum of 1500 psi if necessary to get reasonable treatment rates (>0.75 bpm). Current injection rate in long string is 842 BWPD at 909 psi (.58 bpm) a. Reciprocate 86 bbl of 12% 90:10 DAD acid across 8,250'-8,550'. Please shut down fora 15 minute soak period after first complete pass with acid. Continue acid wash. Flush perfs with 10 bbls 2% KCI. b. PUH and reciprocate 143 bbl of 12% 90:10 DAD acid across 6,850'-7,350'. Please shut down fora 15 minutes soak period after first complete pass with acid. Continue acid wash. Flush all perfs in the long string with 60 bbls 2% KCI. Do not POOH until the total overflush volume is behind pipe. Please note the initial and final infectivity in the WSR summary. • 5. POOH. If possible put long string on injection immediately to flush acid precipitates away from wellbore. DAD Acid Stimulation -SHORT STRING 1. RU 1.5" CT on the short string with same BHA. The No-Go has an ID of 1.791" at 5,630' in the short string. 2. SI well at lateral and wing valves. 3. Load well with +/- 35 bbl 2% KCI both down the backside and down the CT at max rate possible at 1000 psi max pressure. Objective is to displace injected water from the wellbore. 4. Wash perforations with acid followed by KCI. Report pump rate, CT, and WHP at least every 10-20 bbls. Attempt to keep treating WHP below 1000 psi by controlling pump rate. However, this pressure may be exceeded to a maximum of 1500 psi if necessary to get reasonable treatment rates (>0.75 bpm). Current injection rate in short string is 565 BWPD at 760 psi (.39 bpm) a. Reciprocate 29 bbl of 12% 90:10 DAD acid across 5,730'-5,830'. Please shut down fora 15 minute soak period after first complete pass with acid. Continue acid wash. Flush perforations with 24 bbl 2% KCI. b. Do not POOH until the total overflush volume is behind pipe. 5. POOH. Put both strings on injection immediately to flush acid precipitates away from wellbore. Please note the initial and final injectivity in the WSR summary. Check acid additive packages for BHST of 77°F and 12 hour protection time for L-80. Acceptable acid concentrations +/-1 % for HCI. Fluids should be 90-110 F. Total Fluid 90:10 DAD Acid 258 bbl 2% KCL* 292 bbl 90:10 DAD acid additives Corrosion A261 Inhibitor 0.6% 65 gal Corrosion A153 Inhibitor 8 87 Ibs Corrosion A179 Inhibitor 4 43 Ibs U74 Dispersant 1.5°1° 163 gal W54 NonEmulsifier 0.5% 54 gal W60 Anti-Sludge 0.5% 54 gal F103 Surfactant 0.2% 22 gal L58 Iron Stabilizer 20 217 Ibs (*KCI volume here does not include injectivity tests or displacing coil volume) Tree: CIW 2 1/16" 5M Dual strir~ Wellhead:l1" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112` V 1 Orig. KB Elev. = 73.05 ~ ~+~ Orig. GL Elev. = 38.90 '~t~s -10 ~~, ~~I .~~ ~lt 9-5/8" 40 #/ft, L-80 BTC 2,776' 2,996' 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 400' Max. hole angle = 59 deg @ 2770' Hole angle thru perfs = 56 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,610' 2-3/8" HES X-Nipple (1.875" pkg. bore) 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,994' NOTE :Well sidetracked 10/20/05 Kick-off @ 2839' and 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,806' 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,620' 1.945"ID. 5,630' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,643` Tubing tail / WLEG ~ 6,138' 7" Halliburton Float Collar PBTD 6,225' 7" Halliburton float shoe Perforation Summary Size Spf Interval (TVD) 3 3/8" 6 OA sands 5,730' - 5,830' OB d 4,146' - 4,170' 2 7/8" 6 san s 6,850` - 7,350' 4,199` - 4,189' 2 7/8" 6 8,250' - 8,550' 4,209' - 4,220' Guns : 3406PJ, HMX, 60 deg. phase 2906PJ, HMX, 60 deg, phase DATE REV. BY 06!22(02 MDO 06/11/03 MDO 10/20/05 MDO ` 2-3/8" HES XN-Nipple (1.875" pkg. bore) 6,062` No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub 6,068` (2.00" pkg, bore) No-Go Locator sub @ 6,082' 7" Tie Back Sleeve 6,095` 7"x 5" HRD ZXP Liner pkr. 6,085' 7"x 5" HMC Liner Hng. 6,073' 4.5" Baker Landing Collar g,g2g~ 4.5" HES Float Collar 8,870' 4.5" HES Float 8,915' COMMENTS Drilled by Cased Doyon 141 Completion Rig Doyon 14 Sidetrack 8, Completion Doyon - 14 MILNE POINT UNIT WELL No.: S-10i API : 50-029-20152-00 BP EXPLORATION (AK) STATE OF ALASKA ~C"Eq~C~ ALASKA OIL AND GAS CONSERVATION COMION NOV 2 1 2005 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Qi! & Gas Cons. Corranission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 zoAACZS.~io ^ 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. 10/20/2005 12. Permit to Drill Number 205-125 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/9/2005 a 13. API Number 50- 029-23152-01-00 4a. Location of Well (Governmental Section): Surfacer ' ' 7. Date T.D. Reached 10/15/2005 ~ 14. Well Name and Number: MPS-10Ai FEL, SEC. 12, T12N, R10E, UM 3342 FSL, 64 Top of Productive Horizon: 3815' FSL, 2073' FEL, SEC. 07, T12N, R11 E, UM 8. KB Elevation (tt): 73.30 15. Field /Pool(s): Milne Point Unit / Schrader Bluff Total Depth: 751' FSL, 2566' FEL, SEC. 07, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 8870 + 4205 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565946 y- 6000010' Zone- ASP4 10. Total Depth (MD+TVD) ~ 8915 + 4201 Ft 16. Property Designation: ADL 380110 TPI: x- 568712 y- 6000509 Zone- ASP4 Total Depth: x- 568258 ~ Y- 5997441 f Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: ------------------- ----------------- --------- ff h f f P t Thi k 20 18. Directional Survey ®Yes ^ No ore 19. Water depth, if o s N/A MSL ness o erma ros c . 1800' (Approx.) 21. LOgs Run: ~1i~ MWD , GR , RES , DIR , IFR/CASANDRA , SCMT , CCL , NEU/DEN ,L -7 ~4 r~DJ Z~{'7S ~T'/r~ .~ ,/. ~~ z 2. CASING, LINER AND CEMENTING RECORD CASING IN(3 EPTH MD NO EPTH TVD HOLE UNT SIZE WT. PER FT. GRADE OP TTOM OP` T1'OM SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 112' Surface 112' 42" 60 sx Arctic Set A rox. 9-5/8" 40# L-80 34' 2776' 34' 2475' 12-1/4" 10 sx PF'L', 225 sx Class 'G' 7" 12.6# L-80 32' 6225' 32' 4210' 8-3/4" 87 sx Class 'G', 4-1/2" 9.2# L-80 6073' 8870' 4207' 4201' 6-1/8" 39 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. T UBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 SPF 2-7/8" Gun Diameter, 6 SPF 2-3/8", 4.6#, L-80 (Long) 6115' 5620' MD TVD MD TVD 2-3/8", 4.7#, L-80 (Short) 5643' 5620' OA Sands OA Sands OB Sands B San S 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5730' - 5830' 4146' - 4171' 6850' - 7350' 4199' - 4190' ' ' ' ' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED - 4220 8250 - 8550 4209 Freeze Protect (Long) with 9.5 Bbls of Diesel Freeze Protrect (Short) with 9.5 Bbls of Diesel 26. PRODUCTION TEST Date First Production: November 1, 2005 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 ~~~ ~L ('JUV ~ 8 2005 ~ ~ y_~~ Form 10-407 Revised 12/2003 ; x "T ~ ,N ~U DON REVERSE SIDE y `~,~ ~ i I 1 28' GEOLOGIC MARKERS 29' JRMATION 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". TUZC 4613' 3551' None TMA 4947' 3764' TMBi 4981' 3785' TMB2 5085' 3847' TNA 5354' 3996' TNB 5405' 4023' TNC 5473' 4055' THE 5502' 4067' TNF 5630' 411 T Top of OA Sands 5725' 4145' BOA 5841' 4173' Top of OB Sands 6009' 4203' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Son Stewma Title Technical Assistant Date ~''- °~ MPS-10Ai 205-125 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Dave Johnson, 564-4171 ~ NSTRUCTIONS 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 lo~nr low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. heM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. frets 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 f 0-407 Revised 12/2003 Submit Original Only Tree: CIW 2 1/16" 5M Dual str M P U S 10A Wellhead:11" x 2 3!8" 5M FMC string Hanger thread 2 3/8" EUE top and IBT bottom 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112' 9-5/8" 40 #/ft, L-80 BTC 2,776` 2,996' 2-318" HES X-Nipple (1.875" pkg. bore) KOP @ 400` Max. hole angle = 59 deg @ 2770` Hole angle thru perfs = 56 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-318", 4.7 #!ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,610' 2-3/8" HES X-Nipple (1.875" pkg. bore) l 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,620` 1.945" ID. 5,630' 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" 5,643' Tubing tail / WLEG ~ 6,138` 7" Halliburton Float Collar PBTD 6,225' 7" Halliburton float shoe Pertoration Summary Size Spf {nterval (TVD) OA sands 3 3/8" 6 5,730' - 5,830' 4,146' - 4,170' 2 7/8" 6 OB sands 6,850' - 7,350' 4,199' - 4,189' 2 7/8" 6 8,250' - 8,550' 4,209` - 4,220' Guns : 3406PJ, HMX, 60 deg. phase 2906PJ, HMX, 60 deg, phase DATE REV. BY 06/22/02 MDO 06/11/03 MDO 10/20/05 MDO • Orig. KB Elev. = 73.05 Orig. GL Elev. = 38.90 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,994' NOTE :Well sidetracked 10/20/05 Kick-off @ 2839` and 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,806' ~, 2-3/8" HES XN-Nipple (1.875" pkg. bore) 6,062' No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub " 6,068` pkg. bore) (2.00 No-Go Locator sub @ 6,082' " 6 095' Tie Back Sleeve 7 , 7"x 5" HRD ZXP Liner pkr. 6,085' 7"x 5" HMC Liner Hng. 6,073' 4.5" Baker Landing Collar 4.5" HES Float Collar 4.5" HES Float COMMENTS Drilled by Cased Doyon 141 Completion Rig Doyon 14 Sidetrack & Completion Doyon - 14 8, 828' 8,870' 8,915` MILNE POINT UNIT WELL No.: S-10i, API : 50-029 20152'1 l`~L BP EXPLORATION (AK) 06:00 - 08:00 2.00 MOB P 08:00 - 10:00 2.00 MOB P Operations Summary Report Legal Well Name: MPS-10 Common Well Name: MPS-10 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~ From - To ~I Hours ~~~ Task ~, Code ~~ I 10/3/2005 10/4/2005 BP EXPLORATION Start: 10/4/2005 Rig Release: 10/20/2005 Rig Number: 14 NPT Phase PRE PRE 10:00 - 14:30 I 4.501 MOB I P I I PRE 14:30 - 16:00 1.50 MOB P PRE 16:00 - 18:00 2.00 MOB P PRE 18:00 - 20:30 2.50 MOB P PRE 20:30 - 21:30 1.00 RIGU P PRE 21:30 - 00:00 2.50 RIGU P PRE 00:00 - Oi:00 1.00 KILL P DECOMP 01:00 - 02:30 1.50 WHSUR P DECOMP 02:30 - 03:00 0.50 EVAL P DECOMP 03:00 - 04:30 1.50 CLEAN P DECOMP 04:30 - 05:00 0.50 RIGD P DECOMP 05:00 - 08:00 3.00 EVAL P DECOMP 08:00 - 09:00 1.00 BOPSU P DECOMP 09:00 - 11:30 2.50 BOPSU P DECOMP 11:30 - 13:00 1.50 BOPSU P DECOMP 13:00 - 14:00 1.00 RIGU P DECOMP 14:00 - 18:00 4.00 EVAL P DECOMP 18:00 - 22:00 4.00 BOPSU P DECOMP 22:00 - 23:30 1.50 EVAL P DECOMP 23:30 - 00:00 0.50 BOPSU P DECOMP 10/5/2005 00:00 - 10:00 10.00 BOPSU P DECOMP 10:00 - t i:00 1.00 BOPSU P DECOMP 11:00 - 13:00 2.00 PULL P DECOMP 13:00 - 14:30 1.50 PULL P DECOMP 14:30 - 15:00 0.50 PULL P DECOMP 15:00 - 18:00 3.00 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 21:30 3.00 PULL N DPRB DECOMP 21:30 - 22:00 0.50 PULL N DPRB DECOMP 22:00 - 23:00 1.00 PULL N DPRB DECOMP 23:00 - 00:00 1.00 PULL N DPRB DECOMP 10/6/2005 00:00 - 01:00 1.00 PULL N DPRB DECOMP 01:00 - 01:30 0.50 PULL P DECOMP Page 1 of 7 Spud Date: 5/25/2003 End: Description of Operations Remove front and back boosters -Install front stairs Install BOP stack in cellar -Install adapter flange /riser -Rack back on stand Lay Herculite mats on well MPS-10 -Install mouse hole -cellar heaters -cellar doors Position rig to crab move down pad Install conveyor -Repair jack cylinder Move rig to slot MPS-10 -Spot over well Lay mats / hercuilte Skid rig floor from move position to drlg position - RU service lines -Choke -Spot rock washer and berm - RU pits -prepare to take on water -Accept rig @ 00:00 hrs Rig up Annulus to Slop tank Rig up Lubricator -Pull BPV - On both sides with DSM - No psi on tubing or annulus Test line to slop tank and Long side of tubing to 1500 psi Displace with water on long side tubing - 4 bpm ~ 1450 psi - Change hose to short side -Test line to 1500 psi -Displace with water on short side 4 bpm @ 1400 psi -Shut down check pressure -well static Rig down circulating lines - Install TWC in long side /short side -Test to 3000 psi on both strings ND Tree NU up BOP's Change top VBR rams (2 7/8" X 5") to 2 3/8" Dual Rams R.U. flowline, fill up line etc. Install 2 3/8" test joint -Attempt to test annnular -Test failed - LD test joint - RD flowline PJSM -Change out 13 5/8" annnular element RU flowline, fillup line - PU test joint -Test equipment Test Annular to 250 low - 2500 hgih -Test good Testing BOP's -Dual Rams -Choke manifold - HCR Kill / Choke -Manual Kill /Choke - 2 3/8" Floor valves -Dart valves - 250 low - 3000 high 5 mins each test -Choke man. valve # 9 & manual choke on ROPE failed -Rebuild & re-test same - OK - Witness of test waived by AOGCC rep Lou Grimauldi. - WSL witnessed all BOP and related tests RD test equip. RU GBR equipment to pull 2 3/8" dual hanger. PJSM - MU landing joints -Attempt pulling dual hanger w/ no success -pull single single string hanger to floor (long side) - LD hanger RD dual equipment - RU "YC" elevators & slips LD 2 3/8" 4.6# IBT tubing -recovered 105 jts. + cut jt. (15.32' ). MU landing jt. to hanger. RU pump in sub Circ. well -wait on hot water.