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Home My WebLink About208-159Image 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. ~Q $ - ~ ~~ Well History File Identifier Or anizin (done) g g ^ Two-sided II I II II II II II I II III ^ Rescan Needed II I II II'I II (III (III RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Di kettes, No. G~ NO*' ~ ^ Maps: bl b I S ^ Greyscale Items: Other, No/Type : y canna e tems ^ Other a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ Q /s/ Project Proogng IIIIIIIIIIIIII IIIII BY: Maria Date: ~ !~ /s/ Scannin Pre aration x 30 = ~ + ~_ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: P, /~ /~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: ~ ©~(Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ /~ /s/ ~ V Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s u l u ^1I I I u II 11111 Scanning is complete at this point unless rescanning is required. Rescanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III (I'lll III II~) III 10/62005 Well History File Cover Page.doc • • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Ye/4 tt Sent: Friday, April 15, 2011 5:15 PM [� J �e ` � To: 'Worthington, Aras J' Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: MPU CHOPS Wells SSV Variance The Well Safety Valve System (SVS) regulations - 20 AAC 25. 265 - effective December 3, 2010, provide for granting either a variance or waiver of the stated requirements; a variance if what is proposed provides at least an equally effective means of compliance; a waiver if what is proposed does not promote waste, is based on sound engineering /geoscience principles, will not jeopardize ultimate recovery, and does not increase risk to health, safety, environment. 20 AAC 25.265(c)(1) requires the surface safety valve (SSV) to be installed in the vertical run of the well's tree. As explained, this would be impossible to comply given the rod - driven downhole pumps used in the Cold Heavy Oil Production with Sand (CHOPS) project completions. BPXA's request for a temporary variance is approved. 20 AAC 25.265(c)(4) requires installation of a check valve in the well's flowline upstream of the production manifold. Your explanation indicates these check valves have not been installed, thus your request is not for a variance (equivalence) but a waiver [20 AAC 25.265(o)(2)]. BPXA's request for a temporary waiver is approved, but there needs to be additional discussion about the levels of protection in lieu of the check valves. These temporary approvals apply to Milne Point Unit wells S -37 (PTD 2070520), S -39 (PTD 2081830), S- 41 (PTD 2081590), and S -43 (PTD 2081760). Sufficient information has been provided to allow BPXA to begin operating these wells this weekend as requested in our phone conversation. Broader coverage (other wells) will be addressed in the Commission's response to BPXA's formal request as necessary. BPXA's formal request (letter application) covering the variance and waiver must be provided no later than Tuesday, April 19, 2011 (do not need to submit request by sundry application). Appropriate schematics as necessary and justification must be provided that can serve as the basis for the Commission's approval of permanent variance /waiver. Jim Regg AOGCC APR 2 0 20fl 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Worthington, Aras J [ mailto:Aras.Worthington ©bp.com] Sent: Friday, April 15, 2011 4:26 PM To: Regg, James B (DOA) Subject: Mr. Regg, BPXA requests a temporary e-mail variance to 20 AAC 25.265C for rod - driven pump wells at Milne Point: MPS -37, 39, 41, and 43 to allow the surface safety valve (SSV) to be located horizontally on the tree. Wells 37, 41, and 43 were completed prior to the regulation change that became effective December 3, 2010. A SSV in a vertical line with the tree (25.265C.1) is neither practical nor effective due to the need to accommodate the drive rod. 4/15/2011 • • Page 2 of 2 Also, a variance is requested on 25.265C.4 which states that a check valve must be installed in the well's