- (water temp 50 degrees surface - water down hole 47 degrees) Pump 100 bbls 90 degree water PJSM - RU Schlumberger /Chem. cutter R1H w/ Chem, cutter -Spot cutter & cut tubing at 3277'. POH w/ wireline - RD same RU to pull 2 3/8" tubing Printed: 10/21/2005 1:39:14 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPS-10 MPS-10 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To I Hours - I - Task I Code NPT 10/6/2005 ~ 01:30 - 05:00 ~ 3.50 ~ PULL ~ P 05:00 - 05:30 0.50 PULL P 05:30 - 06:00 0.50 PULL P 06:00 - 08:30 2.50 BOPSU P 08:30 - 11:00 2.50 BOPSU N RREP 11:00 - 12:00 I 1.001 PULL I N f RREP 16:00 - 16:30 0.50 BOPSU~P RREP 16:30 - 17:00 0,50 PULL P 17:00 - 18:00 1.00 PULL P 18:00 - 20:30 2.50 PULL P 20:30 - 22:00 1.50 PULL P 22:00 - 23:00 1.00 PULL P 23:00 - 23:30 0.50 PULL P 23:30 - 00:00 0.50 PULL P 10/7/2005 00:00 - 01:00 1.00 PULL P 01:00 - 01:30 0.50 PULL P 01:30 - 02:30 I 1.001 PULL I P 02:30 - 03:30 1.00 PULL P 03:30 - 04:00 0.50 PULL P 04:00 - 05:30 1.50 PULL P 05:30 - 06:30 1.00 PULL P 06:30 - 07:00 0.50 PULL P 07:00 - 08:30 1.50 PULL P 08:30 - 09:30 1.00 PULL P 09:30 - 10:30 1.00 PULL P 10:30 - 11:30 ! 1.001 PULL I P 11:30 - 12:00 ( 0.50 ~ PULL ~ P 12:00 - 12:30 I 0.501 PULL I P 12:30 - 13:00 I 0.501 PULL I P Page 2 of 7 Spud Date: 5/25/2003 Start: 10/4/2005 End: Rig Release: 10/20/2005 Rig Number: 14 Phase ' Description of Operations _~_ _ DECOMP Pull hanger to floor - LD same - PU weight 60k - LD 2 3/8" tubing (short side) -Recovered 103 jts. & cut jt (26.76'). DECOMP RD tubing tools -Clear floor DECOMP Install test plug DECOMP Change dual rams to 2 7/8" X 5" VBR rams - RU to test BOP's DECOMP Test BOP's -Open annulus valves -Test Top rams -Lower rams -Lower IBOP -Floor safety valve - 250 low - 3000 high for 5 mins each test -Upper IBOP valve failed and upper door seal failed -All test were witnessed by WSL DECOMP Pull test joint - RD testing equipment -Close annulus valves - Prepare to replace Upper IBOP valve DECOMP PJSM -Change out upper IBOP valve -Saver sub DECOMP Install test joint - RU testing equipment -Open annulus valves - Retest Upper IBOP valve 250 low - 3000 high - 5mins each test - Test was witnessed by WSL - RD Testing equipment -Pull test plug -Install wear ring -Close annulus valves DECOMP Clear rig floor - Moblize BHA - RU Bales -Elevators DECOMP MU BHA -Bit 6 1/8" -Scraper 7" 26# - XO DECOMP RIH 1 X 1 -Tag tubing stub 3276' DP measurement DECOMP Circulate Duo-Vis Sweep - surface to surface - 9 BPM @ 950 psi DECOMP POH from 3276' to BHA DECOMP LD BHA - MU BHA # 2 - Howco EZ Dril DECOMP RIH on 4" DP to 967' DECOMP RIH f/ 967 to 3193 - PU wt. 90 - SO 85 DECOMP Spot EZSV top at 3193. Rotate 35 turns right. PU & shear off EZSV w/ 40k overpull. Set back down 20k to ensure set. Set back 1 stand DECOMP RU test equip -Test casing to to 3000 psi f/ 30 min - OK - RD & blow down lines DECOMP POH DECOMP LD running tool - PU Mutli string cutter dressed for 7" 26# casing. DECOMP RIH -Spot cutter knives at 3110' DECOMP Cut 7" casing at 3110' - 70 RPM - TO 2K - 4,5 bpm @ 690 - Increase SPM to 60 = 6 bpm @ 360 -Close Annular on DP - Pump down 7" casg with outside annulus open to confirm cut - Did not see any pressure on annulus but appear that we were pumping into the formation DECOMP CBU 5.5 bpm @ 500 psi DECOMP POH DECOMP RU to displace down outer annulus DECOMP Pump down casg with blinds closed -Taking returns out annulus to slop tank -Stage up pressure up from 500 psi to 1500 psi would not bleed off - No returns out annulus DECOMP Switch hoses -Pump down annulus - 2000 psi to break circulation - No returns out casg -Establish circulation rate 1 bpm @ 460 psi DECOMP Pump down casg 3700 psi to break circulation -Establish circulation rate 2.8 bpm @ 470 psi -pumped 20 bbls - DECOMP Pump down annulus @ 1.6 bpm @ 430 psi -increase to 7 bpm @ 1480 psi -Pump 113 bbls - No returns out casg DECOMP Attempt pump down casg -Pressure up to 4000 psi - No Printed: 10/21/2005 1:39:14 PM • BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: MPS-10 Common W ell Name: MPS-10 Spud Date: 5/25/2003 Event Nam e: REENTE R+COM PLET E Start : 10/4/2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 10/20/2005 Rig Name: DOYON 14 Rig Number: 14 Date '' From - To Hours Task Code NPT Phase Description of Operations 10/7/2005 12:30 - 13:00 0.50 PULL P DECOMP injection rate or circulation rate could be established 13:00 - 14:00 1.00 PULL P DECOMP Wait on orders 14:00 - 16:00 2.00 PULL P DECOMP MU Baker 7" casg cutter -RIH to 3030' -Could not pass 3030' 16:00 - 16:30 0.50 PULL P DECOMP Break Circulation -Spot 18 ppg pill 16:30 - 17:30 1.00 PULL P DECOMP Locate casg collar Q 2844' -Cut casg C 2839 17:30 - 20:00 2.50 PULL P DECOMP PJSM -Close annular -Pump down casg taking returns out outer annulus to slop tank - 4 bpm @ 160 psi -Circulate 350 bbls -Monitor well 30 mins -Well static 20:00 - 21:30 1.50 PULL P DECOMP POH with BAker 7" casg cutter - LD cutting assy 21:30 - 22:00 0.50 PULL P DECOMP Pull wear ring 22:00 - 22:30 0.50 PULL P DECOMP Pull 7" pack-off 22:30 - 00:00 1.50 PULL P DECOMP MU Baker spear assy -RIH spear 7" casg -Pull free ~ 325K 210k over ). 10/8/2005 00:00 - 01:00 1.00 PULL P DECOMP ND BOPE - PU stack & remove emergency slips. 01:00 - 02:30 1.50 PULL P DECOMP NU BOPE 02:30 - 03:00 0.50 PULL P DECOMP RU casing equip. -Pull 7" to rig floor. 03:00 - 06:30 3.50 PULL P DECOMP LD 7" 26# Butt. casing 06:30 - 07:00 0.50 PULL P ~ DECOMP LD Casg tools 07:00 - 08:00 1.00 BOPSU P DECOMP Install test plug -Rig up test equipment -Test casg head flange -Choke hose flange 250 low - 3000 high - 5 mins each test - RD test equipment -Pull test plug -Install wear ring 08:00 - 09:00 1.00 STKOH P INTi Break down Baker spear - LD same 09:00 - 10:30 1.50 STKOH P INTi TIH with mule shoe to 3030' -Could not pass 3030' 10:30 - 11:00 0.50 STKOH P INT1 CBU - 360 GPM @440 psi -Pump 15 bbl 18 ppg pill @ 120 GPM - 100 psi -Chase pill with 20 bbls C~ 360 GPM -140 psi - PU90-S085 11:00 - 11:30 0.50 STKOH P INT1 POH from 3030' to 2400' 11:30 - 12:30 1.00 STKOH P INT1 Circ / Cond mud @ 340 GPM - 350 psi 12:30 - 13:00 0.50 STKOH P INT1 RIH from 2400 to 3000' - RU cementing lines 13:00 - 14:30 1.50 STKOH P INT1 PJSM -Break circulation through choke -Pump 5 bbls water - Test lines to 2500 psi -Pump 23.4 bbls water - 47.7 bbls 17 ppg Class "G" slurry - Dlsplace with 19.8 bbls water - TOC 2290' 14:30 - 15:30 1.00 STKOH P INT1 POH slow 8 stands to 2230' 15:30 - 17:00 1.50 STKOH P INT1 Perform hesitation sgeeze - 1.4 bbls C~3 500 psi -Holding 450 psi f/ 5 min. 17:00 - 17:30 0.50 INTi Pump nut plug sweep Surface To Surface 17:30 - 19:00 1.50 STKOH P INT1 POH -Monitor well f/ losses -Static 19:00 - 19:30 0.50 STKOH P INT1 RIH w/ 8 stds 4" DP 19:30 - 20:30 1.00 STKOH P INT1 POH LD 4° DP 20:30 - 00:00 3.50 STKOH P INTi RIH PU 4" DP - POH stand back in derrick 10/9/2005 00:00 - 03:30 3.50 STKOH P INT1 PU singles 4" DP- POH stand back in derrick 03:30 - 04:30 1.00 STKOH P INTi Cut drlg line -Service Top Drive /Rig 04:30 - 05:00 0.50 STKOH P INTi Moblize 8 3/4" Directional BHA 05:00 - 07:30 2.50 STKOH P INT1 MU BHA -Surface test BHA GPM 458 - PP 1100 psi 07:30 - 08:00 0.50 STKOH P INTi RIH to 2232' 08:00 - 12:00 4.00 STKOH P INTi Wash /Ream from 2232' to 2776' -Started getting firm cement - C~3 2350' - WOB 20 to 30 -GPM _ ~ 12:00 - 15:00 3.00 STKOH P INTi Directional Drill -Side tract hole C«~ 2776' to 2851' v ~-' 15:00 - 15:30 0.50 STKOH P r'rl -L INT1 PJSM -Displace hole with 8.6 bland mud 15:30 - 16:00 0.50 STKOH P INT1 POH from 2851' to 2634' 16:00 - 17:00 1.00 EVAL P ~ INTi Rig up test equipment -Perform FIT - MD 2815 - TVD 2499 - MW 8.6 -Surface pressure 247 = EMW 10.5 - RD testing Printed: 10/21/2005 1:39:14 PM • BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: MPS-10 Common W ell Name: MPS-10 Spud Date: 5/25/2003 Event Nam e: REENTE R+COM PLET E Start : 10/4/2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 10/20/2005 Rig Name: DOYON 14 Rig Number: 14 Date ~ From - To Hours ' Task ~ Code ', NPT Phase Description of Operations 10/9/2005 16:00 - 17:00 1.00 EVAL P ~ INTi equipment -Blow down 17:00 - 17:30 0.50 STKOH P INT1 RIH -Orient -Slide to 2851 17:30 - 00:00 6.50 DRILL P INT1 Directional Drill from 2851' to 3498' - WOB 10 to 15k -RPM 60 -TO on 4k-off 4k-GPM518-PPon1920-off1760-PU 125k - SO 90k -ROT 105k -ECD 9.66 -Clean hole ECD 9.1 Rot., 9.0 sliding. 10/10/2005 00:00 - 10:30 10.50 DRILL P INTi Dir. Drill f/ 3498 to 4553' - WOB 15 to 20 -RPM 60 - TO on 6 - off 7 -GPM 550 - PP on 2000 -off 1790 - PU 142 - So 85 - ROT 106 -ECD 9.8 10:30 - 11:30 1.00 DRILL P INT1 CBU 2x -Rotate & reciprocate DP. 550 gpm 2000 psi - 60 rpm -PU142-S085-ROT 106 11:30 - 15:00 3.50 DRILL P INT1 Pump out of hole @ drilling rate C~ GPM 550 -Mad Pass from 3040' to 2740' @ 350 ft per hour 15:00 - 15:30 0.50 DRILL N RREP INTi Repair Rig -Pump up compensator on Top Drive 15:30 - 16:00 0.50 DRILL P INT1 Rig service -Top Drive service 16:00 - 17:00 1.00 DRILL P INT1 RIH from 2400' to 4553' -Precautionary wash last stand to bottom 17:00 - 00:00 7.00 DRILL P INT1 Directional Drill from 4553' to 5223' - WOB 10 to 15 -RPM 60 - TOon5-off7-GPM550-PPon2200-off 2270-PU 175- S090-ROT115-ECD 9.68 10/11/2005 00:00 - 18:30 18.50 DRILL P INT1 Directional drilling f/ 5223' - 6239' (8 3/4" TD) - PU 175k SO 90k ROT 115k - PP on 2700 off 2500 - Tq on 7500 - Tq off 9000 - ECD - 10.16 18:30 - 20:00 1.50 CASE P INT1 Cond. mud &CBU 2x 520 gpm 2500 psi. 20:00 - 22:00 2.00 CASE P INT1 Pump out w/ full drlg. rate to last trip depth - 4553'. Monitor well. 22:00 - 22:30 0.50 CASE P INT1 RIH to 6239' -Wash last stand to bottom. 22:30 - 00:00 1.50 CASE P INT1 CBU 3x -Rotate & reciprocate pipe 60 rpm - 520 gpm 2650 psi. 10/12/2005 00:00 - 00:30 0.50 CASE P INT1 CBU 3x -Rotate & reciprocate pipe 60 rpm - 520 gpm 2650 psi. 00:30 - 03:30 3.00 CASE P INT1 Pumping out with full drilling rate to csg shoe @ 2776' 03:30 - 04:30 1.00 CASE P INTi Circulate hole clean -Flow check - OK 04:30 - 05:30 1.00 CASE P INT1 POH to BHA 05:30 - 07:30 2.00 CASE P INTi Laying down 5" HWT. & BHA 07:30 - 09:00 1.50 CASE P INTi Pull wear ring -install test plug -Change rams to 7" 09:00 - 09:30 0.50 CASE P INTi Test door seals to 1500 psi f/ 5 min. -Pull test plug. 09:30 - 10:30 1.00 CASE P INT1 PJSM - RU to run 7" 26# L-80 BTC-M casing. 10:30 - 14:30 4.00 CASE P INTi Run 7" casing to 2755' (11' above 9 5/8" shoe ) 14:30 - 15:30 1.00 CASE P INT1 Condition mud &circ. casing volume. 15:30 - 19:30 4.00 CASE P INT1 Continue run casing to 6225', total jts run 149 -Break circ. every 1000'. 19:30 - 21:00 1.50 CASE P INT1 RD Franks fill up tool - MU cement head -Break circ. & circulate 2 casing voume while reciprocating pipe - PU 275K - SO - 110K - PP - 500psi @ 252 gpm. 21:00 - 22:00 1.00 CEMT P INT1 Line up Schumberger -Pump 5 bbls. water -Test lines to 4000 psi -Pump 10 bbls. CW-100 - 40 bbls. 10.5 ppg Mud Push Spacer -Bottom plug -Pump 82.7 bbls. 15.8 ppg class "G" cement w/ 2% D600G + .2% D047 + .3% D065 + .4% S001 - Cement was mixed and pumped @ 5 bbls min. Drop top plug - kick out w/ 30 bbls fresh water. 22:00 - 22:30 0.50 CEMT P INTi Displace cement w/9.3 ppg mud @ 6 bbls min, reciprocating CSG thru out job, full returns thu job, bump plug with 2500 psi, Printed: 10/21/2005 1:39:14 PM BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: MPS-10 Common Well Name: MPS-10 Spud Date: 5/25/2003 Event Name: REENTER+COMPLETE Start: 10/4/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 10/20/2005 Rig Name: DOYON 14 Rig Number: 14 Date From - To I Hours Task 'Code ~~ NPT ~ Phase I. Description of Operations _ __ 10/12/2005 22:00 - 22:30 0.50 CEMT P 22:30 - 00:00 1.50 CASE P 10/13/2005 00:00 - 01:00 1.00 CASE P 01:00 - 02:00 1.00 CASE P 02:00 - 02:30 0.50 CASE P 02:30 - 04:30 2.00 CASE P 04:30 - 07:00 I 2.501 CASE I P 07:00 - 07:30 0.50 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 11:00 3.00 CASE P 11:00 - 11:30 0.50 CASE P 11:30 - 16:00 4.50 CASE P 16:00 - 18:00 2.00 CASE P 18:00 - 20:00 2.00 CEMT P 20:00 - 21:00 1.00 CASE P 21:00 - 22:00 1.00 DRILL P 22:00 - 00:00 I 2.001 DRILL I P 10/14/2005 00:00 - 10:00 10.00 DRILL P 10:00 - 11:00 1.00 DRILL P 11:00 - 12:00 1.00 DRILL N 12:00 - 14:00 2.00 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 00:00 9.50 DRILL P 10/15/2005 100:00 - 12:30 I 12.501 DRILL I P 12:30 - 13:30 1.00 CASE P 13:30 - 16:00 2.50 CASE P 16:00 - 17:00 1.00 CASE P 17:00 - 19:00 2.00 CASE P 19:00 - 22:00 3.00 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 ; 1.00 CASE P 10/16/2005 00:00 - 01:00 1.00 CASE P 01:00 - 03:30 I 2.50 CASE P 03:30 - 04:30 1.00 CASE P 04:30 - 08:30 4.00 CASE P 08:30 - 09:00 0.50 CASE P 09:00 - 10:30. 1.50 CASE P INTi held for ten min., check floats held, last pickup wt 275K, last slackoff 70K INT1 Rig down cement head, rig and blowed out landing jt, for cut off INT1 ND BOPE INT1 Install emerg. slips - PU 250k on casing -Set slips & slack off & cut off w/ Watts casing cutter. INT1 Install 9 5/8" x 7" packoff INTi NU BOPE - attemped to test packoff, leaking @ API ring on flange, INT1 Nipple down BOPS, to check API ring, change out same,Nipple up BOPS INT1 Test Packoff 4500 psi for 10 min. INT1 Rig up to test BOPS INTi Test BOPS and Manifold with 250-3000 psi for 5 min. per test, Hydril 250-2500 psi for 5 min. per test, the right to witness test was wavier by John Spaulding AOOGC, test was witness by WSL INTi Pull test plug and install wear ring INTi Mobilize BHA, picking up BHA #2, pluse test MWD tool INTi Rih to 6189' INTi Wash and drill Float collar @ 6138 and shoe track and shoe @ 6225, wash to bottom and drill 20 ft of new hole to 6259' INT1 Circ and displace hole with new 8.9 LSD mud PROD1 Pull in to csg and Perform FIT test with 8.9 mud, 4209 TVD, 680 psi, =12 # Emwt PROD1 Drill 6259' to 6377' with 320 gpm, 2400 psi, 80 rpms, 8K bit wt. TQ 7K, AST ,64 ART .22 PROD1 Drill 6377' to 7145' with 320 gpm, 2400 psi, 80 rpms, 8K bit wt. PRODi Pull to csg shoe @ 6225' without pump RREP PROD1 Rig repair, change out saver sub on top drive PROD1 Circ. PRODi Rih PROD1 Drill 7145' to 8007' with 275 gpm, 2200 psi, 80 rpms, 8K bit wt., AST 2.52, ART 8.31, TO 4K PROD1 Drill 8,008' to 8,915' with 275 gpm, PP on 2480 off 2340 -PU 120k - SO 80k -ROT - 100k - 80 rpms, 8K bit wt.- Tq on 4k off 3k. Drill out of sand @ 7955', back in sand @ 8220' RUNPRD CBU, Three bottoms up with 275 gpm, 2300 psi, 80 rpms RUNPRD Pump out to 7" shoe @ 6225 with full drilling rate. RUNPRD Rih, wash last stand to bottom RUNPRD Circ, Three bottoms up with 80 rpms, 275 gpm, 2300 psi RUNPRD Pump out to 7" shoe @ 6,225' with full drilling rate. RUNPRD Circ, bottoms up @ 6,225', flow check well, pump slug RUNPRD POH RUNPRD POHtoBHA RUNPRD Laying down BHA, remove sources, download MWD,Iay down MWD,Motor,bit RUNPRD Clear floor, Rig up to pickup liner, count csg, function blinds RUNPRD Picking up liner 67 jts 4.5 12.6 L-80 and Baker HMC liner hanger, Baker HRD ZXP liner top packer, running tools RUNPRD Circ. one liner vol, 3 bbls min. 250 psi, p/u 82k, s/o 77k RUNPRD Trip in hole with liner to 6224' Printed: 10/21/2005 1:39:14 PM • BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: MPS-10 Common W ell Name: MPS-10 Spud Date: 5/25/2003 Event Nam e: REENTE R+COM PLET E Start : 10/4/2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 10/20/2005 Rig Name: DOYON 14 Rig Number: 14 Date I From - To I Hours ' Task Code NPT l Phase ~ Description of Operations 10/16/2005 10:30 - 11:00 0.50 - _ CASE P __ RUNPRD _ ___ - - ---._ Circ one liner and drill pipe vol. 3 bbls min, 540 psi, p/u 122k, s/o 95k 11:00 - 12:00 1.00 CASE P RUNPRD Trip in with liner to 8910', no problems 12:00 - 13:00 1.00 CASE P RUNPRD Circ. and cond. mud for cement job, 30 spm, 650 psi, P/U 125K, S/O 83K 13:00 - 16:30 3.50 CEMT P RUNPRD PJSM, cement with Schlumberger, with 5 bbls, water, test lines to 4,000, Pump 10 bbls Cw100, 30 bbls 10.5 mud push, 72.5 bbls, 339 sx.Class G, 15.8, 1.2 yield, drop plug, washed out lines with 5 bbls pert. pill, displace with 40 bbls 9.0 vis pill, 10 bbls water, 56 bbls 9.0 mud, bump plug with 2700 psi, pumped and displace @ 5bbls min. reciprocate pine thru out job, 16:30 - 17:00 0.50 CASE P RUNPRD Set hanger, unsling with 1000 psi, lay down cement head., Liner shoe @ 8915, float 8870, landing collar 8828, seal bore extension 6,102', tie back 6,073, 12 bbls cement to surface 17:00 - 19:00 2.00 CASE P RUNPRD Displace well, with 20 bbls high vis pill, 70 bbls sea water, 30 bbls high vis pill, 500 bbls sea water, 19:00 - 20:30 1.50 CASE P RUNPRD PJSM, Slip and cut drilling line, service rig and topdrive 20:30 - 00:00 3.50 CASE P RUNPRD POH and laying down excess pipe 10/17/2005 00:00 - 00:30 0.50 CASE P ..RUNPRD Laying down excess pipe, Baker running tools 00:30 - 14:00 13.50 EVAL P i LOWERI Clear floor, Rig up E-line unit, Running GR/USIT/CCL from top of liner @ 6,073' to top of cement @ 4000', rig down loggers 14:00 - 15:00 1.00 PERFO P LOWERI Testing csg and liner with 2500 psi for 30, test witness by WSL, PJSM on picking up pert. guns 15:00 - 21:00 6.00 PERFO P LOWERI Picking up 2 7/8 pac pipe and 2 7/8 TCP and 3 1/4 guns 21:00 - 23:00 2.00 PERFO P LOWERI Tripping in with guns to 8,550' 23:00 - 00:00 1.00 PERFO P LOWERI Rig up schlumberger logger and verify guns on depth, pip tag @ 5307.2' 10/18/2005 00:00 - 02:30 2.50 EVAL P LOWERi Logging with to verify guns on depth, pip tag @ 5307.2' 02:30 - 03:00 0.50 PERFO P LOWERI Rig up to pert. pipe, PJSM on firing guns 03:00 - 03:30 0.50 PERFO P LOWERI Pressure up on drill pipe to 2500 psi held for 8 min., bleed off, open bag, guns fired in order in about 10 min., well static, pert (5730-5830. 6850-7350, 8250-8550) 03:30 - 04:30 1.00 PERFO P LOWERI Pull guns above liner @ 6073 04:30 - 05:30 1.00 PERFO P LOWERI Circ bottoms up 05:30 - 06:30 1.00 PERFO P LOWERI Tripping out with guns 06:30 - 13:30 7.00 PERFO P LOWERI Laying down guns and 2 7/8 pac pipe 13:30 - 17:00 3.50 PERFO P LOWERI Picking up stinger, 13 jts 2 7!8 pac pipe and 7" scraper run in hole to 6,141', scraper to 5,729' 17:00 - 18:00 1.00 PERFO P LOWERI Circ, hi- vis sweep, clean sea water, circ bottoms up 18:00 - 22:00 4.00 PERFO P LOWERI . Trip out with stinger and csg scraper, lay down same 22:00 - 22:30 0.50 PERFO P LOWERI Pull wear ring 22:30 - 23:30 1.00 BUNCO RUNCMP Pickup landing jts and make dummy run with hangers, mark jts. 23:30 - 00:00 0.50 BUNCO RUNCMP Change top rams to 2 3/8 duals 10/19/2005 00:00 - 01:30 1.50 BUNCO RUNCMP Change out rams 01:30 - 03:00 1.50 BUNCO RUNCMP Test Dual rams 250-3000 5 mins. per test, Lou Grimaldi waiver the right to witness test, test witness by WSL 03:00 - 04:30 1.50 BUNCO RUNCMP Change out bails, rig up to run dual tubing, count pipe 04:30 - 22:00 17.50 BUNCO RUNCMP Picking up 2 3/8 tubing 4.6# L-80 Dual string with Baker GT packer total 188 jts long string, 175 jts short string, P/U 105k, S/o 75K 22:00 - 00:00 2.00 BUNCO RUNCMP Land, long string no go in tie back sleeve, rig up to pump, pickup and verfify seals was going in 16 ft., space out to land ~ tubing. Printed: 10/21/2005 1:39:14 PM • BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: MPS-10 Common Well Name: MPS-10 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date i From - To I Hours ; Task ' Code I NPT j- _ ~ _ _I 10/20/2005 00:00 - 01:30 1.50 01:30 - 02:30 1.00 02:30 - 03:00 0.50 03:00 - 03:30 0.50 03:30 - 04:30 I 1.00 04:30 - 06:30 I 2.00 06:30 - 07:30 1.00 07:30 - 08:30 1.00 08:30 - 09:30 1.00 09:30 - 11:00 1.50 11:00 - 15:30 ~ 4.50 15:30 - 16:30 I 1.00 16:30 - 17:00 I 0.50 Spud Date: 5/25/2003 Start: 10/4/2005 End: Rig Release: 10!20!2005 Rig Number: 14 Phase Description of Operations RUNCMP Space out, pickup Dual hangers, land tubing RUNCMP Run in LD on hanger,clear floor on tools RUNCMP PJSM, rig up Circ lines on landing jts and annulus RUNCMP Circ down annulus, retums up short string with clean sea water and corrosion inhibitor 90 bbls, 2 bbls min 550 psi RUNCMP Test lines 4500 psi, pump 69 bbls down annulus with Hot oil pump truck, 1 bbls min. 400 psi starting pressure, 750 psi final, taking returns up short string. RUNCMP Drop 1 1/2 ball down long string, bull head to seat with 1 bbl min. 750 psi, with 12 bbls sea water, let pressure bleed down to 450 psi, set packer with 3200 psi, Held pressure on long string tubing for 30 mins, annulus pressure 200 psi RUNCMP Test annulus with hot oil 3500 psi for 30 min. good test RUNCMP Drop ball on short string, bull head ball to seat with 19 bbls 1 bbl min. 670 psi, test short string 3000 psi for 30 min. good test RUNCMP .Lay down landing jts, install TWC, test to 1000 psi from the top RUNCMP Nipple down BOPs RUNCMP Nipple up CIW 2.0625 Dual tree, test hanger to 5000 psi, test tree to 5000 psi.,pull TWC, Install BPV RUNCMP Rig up Hot oil on tree and shear ball on long string with 3900 psi and freeze protect long string tubing with 9.5 bbls desel 1.5 bbls min 1000 psi, rig up on short string and shear ball with 3500 psi and freeze protect short string with 9.5 bbls diesel 1.5 bbls min. 900 psi RUNCMP Secure well, rig release @ 1700 hrs 10/20/2005 Printed: 10!21/2005 1'.39'.14 PM Printed: 10/21/2005 1:39:05 PM Halliburton Sperry-Sun Milne Point Unit BPXA MPS-10A Job No. AKZZ3978051, Surveyed: 15 October, 2005 Survey Report 8 November, 2005 Your Ref: API 500292315201 Surface Coordinates: 6000010.04 N, 565946.43E (70° 24' 37.6785" N, 149° 27' 46.8455" IM Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 73.30ff above Mean Sea Level ~~~~-~~~~ ~~R~~~~~ Survey Ref:svy1549 A Hxliiburtan Corrtpany r: • Halliburton Sperry-Sun Survey Report for MPS-10A Your Ref.' API 500292315201 Job No, AKZZ3978051, Surveyed: 15 October, 2005 BP EXPLORATION (ALASKA) INC. Milne Poinf Unit BPX,4 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) 2726.49 49.110 84.890 2369.25 2442,55 219.73 S 917.67E 5999798.42 N 566866.01 E -219.73 Tie On Point MWD+IIFR+MS+SAG 2776.00 49.580 84.730 2401.50 2474.80 ~~ 216.33 S 955.08E 5999802.15 N 566903.38E 0.980 -216.33 Window Point ., 2850.30 50.660 78.340 2449.17 2522.47 207.92 S 1011.42E 5999811.05 N 566959.64E 6.756 -207.92 2948.56 50.280 76.170 2511.72 2585.02 191.21 S 1085.33E 5999828.42 N 567033.41E 1.747 -191.21 3042.13 51.000 72.520 2571.07 2644.37 171.68 S 1154.97E 5999848.56 N 567102.87E 3.112 -171.68 3140.51 51.520 63.510 2632.71 2706.01 142.99 S 1225.98E 5999877.88 N 567173.63E 7.160 -142.99 3237.04 50.440 61.010 2693.49 2766.79 108.10 S 1292.36E 5999913.36 N 567239.69E 2.302 -108.10 3333.67 49.080 56.900 2755.93 2829.23 70.10 S 1355.54E 5999951.92 N 567302.54E 3.538 -70.10 3429.21 49.980 51.670 2817.96 2891.26 27.68 S 1414.50E 5999994.85 N 567361.12E 4.269 -27.68 3525.41 52.110 51.780 2878.44 2951.74 18.66 N 1473.23E 6000041.71 N 567419.44E 2.216 18.66 3620.71 54.570 47.250 2935.36 3008.66 68.30 N 1531.31E 6000091.86 N 567477.08E 4.604 68.30 3716.90 57.390 41.300 2989.20 3062.50 125.39 N 1586.87E 6000149.43 N 567532.13E 5.904 125.39 3811.16 60.090 33.550 3038.16 3111.46 189.34 N 1635.72E 6000213.82 N 567580.41E 7.587 189.34 3909.33 62.780 29.210 3085.12 3158.42 262.94 N 1680.56E 6000287.81 N 567624.60E 4.752 262.94 4005.43 62.050 24.180 3129.64 3202.94 339.00 N 1718.82E 6000364.20 N 567662.18E 4.701 339.00 4101.72 61.490 22.870 3175.19 3248.49 416.78 N 1752.68E 6000442.28 N 567695.36E 1.332 416.78 4196.96 58.530 26.820 3222.80 3296.10 491.62 N 1787.28E 6000517.42 N 567729.30E 4.749 491.62 4293.18 54.490 33.860 3275.93 3349.23 560.85 N 1827.67E 6000587.01 N 567769.08E 7.404 560.85 4389.17 51.980 39.860 3333.41 3406.71 622.36 N 1873.71E 6000648.92 N 567814.57E 5.647 622.36 4485.19 49.580 47.050 3394.17 3467.47 676.35 N 1924.75E 6000703.36 N 567865.13E 6.314 676.35 4580.96 49.220 54.130 3456.54 3529.84 722.47 N 1980.86E 6000749.97 N 567920.83E 5:624 722.47 4675.28 48.970 61.660 3518.35 3591.65 760.31 N 2041.15E 6000788.35 N 567980.79E 6.038 760.31 4768.40 49.250 69.670 3579.37 3652.67 789.27 N 2105.20E 6000817.87 N 568044.58E 6.507 789.27 4867.27 51.740 78.500 3642.33 3715.63 810.05 N 2178.46E 6000839.29 N 568117.65E 7.332 810.05 4962.46 53.200 88.610 3700.41 3773.71 818.43 N 2253.30E 6000848.34 N 568192.42E 8.557 818.43 5059.66 53.560 96.440 3758.45 3831.75 814.99 N 2331.14E 6000845.58 N 568270.28E 6.474 814.99 5155.71 54.580 104.110 3814.87 3888.17 801.10 N 2407.56E 6000832.37 N 568346.82E 6.551 801.10 5251.44 57.080 111.890 3868.69 3941.99 776.58 N 2482.76E 6000808.51 N 568422.24E 7.211 776.58 5347.18 58.370 124.300 3919.95 3993.25 738.52 N 2553.92E 6000771.09 N 568493.73E 11.035 738.52 5443.52 62.230 135.760 3967.79 4041.09 684.72 N 2617.73E 6000717.85 N 568558.01E 11.075 684.72 • C J 8 November, 2005 - 9:12 Page 2 of 5 DrillQuest 3.03.06.008 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Depth (ft) 5539.85 5635.82 5731.61 5827.79 5924.55 5971.42 6020.15 6069.14 6116.63 6170.49 6235.56 6284.11 6331.91 6373.23 6424.75 Incl. 65.670 71.200 74.660 77.170 78.830 81.950 84.410 88.400 88.880 89.080 89.260 89.730 86.530 88.560 87.820 True Azim. 143.750 146.130 149.190 154.210 156.870 159.420 161.830 163.980 167.540 171.880 173.800 179.150 181.140 183.340 189.680 Sub-Sea Depth (ft) 4010.15 4045.41 4073.53 4096.95 4117.07 4124.90 4130.68 4133.76 4134.88 4135.84 4136.78 4137.21 4138.77 4140.54 4142.17 Vertical Depth (ft) 4083.45 4118.71 4146.83 4170.25 4190.37 4198.20 4203.98 4207.06 4208.18 4209.14 4210.08 4210.51 4212.07 4213.84 4215.47 6470.90 88 .620 193.800 4143.61 4216.91 6520.30 91 .820 196.200 4143.42 4216.72 6564.99 94 .350 198.920 4141.01 4214.31 6617.18 94 .100 198.350 4137.17 4210.47 6661.36 92 .620 198.760 4134.58 4207.88 6714.08 92 .500 198.600 4132.22 4205.52 6757.10 92 .660 198.090 4130.29 4203.59 6810.72 92 .690 198.520 4127.78 4201.08 6852.48 93 .120 197.650 4125.67 4198.97 6905.54 92 .810 197.960 4122.92 4196.22 6949.77 92 .870 198.050 4120.73 4194.03 7002.24 92 .070 196.780 4118.47 4191.77 7049.85 90 .590 196.980 4117.36 4190.66 7098.96 90 .780 197.090 4116.78 4190.08 7147.37 90 .530 195.710 4116.22 4189.52 7193.61 91 .020 195.530 4115.60 4188.90 7240.23 90 .710 195.240 4114.89 4188.19 7288.81 88 .750 195.230 4115.12 4188.42 7341.98 88 .480 195:480 4116:41 4189.71 7387.24 87 .800 195.520 4117.88 4191.18 Halliburton Sperry-Sun Survey Report for MPS-10A Your Ref.• API 500292315201 Job No. AKZZ3978051, Surveyed: 15 October, 2005 Local Coordinates Northings Eastings (ft) (ft) 618.69 N 2673.50 E 545.65 N 2724.71 E 468.29 N 2773.67 E 386.18 N 2817.85 E 300.04 N 2857.03 E 257.15 N 2874.23 E 211.51 N 2890.27 E 164.79 N 2904.64 E 118.78 N 2916.32 E 65.81 N 2925.93 E 1.26 N 2934.04 E 47.18 S 2937.03 E 94.95 S 2936.91 E 136.19 S 2935.29 E 187.33 S 2929.46 E Global Coordinates Northings Eastings (ft) (ft) 6000652.31 N 568614 .36 E 6000579.72 N 568666 .22 E 6000502.80 N 568715 .85 E 6000421.08 N 568760 .76 E 6000335.29 N 568800 .70 E 6000292.56 N 568818 .27 E 6000247.06 N 568834 .72 E 6000200.47 N 568849 .50 E 6000154.57 N 568861 .58 E 6000101.68 N 568871. 67 E 6000037.20 N 568880. 35 E 5999988.79 N 568883 .76 E 5999941.03 N 568884. 06 E 5999899.77 N 568882 .81 E 5999848.58 N 568877. 43 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 8.260 618.69 6.206 545.65 4.730 468.29 5.695 386.18 3.190 300.04 8.549 7.042 9.247 7.562 8.065 2.963 11.062 7.882 7.241 12.383 257.15 211.51 164.79 118.78 65.81 1.26 -47.18 -94.95 -136.19 -187.33 232. 48 S 2920.07E 5999803 .35 N 568868.44E 9.090 -232.48 280. 19 S 2907.29E 5999755 .53 N 568856.08E 8.097 -280.19 322. 73 S 2893.83E 5999712 .88 N 568843.00E 8.305 -322.73 372. 05 S 2877.20E 5999663 .41 N 568826.80E 1.190 -372.05 413. 86 S 2863.17E 5999621 .48 N 568813.14E 3.476 -413.86 463. 75 S 2846.30E 5999571 .44 N 568796.71E 0.379 -463.75 504. 54 S 2832.77E 5999530 .53 N 568783.55E 1.241 -504.54 555. 39 S 2815.95E 5999479 .53 N 568767.17E 0.803 -555.39 595. 04 S 2803.00E 5999439 .77 N 568754.58E 2.322 -595.04 645. 49 S 2786.80E 5999389 .18 N 568738.82E 0.826 -645.49 687. 50 S 2773.14E 5999347 .05 N 568725.54E 0.244 -687.50 737. 52 S 2757.46E 5999296 .90 N 568710.29E 2.859 -737.52 783. 06 S 2743.64E 5999251 .23 N 568696.87E 3.137 -783.06 830. 02 S 2729.25E 5999204 .15 N 568682.90E 0.447 -830.02 876 .45 S 2715.58E 5999157 .60 N 568669.65E 2.897 -876.45 920. 98 S 2703.13E 5999112 .96 N 568657.59E 1.129 -920.98 965. 93 S 2690.77E 5999067 .91 N 568645.62E 0.911 -965.93 1012. 80 S 2678.00E 5999020 .93 N 568633.27E 4.035 -1012.80 1064. 05 S 2663.93E 5998969 .55 N 568619.65E 0.692 -1064.05 1107 .64 S 2651.84E 5998925 .86 N 568607.94E 1.505 -1107.64 • • 8 November, 2005 - 9:12 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPS-10A Your Ref: API 500292315201 Job No. AKZZ3978051, Surveyed: 15 October, 2005 BP EXPLORATION (ALASKA) INC. 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) (°I100ft) 7431.84 88.040 195.510 4119.50 4192.80 1150.59 S 2639.91E 5998882.81 N 568596.40E 0.539 -1150.59 7483.94 89.540 194.880 4120.60 4193.90 1200.85 S 2626.26E 5998832.42 N 568583.19E 3.123 -1200.85 7534.38 90.590 194.970 4120.54 4193.84 1249.59 S 2613.27E 5998783.57 N 568570.63E 2.089 -1249.59 7579.61 90.840 194.690 4119.97 4193.27 1293.31 S 2601.70E 5998739.75 N 568559.44E 0.830 -1293.31 7626.98 90.950 194.520 4119.23 4192.53 1339.15 S 2589.75E 5998693.81 N 568547.91E 0.427 -1339.15 7677.26 89.670 192.780 4118.96 4192.26 1388.00 S 2577.89E 5998644.85 N 568536.47E 4.296 -1388.00 7724.09 89.850 193.430 4119.16 4192.46 1433.61 S 2567.27E 5998599.15 N 568526.26E 1.440 -1433.61 7771.74 89.710 193.770 4119.34 4192.64 1479.93 S 2556.07E 5998552.74 N 568515.46E 0.772 -1479.93 7817.85 89.530 193.680 4119.65 4192.95 1524.72 S 2545.13E 5998507.85 N 568504.92E 0.436 -1524.72 7866.84 89.340 193.180 4120.13 4193.43 1572.37 S 2533.75E 5998460.11 N 568493.96E 1.092 -1572.37 7910.73 88.680 191.300 4120.89 4194.19 1615.25 S 2524.45E 5998417.14 N 568485.04E 4.539 -1615.25 7961.74 88.540 191.410 4122.13 4195.43 1665.25 S 2514.40E 5998367.06 N 568475.44E 0.349 -1665.25 8012.04 90.160 191.620 4122.70 4196.00 1714.53 S 2504.36E 5998317.69 N 568465.84E 3.248 -1714.53 8058.65 89.050 190.840 4123.02 4196.32 1760.24 S 2495.29E 5998271.90 N 568457.16E 2.911 -1760.24 8107.40 86.040 191.970 4125.11 4198.41 1807.98 S 2485.66E 5998224.08 N 568447.96E 6.594 -1807.98 8155.14 85.940 191.830 4128.44 4201.74 1854.58 S 2475.84E 5998177.39 N 568438.55E 0.360 -1854.58 8199.14 85.360 191.540 4131.78 4205.08 1897.55 S 2466.95E 5998134.35 N 568430.04E 1.473 -1897.55 8249.95 85.670 191.570 4135.76 4209.06 1947.17 S 2456.81E 5998084.64 N 568420.33E 0.613 -1947.17 8295.98 86.690 192.360 4138.82 4212.12 1992.10 S 2447.28E 5998039.62 N 568411.21E 2.801 -1992.10 8346.72 88.370 193.390 4141.01 4214.31 2041.52 S 2435.99E 5997990.11 N 568400.35E 3.883 -2041.52 8395.98 89.290 193.990 4142.01 4215.31 2089.37 S 2424.33E 5997942.16 N 568389.12E 2.230 -2089.37 8443.10 87.700 194.550 4143.25 4216.55 2135.02 S 2412.72E 5997896.41 N 568377.91E 3.577 -2135.02 8490.96 88.170 194.870 4144.98 4218.28 2181.28 S 2400.58E 5997850.04 N 568366.17E 1.188 -2181.28 8537.49 88.250 195.950 4146.43 4219.73 2226.11 S 2388.22E 5997805.10 N 568354.21E 2.326 -2226.11 8589.56 87.520 196.020 4148.35 4221.65 2276.13 S 2373.89E 5997754.96 N 568340.33E 1.408 -2276.13 8634.42 91.130 195.930 4148.88 4222.18 2319.25 S 2361.55E 5997711.73 N 568328.36E 8.050 -2319.25 8679.23 93.180 195.930 4147.19 4220.49 2362.31 S 2349.26E 5997668.57 N 568316.46E 4.575 -2362.31 8730.26 94.170 195.150 4143.92 4217.22 2411.37 S 2335.62E 5997619.39 N 568303.25E 2.468 -2411..37 8775.43 94.970 194.900 4140.33 4213.63 2454.86 S 2323.94E 5997575.80 N 568291.96E 1.855 -2454.86 8826.06 94.970 194.650 4135.94 4209.24 2503.63 S 2311.08E 5997526.91 N 568279.53E 0.492 -2503.63 BPXA • ~J 8868.96 95.290 194.730 4132.10 4205.40 2544.96 S 2300.24E 5997485.49 N 568269.06E 0.769 -2544.96 8915.00 95.290 194.730 4127.86 4201.16 -- 2589.30 S 2288.59E 5997441.05 N 568257.79E 0.000 -2589.30 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State. Planes, Zone 4. 8 November, 2005 - 9:12 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for MPS-10A Your Ref: API 500292315201 Job No. AKZZ3978051, Surveyed: 15 October, 2005 BP EXPLORATION (ALASKA) INC. Milne Point Unit The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True) Based upon Minimum Curvature type calculations, at a Measured Depth of 8915.OOft., The Bottom Hole Displacement is 3455.73ft., in the Direction of 138.528° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 2726.49 2442.55 219.73 S 917.67E Tie On Point 2776.00 2474.80 216.33 S 955.08E Window Point 8915.00 4201.16 2589.30 S 2288.59E Projected Survey BPXA • Survey tool program for MPS-1OA From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 917.27 911.62 2726.49 2442.55 To Measured Vertical Depth Depth (ft) (ft) 917.27 911.62 2726.49 2442.55 8915.00 4201.16 Survey Tool Description BP High Accuracy Gyro (MPS-10,Gyro) MWD+IIFR+MS (MPS-10) MWD+IIFR+MS+SAG (MPS-10A) 8 November, 2005 - 9:12 Page 5 of 5 DrillQuest 3.03.06.008 • 16-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPS-10A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey 2,726.49' MD Window /Kickoff Survey: 2,776.00' MD (if applicable) Projected Survey: 8,915.00' 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: Cart Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~,~ ~Q.- ~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) I ~V J ~ 1 (~ ~~ ~~ ~( • • 16-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-10A MWD Dear Dear Sir/Madam: Enclosed is one disk with the .PTT and '~.PDF fifes. Tie-on Survey: 2,726.49' MD Window /Kickoff Survey: 2,776.00' MD (if applicable) Projected Survey: 8,915.00' 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 ,o~~ ~~.~ ~~Y ? Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) P MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 09, 2005 To: Jim Regg ~~t> r P1~~~~n5' P.I, Supervisor y ( SUBJECT: Mechanical Integrity Tests $P EXPLORATION (ALASKA) INC ~. S- I OA FROM: Chuck Scheve MILNE PT UNIT SB S-l0A ` „~. Petroleum Inspector ~" Src: Inspector Reviewed By: P.I. Suprv. 1~~ NON-CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S-l0A Insp Num: mitCS051107142124 Rel Insp Num API Well Number Permit Number: 50-029-23152-01-00 205-125-0 Inspector Name: Chuck Scheve Inspection Date: 11/7/2005 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well ~ s-IOA 'Type Inj. ~ w ~ TVD ~ an3 ~ IA Soo 2ozo zolo 2oto ~ i p T ~ zoslzso ~TypeTest ~ sPT Test psi ~ Iozs.zs ~ pA ', 2ao j zso ~ zso 2so ~ ~ Interval INITAL P/F P Tubing I goo j goo ~ goo goo j -;- Notes Wednesday, November 09, 2005 Page I of 1 i\v. i~u v-aV Juuuiy 1~V UL.4 JV/-t. [.V u1141v11 JAVA Llllllllb' 1 Gl 11111 ... Subject: Re: NFPS-lO Sundry Notice 3OS-228 and MPS-l0A DrillingYe1~11it.~€~~-~25 From: Thomas Maunder <torn_maunder~~z~adrnn.state_ak.us= Date: Fri; '(~ Auk ZOOS (i9: l ~:2~ -OSUO To: "Johnson, Da~~id A. (Fairwcathei-)" ~johnZ~<<i:BP.conw David, Testing the BOP to 3000 psi for the sundry work and actual drilling work is OK. Tom Maunder, PE AOGCC Thomas E Maunder wrote, On $/25/2005 8:06 PM: Hi Dave, Sorry about that. I changed it on the orginal and apparently not on the duplicate. I will have a look tomorrow and get back to you. Tom ----- Original Message ----- ', From: "Johnson, David A. (Fairweather)" <johr_23~BP.com> Date: Thursday, August 25, 2005 4:26 pm Subject: MPS-10 Sundry Notice 305-228 and MPS-l0A Drilling Permit 205- 125 Tom, On the approved Sundry Notice, the required BOP test is 5000 psi and on approved Permit to Drill it is 3000 psi. The two were sent together and on the Sundry Notice I failed to include the planned BOP test which was included in the drilling permit. When we rig up to pull the tubing strings can we test the BOPS to 3000 psi instead of 5000 psi? Maximum anticipated surface pressure is 1366 psi. The OA and OB sands will already be plugged with cement prior to rigging up. * Maximum anticipated BHP: Sand) * Maximum surface pressure: column of gas at 0.1 psi/ft) * Planned BOP test pressure: Dave 1775 psi at 4,090' TVDss (OA 1366 psi at (Based on a full 3,000 psi 1 of 1 8/26/2005 9:41 AM ~~ ALASSA OIL A11TD CrA-S COI~TSERQATIOIK COrII~i15SIO1R Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 909519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Milne Point MPS-10A BP Exploration (Alaska) Inc. Permit No: 205-125 Surface Location: 3342' FSL, 64' FEL, SEC. 12, T12N, R10E, UM Bottomhole Location: 751' FSL, 2582' FEL, SEC. 07, T 12N, R11 E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by Iaw 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 Commission to witness any required test. Contact the Commission' etrole eld inspector at (907) 659- 3607 (pager). ~ Chairman DATED this day of August, 2005 Orman cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t STATE OF ALASKA ~, ~ ~ ~~; ` ALASKA OIL AND GAS CONSERVATION COMIPf"~SIO PERMIT TO DRILL ~~~ ~ ~ ~~~~ ~`~~ 20 AAC 25.005 . a ~ „•~ „ ~, ,~ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^Developmen Ot~~il. ^ Stratigraphic Test ®Service ^Developmen +0 ~nglelZonee 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ^ Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: MPS-10A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8940 TVD 4218 ~ 12. Field /Pool(s): Milne Point Unit / Schrader Bluff 4a. Location of Well (Governmental Section): Surface: 3342' FSL 64' FEL SEC 12 T12N R10E UM 7. Property Designation: ADL 380110 , , . , , , Top of Productive Horizon: 3864' FSL, 2092' FEL, SEC. 07, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: 09/10/05 Total Depth: 751' FSL, 2582' FEL, SEC. 07, T12N, R11E, UM 9. Acres in Property: 2560 '~ 14. Distance to Nearest Property: 750' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565946 y- 6000010 Zone- ASP4 10. KB Elevation (Height above GL): 73.20' feet 15. Distance to Nearest Well Within Pool 130' away from MPS-10 16. Deviated Wells: Kickoff Depth: 287g~ feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1775 y' Surface: 1366 1 Casing Program: Size S pecifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-3/4" 7" 12.6# L-80 BTC-M 6053' Surface Surface 6053' ~ 4198' 358 sx Class 'G', 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3037' 5903' 4161' 8940' 4218' 357 sx Class 'G' 1?g. PRESENT WELL CONDITION SUMMARY{To be`completed for Redrill AND Re-entry'Operations) Total Depth MD (ft): 5441 Total Depth TVD (ft): 4338 Plugs (measured): N/A Effective Depth MD (ft): 5355 Effective Depth TVD (ft): 4274 Junk (measured): 5355 Casing Len th Size Cement Volume MD TVD 112' 20" 260 sx Arctic Set A rox. 112' 112' 2742' 9-5/8" 510 sc PF'L', 225 sx Class 'G' 2776' 2475' P ti 8' 7" 275 sx 5440' 4 << <~ ,~ `, a ~- - 3'~~r Perforation Depth MD (ft): 5170' - 5286' Perforation Depth TVD (ft): 4138' - 4223' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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 Dave Johnson, 564-4171 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5667 Date Sondra Stewman, 564-4750 Commission Use Only Permit To Drill y f Number. ~..~~5' _l Z,5 API Number: 50- 029-23152-01-00 Permit Approval. Date: ~ a ~ a s See cover letter for other requirements Conditions of Approval: Samples quired ^ Yes ~I No Mud Log Required ^ Yes ~ No Hy og ulfide Measures ^ Yes ~(j No Directional Survey Required ~ Yes ^ No Other: Z~(~ ~ CiS ~~r.t.,C~. ~ ~~ ~ CE-1"~~ ~/~ C.~~.~Gt~ai+~~ ~C~C~~ rc,~'tl.~O IBS ~ t~, G.C-~..~`J d~ ~ 1 ~c `~ ~ v~ • APPROVED BY A rov THE COMMISSION Date Form 10-401 F~ed(sed`A9f2004 ~~ (1 ~ t ('"~ ~ ~ f ~ubmif I~{ Duplicate by ~~~ ~u~ ~ ~ 2ao~ Milne Point Well MPS-10A Schrader OA/OB Dual Injector Drilling and Completion Plan Summary T e of Well: Schrader Bluff OA/OB Dual In'ector , Surface Location: 3,341' FSL and 64' FEL (AS Proposed) Section 12, T12N, R10E UM E = 565,943' N = 6,000,010' Top of OA 3,864' FSL and 2,092' FEL Section 7, T12N, R11 E UM E = 568,692' N = 6,000,558' Z = 4,133' TVD T1 -MID OB 3,540' FSL and 1,945' FEL Section 7, T12N, R11 E UM E = 568,844' N = 6,000,235' Z = 4,198' TVD T2 -MID OA 1,216' FSL and 2,460` FEL Section 7, T12N, R11 E UM E = 568,359' N = 5,997,906' Z = 4,228' TVD T3 -Mid OB (TD) 751' FSL and 2,582` FEL Section 7, T12N, R11 E UM E = 568,243' N = 5,997,440' Z = 4,218' TVD Distance to Pro a line 750' Distance to nearest well 130' from MPS-10 AFE Number: Ri Do on 14 Estimated Start Date: Se t 10, 2005 Ri da s to com lete: 14 TM D: g 940 ' TVD: 4,218 Max Inc: 91 ° ~ KOP: 2876' KBE: 73.2' Well Desi n: Ultra Slimhole Ob'ective: Schrader Bluff OA/OB Page 1 01~(G!~~AL • Mud Program: 8-3/4" Intermediate Hole (2.776' - 6.053'1: • LSND '~ Au u 1 ~ 2005 Densi PV YP H API Filtrate MBT 8.6-9.3 8-15 24-30 9.0-9.5 6-8 <2t;la~~ 6-1 /8" Production Hole (6.053' - 8.940'1 M~BM Oil ~ G~~ C~a~~. Co~~i~s9~~ C$;~¢.;~;.x~a.e Densi . PV YP H API Fittrate Chlorides MBT 8.9-9.2 18-15 20-28 9.0-9.5 5-7 <1500 <25 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. CasingRubing Program Hole Size Casing Size Wt/Ft Grade Conn Burst Collapse Top TMD Top TVD Bottom TMD Bottom TVD Length 42 20* 92 H-40 Weld 1530 520 0 0 112 112 112 12.25 9-5/8" 40.0 L-80 BTC 5750 3090 0 0 2776 2474 2776 8.75 7.0 26 L-80 BTC-M 7240 6600 0 0 6053 4198 6053 6.125 4-1/2 12.6 L-80 IBT-M 8430 7500 5903 4161 8940 4218 3037 2-3/8 4.6 L-80 TCII 11780 11200 0 0 5600 4098 5600 2-3/8 4.6 L-80 TCII 11780 11200 0 0 5908 4183 5908 * Pre-set Cement Program: Casin Size 7", 26#, L-80, BTC-M Intermediate Casin Basis Tail cement = 500' MD above the TUZC. 40% Excess over Gau a Hole Total Cement Volume: 74 bbl Wash 5-bbl water 10 bbl CW 100 S acer 40 bbl of MudPush Tail 74 bbl, 358 sx "G" mixed at 15.8 Ib/ al & 1.16 ft /sx Tem BHST ~80°F from SOR Casin Size 4-1/2", 12.6#, L-80, IBT-M Liner Basis Tail cement = 200' MD above the liner to 40% Excess over Gau a Hole Total Cement Volume: 35 bbl Wash 5-bbl water 10 bbl CW 100 S acer 30 bbl of MudPush Tail 76 bbl, 357 sx "G" mixed at 15.8 Ib/ al & 1.20 ft /sx Tem BHST =80°F from SOR Page 2 `''`'' , ' Evaluation Program: 8-3/4" Section AUG 4 Open Hole: . MWD/GR/RES/D!R ~: `' • :1`~ IFR/CASANDRA, ~i~~ka ilil ~ ~ • ~, - S er InSite ~ ' Cased Hole: . GR/SCMT/CCL 6-1/8" Section Open Hole: . MWD/GR/RES/DIR • NEU/DEN • IFR/CASANDRA, • S er InSite Cased Hole: ~, Formation Markers: Formation To s TMD ft TVDss ft BHP Pressure Surface Pressure Gradient si/ft EMW Ib/ al TUZC 4652 3475 1509 1161 0.434 8.35 U nu-MA 4965 3680 1598 1230 0.434 8.35 U nu-MB1 5004 3705 1609 1238 0.434 8.35 U nu-MB2 5107 3770 1637 1260 0.434 8.35 SBF2-NA 5349 3910 1698 1307 0.434 8.35 S B F1-N B 5388 3930 1249 -1665 848 - 1265 0.312 - 0.416 6.0 - 8.0 SBE4-NC 5470 3970 1724 1327 0.434 8.35 SBE2-NE 5492 3980 1728 1330 0.434 8.35 SBE1-NF 5613 4030 1750 1347 0.434 8.35 TSBD-To OA 5700 4060 1267-1763 861 - 1356 0.312 - 0.434 6. - 8.35 TSBC-Base OA 5809 4090 1276 - 1775 867 - 1366 0.312 -0.434 6. - 8.35 TSBB-To OB 5989 4120 1301 889 0.316 6.1 TD -Mid OB 8940 4150 1315 900 0.317 6.1 Recommended Bit Program: BHA ~ Hole Size Depth (TMD) Footage Bit Type T T TFA GPM 1 8-1/2 2,776' - 6,053' 3,727' Baker Hughes MX-1 .50-.70 500-600 2 6.125" 6,503' - 8,940' 2,887' Hycalog DSX-146 .45-.55 275-325 Page 3 • • ~~c~~~o~D Well ContCOt: AUG 1 1 ~OG5 Intermediate/Production hole: +Is~it~ ~ij ~~ ~;=: ~~~__• Com~miesr~n • Maximum anticipated BHP: 1775 psi at 4,090' TVDss (OA Sand) /~, ~~ ` ~.:~,~~ • Maximum surface pressure: ' 1366 psi at (Based on a full column of gas at 0.1 psi/ft) • Planned BOP test pressure: 3,000 psi • Integrity tests: FIT to 10.5 Ib/gal 20' below the 9-5/8" shoe. Kick tolerance: 48 BBIs with 9.4 Ib/gal mud at the 9-5/8" shoe. • Integrity tests: FIT to 11.5 Ib/gal 20' below the 7" shoe. • Planned completion fluid: Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: Lost Circulation • Lost Circulation is not reported as a major problem for S-Pad, however the NB, OA, and OB sands may be depleted to +/-6 ppg. Lost circulation may be experienced especially in the OB lateral. Good drilling practices need to be maintained and ECD's monitored. Expected Pressures • All Formation are expected to be normally pressured: 8.35 ppg or less. ` Pad Data Sheet • Please Read the S-Pad Data Sheet thoroughly. Hydrocarbons • Hydrocarbons are possible in the Ugnu & Schrader Bluff interval. Faults • Two (2) faults are mapped in the well. Fault #1 in the SV intermediate hole section at 3,050' TMD (2550' TVDss). This fault has been drilled numerous times without problems, including the MPS-10 original well. Fault #2 is in the OB Lateral production hole interval at 7,850' TMD (4150' TVDss). This fault has been drilled in the MPS-03, MPS-05 and MPS-10 without problems. Hydrogen Sulfide • MPS Pad is not designated as an H2S Pad, H2S detected from S-Pad wells on the pad: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level MPS-03 < 2 ppm Jun-05 #2 Closest SHL Well H2S Level MPS-05 < 2 ppm Jun-05 #3 Closest SHL Well H2S Level MPS-17 < 2 ppm Jun-OS Max. Recorded H2S on Pad/Facility MPS-19A < 2 ppm Jun-OS Anti-collision Issues • MPS-10A passes the Major Risk Criteria except for the MPS-10 original wellbore. This wellbore will be abandoned. Distance to Nearest Property • MPS-10A is planned to be 750 ft from the nearest Milne Point property line. `' Page 4 • Distance to Nearest Well Within Pool • • MPS-10A is 130 ft from the nearest sand penetration in the MPS-10.~ DRILL & COMPLETION PROCEDURE Pre-Rig Operations ~'~ ~AUG ~ ,~ R'Q~5 ~~ ~. ~.:..,v 1. Full-bore cement P&A both strings. Final cement volume should be determined by infectivity test. Minimum cement volume should be sufficient to cover perforations and leave TOC at +/- 4000' TMD. (Approximately 7 BBLS on short string and 10 BBLS on long string. 2. Run Wireline drift and tag TOC. Pressure test both strings. 3. Jet cut tubing strings at 3300' TMD. Circulate strings and IA. 4. Install BPV. Drillin 5. MIRU. NU BOPE and test. 6. Pull dual 2.375" completion from 3300' TMD. 7. PU DP. RIH w/ casing scraper to stubs. 3~S _ ~ ~~ " ' 8. RIH and set 7 bridge plug at ~ 3200 TMD. 9. Make mechanical cut at 3100' (below 9-5/8" shoe) in 7.0" casing. 10. Circulate out OA freeze protect, pull and lay down 7" casing. 11. RIH w/ open-ended DP and lay a 17.0 ppg cement plug from 7" stub to 100' inside 9-5/8" casing shoe (estimated at 40 BBLS). 12. Dress off cement and sidetrack well at 2876' TMD (100' below 9-5/8" casing shoe. 13. Drill 8.5" hole as per directional plan to a 6053' TMD/4198' TVD (Mid-OB sand) . 14. Run and cement 7.0" casing. 15. Drill 6-1/8" horizontal OB hole section to a TD of 8940' TMD/4218 TVD. ~~~ 16. ~ \ Run and cement 4-1/2" liner w/ liner lap in shale between OA/OB. 17. J~ RU E-line and run bond to s (injector). ~ ~c~p 18. ' Displace drilling mud to brine. ~` 19. Perforate horizontal well with TCP guns 20. Run dual completion, w/ PBR below tie-back as lower packer. 21. Land tubing hanger and test. Test IA. 22. Set BPV, ND BOP, instaN and test tree, pull BPV. 23. Freeze protect inner annulus. 24. Rig down. s ~~ ~~ ~ ? Page 5 _~.," '~. i ~ -- 22 - ~A 23 F~AD24 ~ -~. 19 20 21 I ~ , ~ ~, ~~.. ~ ~ ~ 1.~,. ~~,~ ^ 34 ,E ~ `d ~ ~ ~ ^ 33 -~. Fem.. 3 Tnr E PAD IN ^ 31 i I PLANT ~ ~ I - Z ~~ ~ ~ ~~~U~ ~ P 26 25 30 7E 29 28 ^ 29i 1g"QO 00° I ^ 27 I I GRID ~ r~;, ~ -`y,n ~ _ I ~_~I~AD 35 36 31 32 33 25 ~ ' T13N I ^ ^ 241 .. '. ' . ~ T12N K ^ 23 i 2 i s s a 3 ~ 2,i I MPS-20~19i MPU S-PAD I S- AD ii 12 ~ a s io ^17 I ^ 15i o W I ^ 13i LEGEND is 13 ~ ~ is n ~s 11 -~ AS-BUILT CONDUCTOR MPS-10-~ I VICINITY MAP ~~ gi ^ EXISTING CONDUCTOR N.T.S. I ~ ~ 6~ I ~ `\ . L SECt ~ - ~~ ^ ~ SECT ~ r'?N. Rio I I OF q ^ 1 T~2N ~E *0°49 0* ooeoooaooooo00000oooooeooaoasoo '~,"~, Jeffrey J. Cotton ~s ~ LS 8306 ,~ ~'`~'ES3101JAU ~' NOTES: 1. DATE OF SURVEY: JANUARY 4 & 10, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 06-11,14,15. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 10, 2003. LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-10 Y=6,000,010.04 N= 2,237.02 70'24'37.678" 70.4104661' 38 9' 3,342' FSL ' X= 565,946.43 E= 6,824.04 149'27'46.845" 149.4630125' FEL 64 MPS-20 Y=5,999,971.00 N= 2,236.88 70'24'37.307" ' " ' 70.4103631' ' 38'4 3,304' FSL ' X= 565,801.26 E= 6 673.70 149 27 51.111 149.4641975 FEL 209 CHECKED: v AIUSON 0 Q DATE: 01/12/03 DRAN7NG FRB03 MPS 02-00 ~j (g]rJg O(7 I\ \ \ II ~ ~ JOB NO: o U_ U l 'W J SCALE: ,~`~ ~ w 1'= 160' ~~ by MILNE POINT UNIT S-PAD AS-BUILT CONDUCTORS WELLS MPS-10 & MPS-20 .... - .. 5,,..,,. is SHEET: ~ OF 7 r. ~Ul~ ~. 1 200 BP EXPLORATION MPS-10A Field: Miine Point Horizonatl Scrader Bluff OA/OB ENG: D. Johnson Pad: S-Pad Injector RIG: Doyon 14 RKB: 73.2' DIR / LWD OH FORM DE PTH HOLE CASING t Sf C INFO MWD LOGS MD SIZE TVD SPECS emen urry Wellhead NONE NONE Permafrost 112' 20' Conductor FMC Ultra Slimhole NONE Surface Csa 9-5/8' Base Permafrost 1,909' 1,822' ': 401t>/ft L-S0, BTC - Int. Yield 5750 psi Test CSg to Collaspse 3090 psi 1000 Psi Drift - 8.679' Casing Point 2,776' 2,474 ~+ 50° Rw 12-1/4' KOP 2,876' 2,539' DIR/GR/RES NONE Inter. Casino Cement Slurrv IFR/CASANDRA 7' Tail 26.0 Ibs/ft 74 Bbls, 358 sx InSite L-80, BTC-M 15.8 ppg Int. Yield 7240 psi 1.16 ft3/sx Collaspse 6600 psi Drift • 6.151 ` GR/SCMT/CCI Required Top of Tail Cement 4,152' TUZC 4,652' 3,548' Top of NA 5,349' 3,983' Top of NB 5,388' 4,003' Top of NC. 5,470' 4,043' ;' Test Csg to Top of OA 5,700' 4,133' 1500 psi Top of OB 5,989' 4,193' Casing;Point 6,053' 4,t98' 87.4° - - 6-314' DIR/GR/RES NONE Neu/Den Prod. Liner Cement Slurrv IFR/CASANDRA 4.1/2• Tail InSite 12.6 Ibs/ft 76 Bbts, 357 sx L-80, IBT-Mod 15.8 ppg Int. Yield 8430 psi 1.20 ft3lsx Collaspse 7500 psi Drift - 3.833 Test Csg to 1500 psi 912° Casing Point :8,940' ..4.218' "' ,. r -. < , a0.My =: 6-a/8" 8/5/2005 MPS-10A WeN Plan Schematic.xis _ i .>..- Thee: CIW 2 1/16" 5M Dual string I~,S 10A VMeNhead~:11" x 2 3/8" 5M FMC dual string Orig. KB ~. = 73.05 Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev_ = 38.90 2" CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112' 9-5/8" 40 #/ft, L-80 BTC 2,776' sho +/-3000' 2-3/8" HES X-Nipple (1.875" pkg. bore) 2-3/8", 4.7 #/ft L-80, TCII tubing (drift id = 1.901, cap.=.00387 bpf) 5,980' 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,620' 2-3/8" HES XN-Nipple (1.875' pkg. bore) No-Go 1.791' 5640' Tubing tail / WLEG 5903' MD 7'x4-112' Liner Hanger w/ ZXP pkr. And PBR w/ seats 6053' MD 7° 2~, L-80, BTRC Casing (drift id = 6.151, cap = .0383 bpf) Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) +/-3000' 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,980' 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5600' 2-3/8" HES XN~lipple (1.875' pkg. bore) No-Go 1.791' 4-12' 12.61-80 IBT Liner (drift id = 3.875", cap = .0155 bpf) 8940' MD DATE REV. BY COMMENTS 8/4/2005 DAJ Proposed Completion MILNE POINT UNIT WELL No.: S-10A API BP EXPLORATION (A RECEIVED AUG 1 1 2005 Alaska Oil & Gas Cons. Commission Anchorage Tree: CIW 2 1/16" 5M Dual strin~ Wle~tead:ll" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and IBT bottom 2"CIW-H BPV profile 20" x 34" insulated, 215 #/ft A-53 112' 9-5/8" 40 #/ft, L-80 BTC 2,776' Short String 2996' 2-3/8" HES X-Nipple (1.875" pkg. KOP ~ d00' Max. hole angle = 59 deg @2770' Hlole angle tfiru perfs = 56 DEG. 7° 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #!ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 5,090' 2-3/8" HES X-Nipple (1.875" pkg. 5,141' 2-3/8" HES XN-Nipple (1.875" pkc No-Go 'I 5,147' Tubing tail /WLEG Perforation Summary Size Spf Interval (TVC 3 3/8" 6 OA sands 5170' - 5190' 4137' - 41 6 5198' - 5208' OB d 4158' - 41 i 3 3/8" 6 san s 5256' - 5286' 4200' - 42; Guns : HSD, 3406PJ, HMX, 60 deg. phase 5,355' 7" Halliburton Float Collar PBTD 5,440' 7" Halliburton float shoe Orig_ KB Elev = 73.05 Orig. GL Elev. = 38.90 RECEIV AUG 1 1 20~ Alaska Oil & Gas Cons. I °..._ ~~e Long String HES X-Nipple (1.875" pkg. bore) 2,995` HES X-Nipple (1.875" pkg. bore) 5,088' 3/8" Baker "GT" Ret. dual pkr. 5,132' ID. 3/8" Baker "FH" Ret. pkr. 5,216' D. HES XN-Nipple (1.875" pkg. bore) 5,227' No-Go 1.791" Baker'E' Hydro Trip Sub 5,231' ' pkg. bore) WLEG 5,237' ELMD '5" ball. DATE REV. BY COMMENTS Mlt_NE POINT UNIT 06/22/02 MDO Drilled by Cased Doyon 141 VYELL No.• S-10i 06/11/03 MDO Completion Rig Doyon 14 API : 50-029-23152-00 BP EXPLORATION (AK) MPU S-10i COMPANY DEfAIIS REFERENCE INFORMATION SI:RVEY PRIX7RAM Plan: MPS-IOA wp06 (MPS-IO/Plen MPS-IOA) aP Amoco CoaNivk (N/E) Ref :Well Crnac MPSIO, Tme NoM Vatiul(TVD)Ref e: 34 7+38 97310 DepM Fm Depth To Survry/Plen Tool Created B Di tal Business Client User Dale' 7/I R/2005 Y~ qi _ 1 ^^~aqq~~ ~IJ Calcutetian MNlnd: F System: Mvtmnvn Cwvsnae ISCWSA . . Sa'don (VS)Retemt¢: Sla- (OOON.O.OOE) Measm°d Deph Ref :31.7+38.9 73.20 287fi00 8910.21 PYvd: MPS IOA a7A6 V75 MWDHFR+MS Checked: Date: Sun Metlwd: Error Surtus: Tm ryb~ Notth Elliptld +Casmg Gkulauon Medved: M mmum CmsLioe Reviewed: Dare: Warning Mehod RWo Based WELL DETAILS ~ SECTION DETAILS ~ C Name +N~s .F~-w Nw~,s FyunR t,mwe t.on~awe sl°t Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target Z" ~ ~` S T, l\ ryf MPS-10 75.58 -79R1I 61100D10.04 565946.01 70°24'77.b78N 119'2T46.B45W t:/A 1 2876.00 50.01 84.71 2539.25 -209.30 1031.27 0.00 0.00 581.22 ~~ ~ ~ ~°"'{f G ~ TARGET DETAILS 2 2926.00 50.04 82.10 2571.37 -204.90 1069.33 4.00 -90.00 611.24 p.J ~ 3 3878.85 61.70 25.28 3136.11 251.17 1643.68 5.00 -94.19 1339.86 ,,,~,,~ ~ Name TVD +N/-S +E/-W Northing Easting Shape 4 4195.33 61.70 25.28 3286.13 503.14 1762.67 0.00 0.00 1602.17 ~ 5 6065.37 88.00 165.00 4198.20 200.00 2900.00 7.00 121.26 2192.03 MPS-IOA TI p `~®' MPS-IOA TI 4198.20 200.00 2900.00 6000235.62 568844.28 Point 6 6085.37 88.00 165.00 4198.90 180.69 2905.17 0.00 0.00 2182.04 Q '~{'°°"~ MPS-IOA T3 4218.20 -2590.00 2275.00 5997440.47 568243.99 Point 7 6413.16 89.39 194.48 4206.54 -143.39 2906.63 9.00 87.71 1953.90 (_711 MPS-IOA T2 4228.20 -2125.00 2395.00 5997906.47 568359.87 Point 8 8434.55 89.39 194.48 4228.15 -2100.49 2401.33 0.00 0.00 212.73 9 8459.87 90.40 194.48 4228.20 -2125.00 2395.00 4.00 0.17 190.92 MPS-IOA T2 t0 8480.12 91.21 194.47 4227.92 -2144.61 2389.94 4.00 -0.70 173.48 I 1 8940.21 91.21 194.47 4218.20 -2590.00 2275.00 0.00 0.00 -222.74 MPS-IOA T3 CASING DETAII.S No. TVD MD Name Size : '. ~ ; ~, ~ ~ ~ ~ ~ ~ I 4197.71 6053.00 7" 7.000 ' ~ i j , I , ~ 2 4218.20 8940.00 41/2" 4.500 24 - -- - ~ >~ ~ i ¢ t j /1Q0 j ' 2~ 7~I b1 b, I 39 i ,! , i ~ _ t 1 I - - ~ i i C ~ ~ , g - 32 -~- -- - ~- v 1 _. . -. . ... .. - .. .. _ _ii~EE 1200 1600 2000 2400 Vertical Section at 45.00° [400R/inJ 3200 COMPANY DEf AfIS REFERENCE INFORMATION SURVEY PROGRAM Plan: MPS-IOA wp06 (MPS-10/Plan MPS-IOA) BP Amoro CoatditWe IN/EI Re( WeII Centre: MPS-10. Tne NaM Vetvl(TVDI Ref .34.3+78.973.20 Depth Fm Depth To SurvepPW Tool Crtated By: Digital Business Client Usa Date: 7/I &2005 ar VIJ Cakulat E ion MCltad Mvmm tmr Systvn: ISCW vn Curvenve SA Section (VS)Ref na: Sld-(O.ODN,O.OOE) MeesurM DDeegqhh Refertnce: 34.J+78.9 ]J.20 28]6.00 89J0.71 Plem¢d MPS-IOA wpOb V35 MWDHFR+MS Chxked: Date: S Er W un McWod: Tnv C mr Surface: Elgptu m M h d R le ygMer NaM l+Camtg B d Calcdabn MMod: Mvun4vn Curvame WELL DETAILS am g et o : u s ara Name +NIS +F/-W Nutting Fiamg I~trtrrde LumgiWde Sld MPS-10 75.58 -3981 6001p1004 565946.43 ]0°243].678N 149°2T46.MSW NA t I ~ ~ i j' ', , i ! , TARGET DETAILS ' I ~ Start Dlr 7~,IOp t 4 9~.3~' Mq, 3,286 13"(•Vp ., - _ I ~ Name TVD +N/-S +E/-W Northin Eastin Sha 8 8 Pe - - I I --r { MPS-LOA Faultl 2623.20 251.11 1345.97 6000273.00 567290.00 Polygon -'-`~ , I I MPS-l0A TI 4198.20 200.00 2900.00 6000235.62 568844.28 Point ~ - ! ~ I ~ I I I I i ! MPS-LOA POIy 4198.20 577.46 2557.01 6000610.00 568498.00 Polygon - - - ~ '' , ' ~ - ~ ~ ~ MP - 3 421 20 - 9 744 7 S LOA T 8. 25 0.00 2275.00 599 0.4 568243.99 Point Sd0 ~ ~ ~ ~ i ! I i MPS-LOA Faultl 4223.20 -1198.59 1969.25 5998829.00 567926.00 Polygon 60 - ' MPS-l0A T2 4228.20 -2125.00 2395.00 5997906.47 568359.87 Point ,, j ~ ~ I ; ~ k ! ~ ~n}l Du 878.85 Mp, I;f6.1111 ~ ~~ i ~ ~ ~ ~ FORMATION TOP DETAILS MPS-lOp ~'a It ( i i ~ ; ~ ~, '~, End , ir : 6065.37 M 4198.2' TVD I I I i ' j i I i i ,, I i i I ~ ~ D '/ 0 ' ~ ' ~ I ~ ' No. TVDPath MDPath Formation I I ~ ! - 1 ~ ~ Start Dir 9 1 0 6085.3 1 MD 31~8. ~ j ~ I 48.2 4 ZC 1 35 0 65189 TU 1 - I ' a l MPS-LOA Tl ~ ~ 2 3753.20 4965.23 Ugnu-MA I i I : i. _ ~ 3 3778.20 5003.96 Ugnu-MB1 I I ~ '~ i ~ ~ 4 3843.20 5106.87 Ugnu-MB2 20 5349 5 3983 39 SBF2 NA I I ~ I I ~ ~ ~ . . - 6 4003.20 5368.05 SBFI-NB '~ ' I I ~ 1-- ''~ ~ I ~ ', 7 4043.20 5470.40 SBE4-NC '~ II ~ - ~ ~ ~ _ i ~ ; I ~ ~ j I I ~ ~ i ' ' -- - '~ 8 4053.20 5492.30 SBE2-NE 1 it ~ ~ End Dit :641 3 16 MD, 4206 50 ~ V ~ ~ 9 4103.20 5613.30 SBEI-NF I ~ 3000 - 3 0~ I ~ I ~ i I I ~ ~ ~ j - ~ 10 4133.20 5700.19 TSBD-Top OA 250 ~ ' -- - -" - ' ~ I 1 4163.20 5808.93 TSBC-Base OA I ~ h~ P9 I (MPS JO ~ I ~ - i - 12 4193.20 5989.02 TSBB-Top OB ~I - ! I I '. - I ~ I I ~ ~ ~ - ',, I - ~ ~ ~ 13 0.00 0.00 SBAS-Base OB I~ ~~ I ~ I ~ ~ ~~' ~ ~ CASING DETAIl.S -60 ~ ~ ~~ 'I ! ! ~ ~ ~ ; ~ : ~ ~ f I I ; N TVD MD N Si i I ~ Sta rt Dir 5~ 1 ' 1228 I D, 2571.37 TVD ! ~ { ~ I ~ _. . i o. ame u ' ' ~ - ' ' ' I ~ I 4197.71 6053.00 7" 7.000 i i S Duo /1 p0 2 87b MI~h,25 9.25 TVD i I ~-{ ~ , 2 4218.20 8940.00 41/2" 4.500 c I I I ~ I ~ ~ ~ i t v I" i t - - I I I i i i , t ~ . 1 1 S610A Feu1 2'- _ - - i _ _ _ I j i 1 I . rn . r_. _ _ i _ _ _ , _ _120 I ~ I _ - _- _- _- _.- -- - i I , - t ~ _ __ - ! y-_ I i _ I - _ - - ~ - - _ - - __ _ _ __ - _- L - , . I ~ - ~ ~ , 1 '. i - - - - • ~ t _- ~ - - __ - - ~' : '~ - - - - - ~~ - . : ' S DIr4/, II 100 8434,55'MD - 422$.15TV1 ~ `J ~ ~ ~ ~ I ~ ~ i ~ SECTiONDETAB.S I i TVD +N/ S +E/ S MD I A W DL VS TF -180 ~ ec nc z - - ec Target eg ace ~ I I 1 76. 4.7 9 28 00 50.01 8 I 2539.25 20 .30 1031.27 0.00 0.00 581.22 i 'I j " j i i II~~ f, I ~~ ' I I J~ '' _ ~ 2 2926.00 50.04 82.10 2571.37 -204.90 1069.33 4.00 -90.00 611.24 t MD, $ntl 1)v : aa1~0.12 227.92 TNq I ' ~ 3 3878.85 61.70 25.28 3136. I 1 251.17 1643.68 5.00 -94.19 1339.86 j ' I ' ~ ' ~ I ~ ~ ~ -- - _ - - _ ~ ~ - - - , _ ~ ~ 4 4195.33 61.70 25.28 3286.13 503.14 1762.67 0.00 0.00 1602.17 1 , I S-' 10A'~'2 I _ { _ ~ 5 6065.37 88.00 165.00 4198.20 200.00 2900.00 7.00 121.26 2192.03 MPS-l0A TI 4 6 6085.37 88.00 165.00 198.90 180.69 2905.17 0.00 0.00 2182.04 ~~ ~ ~ ~--- r~- { ~ ~ , I I ~ ~-- _ I j - -- _- -~ i ~ 7 6413.16 89.39 194.48 4206.54 -143.39 2906.63 9.00 87.71 1953.90 I ' I ' ~ ~ ~ - - -- -- - - - - -- { - - 8 4 4 5 9 9 194 48 422 2100 49 4 8 3 .5 8 .3 8.15 - 2 01.33 0.00 0.00 212.73 ' I - -- - - -- -~- -- - - --r- + 1 - 9 8459.87 90.40 194.48 4228.20 -2125.00 2395.00 4.00 0.17 190.92 MPS-LOA T2 T ' ~ 8480 12 91 21 194 47 4227 92 -2144 61 2389 94 4 70 173 48 10 00 -0 qp ~ l T ' 8940 h 2 1 QN , 4218 2 D I - -. 4 1 /2" I - i .-{-~ '~ . . . . . . . . . 22.74 MPS-l0A T3 11 8940.21 91.21 194.47 4218.20 -2590.00 2275.00 0.00 0.00 -2 ota D t - . . , ~ _ " _ ~. ~ MPS-10 ~ wIp06 I M PS-I pA Y - r-~-1--i ' i I ' i _ ~ i I I t ~ ~ { i ~ i i f -{`-1 I I [ 1 ~ + - - - 4 I 1200 IB00 2400 3000 3600 4200 4800 5400 6000 West(-)/East(+) [600Wim] • ~~~~~, Sperry-Sun Af~G 1 ~ 2005 BP Planning Report ;; i._~ r - Company: BP' Amoco Date: 7/18!2005 Time: 15:57:48 IIr h . : , Page: 1' Field: Milne Point Co-ordinate(NE) Reference: Well: MPS-1~'fttJ9~d ~ Site: M Pt S Pad Vertical (TVD) Reference: 34.3+38.9 73.2 We1L• MPS-10 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: Plan MPS-10A Snrvey Calculation Method: Minimum Curvature Db: Oracle P-an: MPS-10A wp06 Date Composed: 9/23/2004 Version: 35 Principal: Yes Tied-to: From: Definitive Path 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: Weil Centre Sys Datum: Mean Sea Level Geomagnetic ModeL• bggm2005 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Fasting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Weil: MPS-10 Slot Name: Well Position: +N/-S 35.58 ft Northing: 6000010.04 ft Latitude: 70 24 37.678 N +E/-W -398.31 ft Fasting : 565946.43 ft Longitude: 149 27 46.845 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 6053.00 4197.71 7.000 8.500 7" 8940.00 4218.20 4.500 6.125 41/2" Formations MD TVD Formations Lithobgy Dip Angle Dip Direction ft ft deg deg. 0.00 BPRF 0.00 0.00 4651.89 3548.20 TUZC 0.00 0.00 4965.23 3753.20 Ugnu-MA 0.00 0.00 5003.96 3778.20 Ugnu-MB1 0.00 0.00 5106.87 3843.20 Ugnu-MB2 0.00 0.00 5349.39 3983.20 SBF2-NA 0.00 0.00 5388.05 4003.20 SBF1-NB 0.00 0.00 5470.40 4043.20 SBE4-NC 0.00 0.00 5492.30 4053.20 SBE2-NE 0.00 0.00 5613.30 4103.20 SBE1-NF 0.00 0.00 5700.19 4133.20 TSBD-Top OA 0.00 0.00 5808.93 4163.20 TSBC-Base OA 0.00 0.00 5989.02 4193.20 TSBB-Top OB 0.00 0.00 0.00 SBA5-Base OB 0.00 0.00 Targets Map Map ,;' <- Latitade -> <- Longitude -> Name.. Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft' ft ft MPS-10A Fault 1 2623.20 251.11 1345.97 6000273.00 567290.00 70 24 40.147 N 149 27 7.393 W -Polygon 1 2623.20 251.11 1345.97 6000273.00 567290.00 70 24 40.147 N 149 27 7.393 W -Polygon 2 2623.20 -1080.57 723.13 5998936.00 566679.00 70 24 27.051 N 149 27 25.653 W MPS-10AT1 4198.20 200.00 2900.00 6000235.62 568844.28 70 24 39.640 N 149 26 21,842 W MPS-10A Poly 4198.20 577.46 2557.01 6000610.00 568498.00 70 24 43.353 N 149 26 31.892 W -Polygon 1 4198.20 -16.20 2849.81 6000019.00 568796.00 70 24 37.514 N 149 26 23.316 W -Polygon 2 4198.20 -2673.94 2100.24 5997355.00 568070.00 70 24 11.378 N 149 26 45.308 W -Polygon 3 4198.20 -2732.58 2397.77 5997299.00 568368.00 70 24 10.800 N 149 26 36.591 W -Polygon 4 4198.20 93.82 3075.81 6000131.00 569021.00 70 24 38.595 N 149 26 16.690 W -Polygon 5 4198.20 760.24 2811.66 6000795.00 568751.00 70 24 45.150 N 149 26 24.425 W f ~ ~ ~ t Sperry-Sun ~,~~~ ~, ~ ~~~ BP Planning Report ~C'C~ ~ ~ ~~~~. Company: BP Amoco M Dste: - 7/18/2005 Ti~dg~~4 n s e~+ gage 2 i i i ig `~' ` 'r 0 ~ Field: IIne Polnt ordinate(NE)Reference: Go Well: MPS-1r . tlrs W - - , u~ ;; ~ ~~ Site: M PtSPad Vertical (TVD)Reference: 34.3+38.973.?t;;;;~y~,r,R Well: M PS-10 Section (VS) Reference: Well (O.OON,O .OOE,45.6~A'zi) Wellpath: Pl an MPS-10A Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude -> ~-- Longitude -> 'Name Description TVD +N/-S +ElW Northing Easting Deg Min Sec Deg Min Sec :Dip. Dir. ft ft ft ft ft -Polygon 6 4198.20 577.46 2557.01 6000610.00 568498.00 70 24 43.353 N 149 26 31.892 W MPS-10A T3 4218.20 -2590.00 2275.00 5997440.47 568243.99 70 24 12.203 N 149 26 40.187 W MPS-10A Fault 2 4223.20 -1198.59 1969.25 5998829.00 567926.00 70 24 25.888 N 149 26 49.135 W -Polygon 1 4223.20 -1198.59 1969.25 5998829.00 567926.00 70 24 25.888 N 149 26 49.135 W -Polygon 2 4223.20 -1809.43 2961.99 5998227.00 568924.00 70 24 19.877 N 149 26 20.048 W MPS-10A T2 4228.20 -2125.00 2395.00 5997906.47 568359.87 70 24 16.776 N 149 26 36.666 W Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 2876.00 50.01 84.71 2539.25 -209.30 1031.27 0.00 0.00 0.00 0.00 2926.00 50.04 82.10 2571.37 -204.90 1069.33 4.00 0.06 -5.22 -90.00 3878.85 61.70 25.28 3136.11 251.17 1643.68 5.00 1.22 -5.96 -94.19 4195.33 61.70 25.28 3286.13 503.14 1762.67 0.00 0.00 0.00 0.00 6065.37 88.00 165.00 4198.20 200.00 2900.00 7.00 1.41 7.47 121.26 MPS-10A T1 6085.37 88.00 165.00 4198.90 180.69 2905.17 0,00 0.00 0.00 0.00 6413.16 89.39 194.48 4206.54 -143.39 2906.63 9.00 0.42 8.99 87.71 8434.55 89.39 194.48 4228.15 -2100.49 2401.33 0.00 0.00 0.00 0.00 8459.87 90.40 194.48 4228.20 -2125.00 2395.00 4.00 4.00 0.01 0.17 MPS-10A T2 8480.12 91.21 194.47 4227.92 -2144.61 2389.94 4,00 4.00 -0.05 -0.70 8940.21 91.21 194.47 4218.20 -2590.00 2275.00 0.00 0.00 0.00 0.00 MPS-10A T3 Survey MD Incl Azim TVD Sye TVD N/S EIW' DLS MapN Map1 TooVComme t ft deg ..deg _ ft ft ft ft degl100k ft ft 2876.00 50.01 84.71 2539.25 2466.05 -209.30 1031.27 0.00 5999809.87 566979.41 Start Dir 4/100 2900.00 50.02 83.46 2554.67 2481.47 -207.41 1049.56 4.00 5999811.93 566997.68 MWD+IFR+MS 2926.00 50.04 82.10 2571.37 2498.17 -204.90 1069.33 4.00 5999814.60 567017.43 Start Dir 5/100 3000.00 49.87 77.28 2618.99 2545.79 -194.77 1125.04 5.00 5999825.22 567073.04 MWD+IFR+MS 3006.53 49.87 76.85 2623.20 2550.00 -193.66 1129.90 5.00 5999826.38 567077.89 MPS-10A Fault 3100.00 49.96 70.74 2683.42 2610.22 -173.71 1198.52 5.00 5999846.93 567146.32 MWD+IFR+MS 3200.00 50.42 64.26 2747.49 2674.29 -144.33 1269.41 5.00 5999876.94 567216.95 MWD+IFR+MS 3300.00 51.23 57.89 2810.70 2737.50 -106.85 1337.19 5.00 5999915.01 567284.38 MWD+IFR+MS 3400.00 52.37 51.70 2872.58 2799.38 -61.56 1401.32 5.00 5999960.86 567348.11 MWD+IFR+MS 3500.00 53.83 45.71 2932.65 2859.45 -8.79 1461.33 5.00 6000014.15 567407.64 MWD+IFR+MS 3600.00 55.57 39.97 2990.47 2917.27 51.03 1516.75 5.00 6000074.46 567462.53 MWD+IFR+MS 3700.00 57.57 34.48 3045.58 2972.38 117.47 1567.17 5.00 6000141.33 567512.35 MWD+IFR+MS 3800.00 59.80 29.24 3097.57 3024.37 190.02 1612.20 5.00 6000214.27 567556.74 MWD+IFR+MS 3878.85 61.70 25.28 3136.11 3062.91 251.17 1643.68 5.00 6000275.69 567587.67 End Dir :3878 3900.00 61.70 25.28 3146.13 3072.93 268.01 1651.63 0.00 6000292.59 567595.47 MWD+IFR+MS 4000.00 61.70 25.28 3193.54 3120.34 347.62 1689.23 0.00 6000372.53 567632.37 MWD+IFR+MS 4100.00 61.70 25.28 3240.94 3167.74 427.24 1726.83 0.00 6000452.47 567669.26 MWD+IFR+MS 4195.33 61.70 25.28 3286.13 3212.93 503.14 1762.67 0.00 6000528.67 567704.42 Start Dir 7/100 4200.00 61.53 25.60 3288.35 3215.15 506.85 1764.44 7.00 6000532.40 567706.16 MWD+IFR+MS 4300.00 58.10 32.66 3338.67 3265.47 582.32 1806.39 7.00 6000608.24 567747.43 MWD+IFR+MS 4400.00 55.08 40.23 3393.78 3320.58 649.45 1855.83 7.00 6000675.79 567796.28 MWD+IFR+MS 4500.00 52.57 48.33 3452.86 3379.66 707.22 1912.04 7.00 6000734.05 567851.97 MWD+IFR+MS 4600.00 50.65 56.92 3515.03 3441.83 754.79 1974.17 7.00 6000782.15 567913.67 MWD+IFR+MS 4651.89 49.91 61.54 3548.20 3475.00 775.20 2008.45 7.00 6000802.87 567947.76 TUZC 4700.00 49.39 65.91 3579.36 3506.16 791.43 2041.30 7.00 6000819.39 567980.47 MWD+IFR+MS 4800.00 48.84 75.14 3644.89 3571.69 816.61 2112.43 7.00 6000845.19 568051.37 MWD+IFR+MS 4900.00 49.05 84.43 3710.65 3637.45 829.94 2186.49 7.00 6000859.18 568125.30 MWD+IFR+MS • Sperry-Sun BP Planning Report AUG 1 1 2005 f. ~: r. ~.~ ~,. . ,6 .~,~: 019 :.:~ ~~ ~ ~,~:;i;. . G_ Company: BP Amoco Date: 7/18/2005 Time: 15:57:48 °` ~ ' age: 3 Field: Milne Point Co-ordinste(NE)Reference: Well: MPS-10, True North Site: M Pt S Pad Vertical (TVI))Reference: 34.3+38.9 73.2 Well: MPS-10 Section(VS)Refereoce: Well (O.OON,O.OOE,45.OOAzi) Welipath: Plan MPS-10A Survey Cakulatfon Method: Minimum Curvature Db: Oracle Survey MD Incl Aiim TVI) Sys TVD N/S E/W i)LS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 4965.23 49.57 90.41 3753.20 3680.00 832.16 2235.86 7.00 6000861.83 568174.64 Ugnu-MA 5000.00 49.98 93.55 3775.66 3702.46 831.24 2262.39 7.00 6000861.14 568201.17 MWD+IFR+MS 5003.96 50.03 93.91 3778.20 3705.00 831.04 2265.41 7.00 6000860.97 568204.20 Ugnu-M61 5100.00 51.61 102.34 3838.94 3765.74 820.48 2338.98 7.00 6000851.06 568277.85 MWD+IFR+MS 5106.87 51.74 102.93 3843.20 3770.00 819.30 2344.24 7.00 6000849.93 568283.12 Ugnu-MB2 5200.00 53.86 110.68 3899.56 3826.36 797.81 2415.14 7.00 6000829.07 568354.20 MWD+IFR+MS 5300.00 56.65 118.49 3956.60 3883.40 763.59 2489.72 7.00 6000795.51 568429.07 MWD+IFR+MS 5349.39 58.20 122.16 3983.20 3910.00 742.57 2525.63 7.00 6000774.81 568465.16 SBF2-NA 5388.05 59.49 124.94 4003.20 3930.00 724.29 2553.19 7.00 6000756.77 568492.88 SBF1-NB 5400.00 59.90 125.78 4009.23 3936.03 718.32 2561.61 7.00 6000750.88 568501.35 MWD+IFR+MS 5470.40 62.42 130.62 4043.20 3970.00 680.18 2610.02 7.00 6000713.17 568550.10 SBE4-NC 5492,30 63.24 132.08 4053.20 3980.00 667.30 2624.65 7.00 6000700.43 568564.83 SBE2-NE 5500.00 63.53 132.59 4056.65 3983.45 662.67 2629.74 7.00 6000695.84 568569.96 MWD+IFR+MS 5600.00 67.46 138.96 4098.16 4024.96 597.47 2693.09 7.00 6000631.21 568633.89 MWD+IFR+MS 5613.30 68.00 139.77 4103.20 4030.00 588.13 2701.11 7.00 6000621.94 568641.98 SBE1-NF 5700.00 71.62 144.96 4133.14 4059.94 523.70 2750.73 7.00 6000557.95 568692.17 MWD+IFR+MS 5700.19 71.62 144.96 4133.20 4060.00 523.55 2750.83 0.00 6000557.80 568692.27 TSBD-Top OA 5800.00 75.96 150.68 4161.06 4087.86 442.45 2801.79 7.01 6000477.17 568743.93 MWD+IFR+MS 5808.93 76.36 151.18 4163.20 4090.00 434.88 2806.00 7.00 6000469.63 568748.21 TSBC-Base OA 5900.00 80.44 156.18 4181.52 4108.32 354.94 2845.50 7.00 6000390.06 568788.42 MWD+IFR+MS 5989.02 84.49 160.96 4193.20 4120.00 272.82 2877.71 7.00 6000308.24 568821.35 TSBB-Top OB 6000.00 85.00 161.54 4194.21 4121.01 262.47 2881.23 7.00 6000297.92 568824.95 MWD+IFR+MS 6053.00 87.43 164.35 4197.71 4124.51 211.92 2896.73 7.00 6000247.51 568840.90 7" 6065.37 88.00 165.00 4198.20 4125.00 200.00 2900.00 7.00 6000235.62 568844.28 MPS-10A T1 6085.37 88.00 165.00 4198.90 4125.70 180.69 2905.17 0.00 6000216.36 568849.62 Start Dir 9/100 6100.00 88.05 166.32 4199.40 4126.20 166.53 2908.79 9.00 6000202.23 568853.36 MWD+IFR+MS 6200.00 88.44 175.31 4202.47 4129.27 67.96 2924.73 9.00 6000103.81 568870.17 MWD+IFR+MS 6300.00 88.87 184.30 4204.81 4131.61 -31.91 2925.07 9.00 6000003.96 568871.39 MWD+IFR+MS 6400.00 89.33 193.29 4206.39 4133.19 -130.62 2909.79 9.00 5999905.13 568856.98 MWD+IFR+MS 6413.16 89.39 194.48 4206.54 4133.34 -143.39 2906.63 9.00 5999892.33 568853.94 End Dir :6413 6500.00 89.39 194.48 4207.47 4134.27 -227.47 2884.92 0.00 5999808.07 568832.97 MWD+IFR+MS 6600.00 89.39 194.48 4208.54 4135.34 -324.29 2859.92 0.00 5999711.04 568808.83 MWD+IFR+MS 6700.00 89.39 194.48 4209.61 4136.41 -421.11 2834.93 0.00 5999614.02 568784.69 MWD+IFR+MS 6800.00 89.39 194.48 4210.68 4137.48 -517.93 2809.93 0.00 5999516.99 568760.55 MWD+IFR+MS 6900.00 89.39 194.48 4211.75 4138.55 -614.75 2784.93 0.00 5999419.96 568736.41 MWD+IFR+MS 7000.00 89.39 194.48 4212.81 4139.61 -711.57 2759.93 0.00 5999322.94 568712.28 MWD+IFR+MS 7100.00 89.39 194.48 4213.88 4140.68 -808.39 2734.94 0.00 5999225.91 568688.14 MWD+IFR+MS 7200.00 89.39 194.48 4214.95 4141.75 -905.20 2709.94 0.00 5999128.88 568664.00 MWD+IFR+MS 7300.00 89.39 194.48 4216.02 4142.82 -1002.02 2684.94 0.00 5999031.86 568639.86 MWD+IFR+MS 7400.00 89.39 194.48 4217.09 4143.89 -1098.84 2659.94 0.00 5998934.83 568615.72 MWD+IFR+MS 7500.00 89.39 194.48 4218.16 4144.96 -1195.66 2634.94 0.00 5998837.80 568591.58 MWD+IFR+MS 7600.00 89.39 194.48 4219.23 4146.03 -1292.48 2609.95 0.00 5998740.77 568567.44 MWD+IFR+MS 7700.00 89.39 194.48 4220.30 4147.10 -1389.30 2584.95 0.00 5998643.75 568543.30 MWD+IFR+MS 7800.00 89.39 194.48 4221.37 4148.17 -1486.12 2559.95 0.00 5998546.72 568519.16 MWD+IFR+MS 7900.00 89.39 194.48 4222.44 4149.24 -1582.94 2534.95 0.00 5998449.69 568495.02 MWD+IFR+MS 8000.00 89.39 194.48 4223.51 4150.31 -1679.76 2509.96 0.00 5998352.67 568470.88 MWD+IFR+MS 8100.00 89.39 194.48 4224.58 4151.38 -1776.58 2484.96 0.00 5998255.64 568446.74 MWD+IFR+MS 8200.00 89.39 194.48 4225.65 4152.45 -1873.40 2459.96 0.00 5998158.61 568422.60 MWD+IFR+MS 8300.00 89.39 194.48 4226.71 4153.51 -1970.22 2434.96 0.00 5998061.59 568398.46 MWD+IFR+MS 8400.00 89.39 194.48 4227.78 4154.58 -2067.04 2409.97 0.00 5997964.56 568374.32 MWD+IFR+MS 8434.55 89.39 194.48 4228.15 4154.95 -2100.49 2401.33 0.00 5997931.04 568365.98 Start Dir4/100 8459.87 90.40 194.48 4228.20 4155.00 -2125.00 2395.00 4.00 5997906.47 568359.87 MPS-10A T2 8480.12 91.21 194.47 4227.92 4154.72 -2144.61 2389.94 4.00 5997886.82 568354.98 End Dir :8480 s Sperry-Sun AUG ~ ~ 2005 BP Planning Report i. P, ~ Beet ~ ~ .,~ r•„~,,, t, Company: BP Amoco Dater.. 7!18(2005 Thne: 15:5748 ~+,I7~'~OCe: 4 Field: Milne Point Co-ordinate(NE) Reference: WeB: MPS-10, True North Site: M Pt S Pad Vertical(TVD) Reference: 34.3+38.9 73.2 Well: MPS-10 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpaths Plan MPS-10A Survey Calculation Method: Minimum Curvature Db: Oracle survey MD Inc! Azim TVD Sya'TVD N15 ENV DLS MapN MapE TooUComme t ft deg. deg ft ft ft ft deg/100fl ft ft 8500.00 91.21 194.47 4227.50 4154.30 -2163.85 2384.97 0.00 5997867.53 568350.19 MWD+IFR+MS 8600.00 91.21 194.47 4225.38 4152.18 -2260.66 2359.99 0.00 5997770.52 568326.06 MWD+IFR+MS 8700.00 91.21 194.47 4223.27 4150.07 -2357.47 2335.01 0.00 5997673.51 568301.94 MWD+IFR+MS 8800.00 91.21 194.47 4221.16 4147.96 -2454.27 2310.03 0.00 5997576.49 568277.82 MWD+IFR+MS 8900.00 91.21 194.47 4219.05 4145.85 -2551.08 2285.04 0.00 5997479.48 568253.69 MWD+IFR+MS 8940.00 91.21 194.47 4218.20 4145.00 -2589.80 2275.05 0.00 5997440.67 568244.04 4 1 /2" 8940.21 91.21 194.47 4218.20 4145.00 -2590.00 2275.00 0.00 5997440.47 568243.99 MPS-10A T3 /'..A /"~"\ Name hIPS10 WELL DETAILS +N_S +F/-W Nathkig Fasting Latkude Lossginsde Sla 75.SR -798.31 600001000 565946.47 70°24'J].b78N 149°2T46.WSW N/A ANTI-COLLISION SETTINGS In[¢rpola[ion MC[hod:MD IR[¢[Yal: 2$,00 Depth Range From: 2876.00 To: 8940.21 Masimmn Range: 1090.59 Reference: Plan: MPS-IOA wp06 COMPMV DETAILS BP Amso CakWazion Metlnd: Mmmmn Curwme Error sysan: ISCWSA Scan Method: Trav Cylinder Math Error Surf Elliptlcal+Cnmg Weming McOwd: Ruks Bead SURVEY PROGRAM Depth Fm DepN To Survey/Plan Tool 2tl76.00 X940.21 Plaaied: MPSIOA xTUM1 \'7a MWD+IFR+MS WTLLPATH DETAILS 16U From Colour To MD PIen MPS-IOA 1 JO O 500 Partin WeI1paN MPSIO Ti on MD. 7%76.00 SOO 1 OOO 33 ^~`' 1 OOO ~ I SOO Ref Datmgi~ 31.138.9 ]3.20ft Isoo zooo mg ~ D ~ nw 2000 2500 + Argl+c Fi From ND 125 = 2500 3000 45m° o.m om 343a 3000 _ _ 3500 / 3500 4000 r - ~ 4 OO SOOO LEGE3.v 700 ~ ~ ~~ SOOO sSOO ~• MPS-0I IMPS-0IA Major Rid M X' //j / v, ~- ~ SSOO GOOD ~ MPS-0I I MPS-OI L21. Mela Risk ~ - GOOD -TODD MPS-01 IMPS-0IL2PB1). Major Risk MPS-0I (MPS-0IPBIk Meer RUk 30 ~'\ 7000 O HOOD MPS-02 (MPS-02k Major Risk ~ MPS-031MP5-03k Mepr RUk 3 R k ~~ 5 HHn~OnvOn~D 'WO 90n0n0 I ]000 MP$-0 1MP5-03L11. Map is + MPS-04 (MMP54NLI~Mala Rids I IOOO 12000 MPS-04IMPS4NLIP811, Msja Risk ~ MPS-(14 (MP5410LIP82k Maa Risk . 2000 13000 MPS-OS IMPS-0Sk Major Risk -°° MPSOS IMPS-0SL11 M ja Risk ' - l OOO 14000 . MPS-0S IMPS-0SPBIk Major RUk 0 I OO I SOOO '~°• MPS-061MP5416), Major Risk MPS-0] IMPS-0]k Major Risk _ - MPS-0tl (MPS-0Sk Major Risk ~ MPS-0S IMPS-0SPBIk Mepr RSk MPS-091MP5-091 Mepr Ruk '/ !Y~ ~ I . ~ MPS-10 (MPS-101. NOERRORS ~G :p ` ~ ~ MPSIO (PWa2 MPS-IOAI. NOERRORS MPSII MPS Il M Ri k 5 ~ - F,. ,.~ ' - ajor s I k + MPSI I (PW MPSI TAI. NOERRORS ~ MPS-12 (MPS-12), Major Risk ~• MPS-12 (MPS-12L I1 Myw Rids MPS-I?(MPS-12PBIk Major Risk ll. a ~ MPS-13 (MPS-Ilk Major Rek !K MPS-14 (MPS-14), Major Risk ---~- MPS-IS (MPS-151. 61ajor Rid 0 ^/ ','J,1 270 7 9~ '--- MPS-Ib (MPS-161. Map Rids MPS-I](MPS-1]l. Major Risk MPS I'/ (MPSI9LI). Maja Rid MPSIB (MPSIB). Mapr Rid ' MPS-IR (MPS-IBPBIk Mepr Rid ~ MPSIX (Pl MPS 1 8 41 M Rid .. an - . ajor . ~ MPSI9 (MPS 19) Mapr Risk - , ~ MPS-19 (MPS-19A1. Map Rid - MPS-19 (MPSI9ALI1. Maja Rid 5 MPS-191MP5-19.4PBI I. Mapr Risk MPS-701MP5-2U), Mapr Risk ' MPS-21 (MPS-Ilk Major Risk - ~ MPS-_'2 (MPS22 LI A), Mqa Risk f~" ' - ~~ MPS~'_2 (MPS72 LI plant. Myor Risk ~ MPS 221MPS'2 L~ Pl k M Ri k ,~ , ' ~ ~ ~ - an ajor s MP5~221MPS2_' L7 Plan1. Maja RUt h1 PS-'_? (MPS2_' L4 Plink Maja RUk 0 ~ ~ -- MPS'_21MPS ~2 Plan hclixl. MajorRUk _ MpS-_" (MPS 72). Major Risk h1PS231MPS-231. Major RUk ~~ MPS-231hIPS .SLIT. Maja Risk . ~%~~.~. -,- .. ~ _.~.. MPS-2J (MPS 24PBI~hlapr Risk MPS-241MP5-24P82k Mapr RUk MPS-251MP5-25), Maja Risk 5 ' 240 120 ~-~9 ibrr 1~... i '~ MPS'3 (MPS-25LI). Major RUt MPS-2fi (MPS-261. Mapr Rid + 1'bn MPS-00IP1sv MPS410 PBI), Mya Rid Plan MPS 00 fPlan MP54MIk Meja Risk - Plan old Sauc< Web Well one kc (Source Wakr Wcll). Major Ri ^ ~ / , ~ Plan Sours blazer Well (Sours W'atcr WcID, Alalor Rid U + Phm MPS70A L - MPSIOA xy06 100 - ~~yy pp ,~~U..Gt4 ~~, LJ L { i~.;J~~h17 127 ~~ ~ - SECTION DETAILS ~~~ ; ',DPI Ss MD Irc An "M1'D +N/-S +EI-W DLeg TFas VSec Target 1 0 1 2876.00 SO.OI 2 2926.00 50.00 84.71 251915 62.10 2971.77 -209.30 1031.27 0.00 0.00 SBI12 -704.90 1069.17 6.00 -90.00 61114 7 3878.85 61.70 7518 3176.11 251.1] 1647.68 5.00 -94.19 1339.8b 4 4195.33 61.70 25.78 3286.1) SW.1/ 176267 0,00 0.00 1602.17 170 5 60fi5.37 88.00 165.00 419810 200.00 2900.00 7.00 12126 219207 MPSIOA TI fi 6085.37 88.00 165.00 4198.90 180.69 2905.17 0.00 0.00 7182.04 L 160 ] 6417.16 69.39 X B434S5 8979 194.48 4206.54 194.49 422815 -143.79 2906.63 9.00 87.71 1953.90 -2100.49 2101.73 0.00 0.00 21273 1 ~ 9 8459.8] 90.10 10 B4W.17 91.71 19448 422810 194.77 422792 -212500 2395.00 1.00 0.17 190.92 MPSIOA T2 -"_'14461 2799.96 4.00 -0.70 177.48 II %940.71 91.71 19947 471810 -2590.00 2275.00 U.Ip 0.00 -222.74 MPSIOA T3 Tr vc.ling ;ylinde Azimi :h (Tl ~- ~^a~.I) [ o •g] vs C ntre t Can -e Se laration t`Ofdin] • ~ op MPS-10A Planned~ocation PS-~~ ~ ~' ~.,. j-kI~IIPS-04_ ~ UG 1 1 ZQQ~S-04L1PB' I! ~~ ~~;a ~i~ ~t 8S CGl1S. 1~~~'lib3siG~i AMPS-15 ~:: ,~1i3T8gQ ~ ~ ' ",y'/ is ,; +++•+a4t~94~~200 +,450 +~~5,550 +++4,250 ` ~~, , ` ~ ~"" ~ M'PS-05 +~+5,950 ~ X6,100 -AMPS-Q3 ~_; ~3-05PB1 "~~_ X4.3 ++ ,500 .-~A_10 +s,aoo ,`%i + ~.F :' ~ +x,200 •S-04 ', +7,400 ~ivl~S-05 +7,600 • 8,000 ~S-04L1 I +8,20 ^ +8,400 ~ j 05 8,600 -11 - ~S-I S'-05 •S-O 0.25 Mile Buffer I i (Schrader Bluff OA/OB Section) i _____ _ Well Status 0 1000 2000 Feet • Abandoned Gas Injector Injecting Miscible Injector Operating 1:12,000 Miscible Injector Shut-In ASP Zone 4 NAD 27 v Not Yet Completed / Td Not Yet Reached. ~' ~ Null/Unknown • Oil Producer Flowing Oil Producer Gas Lift • Oil Producer Hydraulic Pump • Oil Producer Shut-In ~ Oil Producer Submersible • Oil Suspended • Oil Well c~ Plugged Back For Redrill TSBB OB Markers ~ Suspended X ~~ Waterlnjector TSBD OA Markers ~;~ Water Injector Injecting Water Injector or Water Producer Shut-In • Water Producer Flowing ~ • SONDRA D STEWMAN 89-6/1252 130 BP EXPLORATION ABC INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 DATE ~~ ~~ ~ ~ _ V 1 -~- ORDER OF E ~~~~~ , ! 1@~Ll d~ DOLLARS First National~Bank Alaska Anc`h-o'r'age/, AK 99501 ~~ MEMO 1 ' 1T"'"~J ~ ~^~.+~-i ~ J ~~Ii~a~1~~j,JY~---~ ~: ~ 25 200060:99 L4~~~6 2 27~~~ L 56,11' 0 X30 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P'ARAGRAPHS TO SE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# 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(f), all (pig 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. (Comaanv 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\jody\transmittat_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL- 525140 Well Name: MILNE PT UNIT SB S-10A Program SER Well bore seg ^ PTD#:2051250 Company BP EXPLORATION (ALASKA) INC Initial Classll'ype SER 1 PEND GeoArea 890 Unit 11328 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached_--_,-_,-_______________________ _________Yes_ --_---_--__--_-_ 2 Lease number appropriate_____ __.____________________ ____--_-_Yes ____Thisredrill lies entirely within leaseApL38011.0._--__--_--__-__-__----_---_---_--- 3 Unique well-name andpumber___________________________ __-.---._Yes_ _.__--_,_._-,_ 4 Well located in_a_defined-pool- _ - _ - - _ - Yes _ _ Milne-Point Schrader Bluff Oil Pool (525140), governed by_CO 477, amended by CO 477_.05, - _ . 5 Well located proper diskancefrom drilling unit_boundary_ _ - _ _ Yes _ - C9 477.Q5specities no restrictions as to well spacing except that no pay shall be opened - 6 Well located proper distance from other wells_ _ - Yes - - - _ - in a well closer than 500-feet from the,e_xte[ior boundary of the affected a[ea._ - - - _ _ - - 7 Sufficient acreage available in-drilling unit_ _ - _ - - _ - _ _ Yes - - _ - .Well bore will be more iha_n 500 feet to the exterior boundary of-the CO 477 area. - 8 If_deyiated, is-wellbore plat-included - - - - - Yes - - - - - 9 Operator only affected party- - - - - - Yes - - - - - 10 Operatorhas-appropriate-bond inforce------ ----- - -- - -- -- --Yes- --- - -- ---- --- -- ------- -- -- -- -- -- - - - - - -- -- - 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can bei_ssuedwithoutadministrativ_e_appr_oval---------------- ---------Yes_ _-_-__-____-_______--_-__-_--_ SFD 8115!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_ Injection Order # (put 10# in-comments)-(For- Yes , - - . - Area Injection Order No._ 10-6 . - _ _ - - _ , _ - - - 15 All wells-within 1!4_mile area of review identified (For service well gnly)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes . - _ - . - _ MPIJ $,3, 5-2, $-5, S-5PB1, 5,11,5-12 _ . _ _ - . - _ , _ - - _ - - _ _ -- 16 Pre-produced injector; duration ofpre-production Less than 3 mogths_ (For_service well only) No_ . - - - - - 17 ACMP-Finding of Consistency-has been issued_fo[this pr_oject_ _ _ - _ NA_ . _ _ _ Redrill of existing well._ _ , - - _ - - Engineering 18 Conductor string-p_rovided_____________________--__--___- __--__-_Yes. ___-__Conduetorset_inoriginalwelh MPS-10(203-067).--__-__-__-__,___.-_--_---_--_-_---_- 19 Surface casing_protectsallkrrQwn_USDW&____-______-__-__-__ ____--__NA-. -__-_Allaquifers exempted, 40CFR,147.iQ2_(b)_(3)._-_--__-__-___- -------------------- 20 CMT_vol-adequate_tocirculate_onconductor&surf-csg__-____-____ _____-__-NA-- ___-_Surfacecasing setin_orignalwell-------------------____--_--------__-__-___-- 21 CMT_v_ol_adequate_totie-in long string to surfcsg___________________ _________No_ -___ AIII_hydrocarbon-zonesplannedto be covered.__--__-___-_-___--__--_--__-__----_---_-- 22 CMT-will coyer all kno_w_nproductivehorizon_s_________________-_- -_--_---Yes_ ______Linerpl_anned to be cemented.-_.-_____-_-___-__,__--__--__---___-__-,__---- 23 Casing designsadegcateforC,_T,B&permafrost--------- -------- --- - Yes _-------------------.--.---.----------- -----.---------------------- _-- 24 Adequate tankage_o_r reserve pit - _ - _ - _ - _ _ - _ Yes - - Rig is_equipped with steel-pits. No_ resen!e_pitplanned, All waste to approved disposal wells._ - - - - 25 If-a_re-drill,has-a1.0-403 forabandgnmentbeenapproved--__ -___._ Yes_ _-__--3Q5,228._-_____--___________________________________________.---- 26 Adequate wellboreseporation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . - Proximiy analysis-pe_rformed._ Closest approach_is abandoned section_of original well, No conflicts_identified- _ _ 27 If_diverter required, does it meet regulations_ _ _ _ _ _ - - _ _ - - _ - _ _ _ _ _ _ - - _ _ _ NA- _ _ _ _ _ _ _ BOP stackwill already_be in place, - - _ _ _ _ _ _ - _ _ - _ . - - _ _ - _ _ - - - - Appr Date 28 Drilling fluid_program schematic & equip list adequate_ - - _ _ _ - - _ _ _ - _ Yes _ - - _ Maximum expected formation pressure 8.35 EMW.-Planned MW 8.9 - 9.2 ppg in Schrader._ - - - . - - - TEM 8/24/2005 29 BOPEs,.do they meet_ regulatiop - - - Yes - - - - - - - - - ~y~ 30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - - - _ _ _ _ _ _ MASP calculated at 1366psi, 3000_psi_BOP testplanned, - - - _ _ _ - _ _ - _ _ - _ _ _ - _ _ _ - . - _ _ . - _ - - - - _ IFY Y 31 Choke_manjfoldoomp_lieswlAPI-RP-53(May84)___________________ _________Yes- ______--__--_-__-__--__-___-___-___-_- 32 Work willoccurwithoutoperationshutdown__________ ___________ _________Yes- ______--__--__-_.____-__--_---____-___,--__ -_ 33 Is presence-of H2S gas_prpbable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - _ - _ _ - _ Minor_H2S_has been reported on_S pad. Mud should_preclude H2$ on rig. Rig has sensors and alarrrls, _ - - _ _ _ 34 Mechanical_condition of wells within AOR verified (for service well only - Yes - - - . -Well des jned_to eliminate i_n zone_communication._ No eyidence_of out of zone communication.in proximate wells_ Geology 35 Permit cap be issued wlo hydr-ogeq sulfide measures - - - - - - - Yes - - - H2$ measurements from MPU_S-Pad_~re all<2_ppm in June 2005. - _ _ - - - 36 Data_presented on_pote_ntial overpressure zones- - - - - - - . - - -Yes Normalpressure gradient except OA & OB_sapds that may be 6.Q ppg; will be drilled with 8.6-9,3_ppg mud._ Appr Date 37 Seismic analysis of shallow as_zones- - _ _ _ - - _ - g - _ - _ - : _ NA_ _ - _ - _ Rednll of existin well g - - ~ - - - - - - SFD 8/15!2005 38 Seabed condition survey(rfoff-sh9re)_--__- _____ _________NA__ _______-_- --_-_ 39 _Contact name/phone for weekly progress reports[explgratoryonly]________ _________NA__ _ _ ______--____-__,__-___-_-__--__-__----_-_-__----__--_-._,__---_ .- Geologic Engineering Public Commissioner: Date: Commissioner: Date C iss' ner Date ~~'S s J z 4 js ~~~ ~'-L~-~' ~ ~, ~-• • C Well History File /APPENDIX Information of detaiied nature that is not particularly germane to the Well Permitting Process but is part of the history file. ~~~~~E~ FEB ®`~ 200` To improve the readability of the Well History fi{e and to simplify finding infom~ation, information of this nature is accumulated at the end of il~e file under APPENDIX. No special effort has been made 1o chronologically organize this category of information. ,~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 07 15:28:21 2007 Reel Header Service name .............LISTPE Date .....................07/03/07 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................ST5 LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/03/07 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Scientific Technical Services Scientific Technical Services Comment Record ~ ~QQ~ TAPE HEADER ~~~ ~ ~~ Milne Point MWD/MAD LOGS WELL NAME: MPS-l0A API NUMBER: 500292315201 OPERATOR: BP Exploration (Alaska), LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 07-MAR-07 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: W-0003978051 W-0003978051 LOGGING ENGINEER: J. BOBBITT R. FRENCH OPERATOR WITNESS: D. GREEN D. GREEN SURFACE LOCATION SECTION: 12 TOWNSHIP: T12 RANGE: R10 FNL: FSL: 3342 ' FEL: 64 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 73.30 GROUND LEVEL: 38.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2776.0 2ND STRING 6.125 7.000 6225.0 3RD STRING PRODUCTION STRING ~~ :~~ al'S ~ _ .. Inc. REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUN 1 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND AT-BIT INCLINATION (ABI) . 4. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN MPS-l0A ON 17 OCTOBER 2005. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH ON 10 JANUARY 2007. 5. MWD RUNS 1,2 REPRESENT WELL MPS-l0A WITH API#: 50-029-23152-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8915'MD/4201'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.8 - 9.0 PPG MUD SALINITY: 500 - 800 PPM CHLORIDES FORMATION WATER SALINITY: 21000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 `~ ~y~ Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 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 2735.5 8850.5 ROP 2776.5 8916.0 RPS 2776.5 8857.5 RPD 2776.5 8857.5 FET 2776.5 8857.5 RPM 2776.5 8857.5 RPX 2776.5 8857.5 FCNT 6201.5 8822.0 NCNT 6201.5 8822.0 RHOB 6201.5 8836.5 PEF 6201.5 8836.5 DRHO 6201.5 8836.5 NPHI 6240.5 8822.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 2735.5 2735.5 3686.5 3686.5 3690.5 3690.0 3713.5 3713.5 3716.5 3716.0 3724.5 3724.0 3759.5 3759.5 3773.5 3773.0 3781.0 3781.0 3794.5 3795.5 3803.0 3804.5 3821.5 3820.5 3831.5 3829.5 3838.5 3835.5 3847.5 3847.5 3866.5 3866.0 3889.0 3888.5 3909.5 3909.0 3911.0 3911.0 3924.5 3924.0 3936.0 3936.0 3949.0 3949.0 3955.0 3954.0 3974.5 3974.0 4005.5 4004.0 4023.5 4024.0 4038.5 4039.0 4046.5 4045.0 4051.5 4050.0 4081.0 4080.5 4086.5 4085.5 4113.5 4113.5 4120.0 4120.5 4160.5 4185.0 4214.0 4216.5 4230.5 4253.5 4260.0 4269.0 4282.0 4285.0 4301.0 4324.5 4346.0 4363.5 4392.0 4408.5 4422.5 4442.0 4459.5 4475.0 4493.0 4515.0 4536.0 4549.0 4560.0 4616.0 4618.5 4626.0 4637.5 4648.0 4669.0 4690.0 4699.5 4720.0 4729.0 4739.0 4749.0 4756.5 4772.0 4777.5 4780.5 4785.5 4790.5 4812.5 4825.5 4837.5 4863.0 4882.0 4916.5 4936.5 4951.5 4966.0 4983.5 5012.5 5021.0 5024.5 5026.0 5053.0 5070.5 5085.0 5093.0 5106.5 5109.0 5118.5 5155.0 5168.0 5192.0 5224.0 4161.0 4186.0 4213.5 4216.5 4231.0 4253.5 4260.0 4269.0 4281.5 4285.5 4300.5 4326.0 4347.0 4365.0 4391.0 4409.0 4423.0 4442.5 4461.0 4476.0 4494.5 4515.0 4537.0 4548.5 4561.0 4618.5 4621.0 4627.0 4639.5 4648.5 4671.0 4690.5 4700.0 4720.0 4729.5 4741.0 4751.0 4758.0 4773.5 4779.0 4782.0 4786.0 4791.0 4812.0 4826.5 4837.0 4864.5 4881.5 4917.5 4938.0 4952.5 4967.0 4984.5 5014.0 5022.5 5024.0 5026.5 5054.0 5071.0 5085.0 5094.0 5107.0 5111.0 5118.5 5155.5 5168.5 5192.0 5224.5 `; 5244.0 5260.5 5289.0 5300.5 5309.5 5316.5 5322.5 5352.0 5367.0 5384.5 5409.0 5434.0 5441.0 5447.0 5475.0 5479.0 5504.5 5517.5 5570.5 5634.5 5638.0 5656.5 5737.5 5827.5 5871.0 5874.5 5920.0 6006.5 6016.0 6018.0 8916.0 5245.5 5261.0 5289.5 5301.5 5309.5 5317.0 5323.0 5353.0 5367.0 5385.5 5410.0 5434.0 5441.5 5448.0 5474.5 5477.5 5504.0 5517.5 5571.0 5631.0 5634.5 5654.0 5736.0 5825.5 5869.0 5873.5 5919.5 6006.0 6015.5 6017.0 8915.0 ~~, MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 2735.5 6239.0 MWD 2 6239.0 8915.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 ,~ NPHI MWD Name Service Unit DEPT FT FCNT MWD CNTS NCNT MWD CNTS RHOB MWD G/CM DRHO MWD G/CM RPD MWD OHMM RPM MWD OHMM RPS MWD OHMM RPX MWD OHMM FET MWD HOUR GR MWD API PEF MWD BARN ROP MWD FT/H NPHI MWD PU-S ~~i PU-S 4 1 68 52 14 First Last Min Max Mean Nsam Reading Reading 2735.5 8916 5825.75 12362 2735.5 8916 113.62 1765.7 296.626 5209 6201.5 8822 14596.9 42982.5 21680 5209 6201.5 8822 1.552 2.69 2.2225 5271 6201.5 8836.5 -0.754 0.407 0.0347471 5271 6201.5 8836.5 0.1 2000 23.2459 12163 2776.5 8857.5 0.39 2000 30.7504 12163 2776.5 8857.5 0.4 2000 21.6339 12163 2776.5 8857.5 0.64 2000 20.3626 12163 2776.5 8857.5 0.14 52.49 1.20003 12163 2776.5 8857.5 4.77 126.31 70.697 12231 2735.5 8850.5 0.94 11.15 2.13945 5271 6201.5 8836.5 0.39 1352.57 168.503 12280 2776.5 8916 10.94 47.54 35.665 5131 6240.5 8822 First Reading For Entire File..........2735.5 Last Reading For Entire File...........8916 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 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 2735.5 6198.5 ROP 2776.5 6239.0 RPX 2776.5 6194.5 FET 2776.5 6194.5 RPD 2776.5 6194.5 RPS 2776.5 6194.5 RPM 2776.5 6194.5 LOG HEADER DATA DATE LOGGED: 11-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6239.0 TOP LOG INTERVAL (FT) 2776.0 BOTTOM LOG INTERVAL (FT) 6239.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.1 MAXIMUM ANGLE: •0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWDO10 RPM MWDO10 RPS MWD010 RPX MWD010 FET MWD010 GR MWDO10 ROP MWDO10 8.500 2776.0 Polymer 8.80 55.0 10.0 550 8.5 4.900 80.0 4.260 100.0 5.000 80.0 4.800 80.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2735.5 6239 4487.25 7008 2735.5 6239 RPD MWD010 OHMM 0.23 2000 27.2919 6837 2776.5 6194.5 RPM MWD010 OHMM 0.39 2000 23.7413 6837 2776.5 6194.5 RPS MWD010 OHMM 0.4 2000 25.1367 6837 2776.5 6194.5 RPX MWDO10 OHMM 0.64 2000 23.5331 6837 2776.5 6194.5 FET MWDO10 HOUR 0.14 13.2 0.766152 6837 2776.5 6194.5 GR MWD010 API 4.77 119.58 69.3609 6927 2735.5 6198.5 ROP MWD010 FT/H 0.39 1352.57 171.892 6926 2776.5 6239 First Reading For Entire File..........2735.5 Last Reading For Entire File...........6239 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPX RPM FET RPS RPD GR PEF FCNT DRHO RHOB NCNT ROP NPHI LOG HEADER DATA DATE LOGGED: header data for each bit run in separate files. 2 .5000 START DEPTH 6195.0 6195.0 6195.0 6195.0 6195.0 6199.0 6200.5 6200.5 6200.5 6200.5 6200.5 6239.5 6239.5 STOP DEPTH 8856.5 8856.5 8856.5 8856.5 8856.5 8849.5 8835.5 8821.0 8835.5 8835.5 8821.0 8915.0 8821.0 15-OCT--05 ~' SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8915.0 TOP LOG INTERVAL (FT) 6239.0 BOTTOM LOG INTERVAL (FT) 8915.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.5 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 90518 ALD Azimuthal Litho-Dens 9755 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 6225.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 60.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 6.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.610 93.2 MUD FILTRATE AT MT: 8.000 70.0 MUD CAKE AT MT: 5.000 70.0 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 Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 `~' RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6195 8915 7555 5441 6195 8915 FCNT MWD020 CNTS 113.62 1765.7 296.626 5209 6200.5 8821 NCNT MWD020 CNTS 14596.9 42982.5 21680 5209 6200.5 8821 RHOB MWD020 G/CM 1.552 2.69 2.2225 5271 6200.5 8835.5 DRHO MWD020 G/CM -0.754 0.407 0.0347471 5271 6200.5 8835.5 RPD MWD020 OHMM 0.1 2000 17.9361 5324 6195 8856.5 RPM MWD020 OHMM 1.1 2000 39.6736 5324 6195 8856.5 RPS MWD020 OHMM 3.88 1897.05 17.0688 5324 6195 8856.5 RPX MWD020 OHMM 3.7 1858.81 16.2163 5324 6195 8856.5 FET MWD020 HOUR 0.35 52.49 1.75663 5324 6195 8856.5 GR MWD020 API 33.71 126.31 72.5137 5302 6199 8849.5 PEF MWD020 BARN 0.94 11.15 2.13945 5271 6200.5 8835.5 ROP MWD020 FT/H 0.69 992.46 163.621 5352 6239.5 8915 NPHI MWD020 PU-S 10.94 47.54 35.665 5131 6239.5 8821 First Reading For Entire File..........6195 Last Reading For Entire File...........8915 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/07 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/03/07 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNK~TOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................07/03/07 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF ~,,d V End Of LIS File