flow line upstream of the production manifold. Although check - valves are present on the annulus gas, and on the production lines prior to entering the atmospheric production tanks, they were not installed upstream of the production manifold due to the high fluid viscosities and initial sand -cuts that could plug the check - valves. BPXA will follow through with a formal request for variance for these wells complete with schematics and all necessary detail. Aras Worthington Wells Intervention Engineer BP Alaska Inc. (907) 564 -4102 4/15/2011 FW: MPS-41 Coring Analysis . • Page 1 of 1 Okland, Howard D (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, July 13, 2010 8:57 AM To: Okland, Howard D (DOA) Subject: FW: MPS-41 Coring Analysis Attachments: MPS-41_SWC_Recovery_and_SARA_Data_for_AOGCC.xIs; MPS-41_GCMS_Data_for AOGCC.xIs Hi Howard, Here is the data that you requested... Terrie From: Bernaski, Greg E Sent: Monday, July 12, 2010 4:46 PM To: Stewman, Sondra D; Hubble, Terrie L Subject: RE: MPS-41 & MPS-43MPS-43 Information Request Terrie/Sondra: ~~~-15 ~ 5,~1 -~~~~~~ Attached are the sidewall core recovery and analyses summary for well MPS-41 for submittal to the AOGCC. Please note that the sidewall cores were taken in order to run GCMS and SARA (only) to determine fluid properties from sidewall core oil extracts. There were no routine porosity, permeability, grain size, mineralogy, etc... analyses run on any of the MPS-41 sidewall cores. Please let me know if you have any questions.... Greg ~ ~' «MPS-41_SWC_Recovery_and_SARA_Data_for AOGCC.xIs» «MPS- 41 GCMS Data for AOGCC.xIs» From: Okland, Howard D (DOA) [mailto:howard.okland@alaska.gov] Sent: Tuesday, June 29, 2010 1:24 PM To: Hubble, Terrie L Subject: MPU S-41 Core Analysis Terrie, I'm not sure if this "belongs" to you. The Completion Report for MPU S-41 states that the core analysis for the sidewall core will be submitted when available from Lab. Is the core analysis available? TNX. Howard 7/13/2010 DATA SUBMITTAL COMPLIANCE REPORT 6/29/2010 Permit to Drill 2081590 Well Name/No. MILNE PT UNIT UGNU S-41 Operator BP EXPLORATION (ALASt(A) INC API No. 50-029-23401-00-00 MD 5081 TVD 4074 Completion Date 12/7/2008 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, GYRO, IFR / CASANDRA, DEN / NEU w/ACAL, DIR, (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Cement Evaluation 5 Col 100 4975 Case 1/28/2009 CEL, USIT, GPIT, GR, CCL 24-Nov-2008 D ¢ Pds 17522..~ement Evaluation 100 4975 Case 1/28/2009 CEL, USIT, GPIT, GR, D CCL 24-Nov-2008 C Las 17588 -136nic 3325 4087 Open 2/18/2009 AIT, Sonic, TLD, MCFL, j Tens, GR, pt LIS Verification 213 5081 Open 2/20/2009 LIS Veri, FCNT, NPHI, NCNT, DRHO, RHOB, PEF, RPS, RPM, RPD, FET, GR, ROP, CALA D C Lis 17598{ Induction/Resistivity 213 5081 Open 2/20/2009 LIS Veri, FCNT, NPHI, NCNT, DRHO, RHOB, PEF, RPS, RPM, RPD, ~ FET, GR, ROP, CALA ~g Induction/Resistivity 25 Col 315 5081 Open 2/20/2009 MD ROP, DGR, EWR, ALD, CTN, ACAL 16-Nov- 2008 g Induction/Resistivity 2 Col 315 5081 Open 2/20/2009 MD ROP, DGR, EWR, ALD, CTN, MRIL-WD, ACAL, MRIAN HO 16-Nov- 2008 og Induction/Resistivity 5 Col 315 5081 Open 2/20/2009 MD ROP, DGR, EWR, ALD, CTN, MRIL-WD, ACAL, PreMRIAN HO 16- Nov-2008 • DATA SUBMITTAL COMPLIANCE REPORT 6/29/2010 Permit to Drill 2081590 Well Name/No. MILNE PT UNIT UGNU S-41 Operator BP EXPLORATION (ALASF(A) INC API No. 50-029-23401-00-00 MD 5081 TVD 4074 Completion Date 12/7/2008 Completion Status P8u4 Current Status P&A UIC N Log Induction/Resistivity 25 Col 315 4075 Open 2/20/2009 TVD DGR, EWR, ALD, CTN, ACAL 16-Nov-2008 Lo Induction/Resistivity 2 Col 315 4075 Open 2/20/2009 TVD DGR, EWR, ALD, CTN, ACAL MRIL-WD, MRIAN HO 16-Nov-2008 L Induction/Resistivity 2 Col 315 4075 Open 2/20/2009 TVD DGR, EWR, ALD, CTN, ACAL MRIL-WD, PreMRIAN HO 16-Nov- ~ 2008 e D C 17599 duction/Resistivity 315 5081 Open 2/20/2009 EWR logs in PDS, EMF and CGM graphics ~^ E C 18233( Sonic 0 0 Open 7/6/2009 Sonic PDS logs Log Sonic 5 Blu 4142 5057 Open 7/6/2009 MD BCSL, AIT, CNL, TLD, ~ ECS, HNGS, BHC 20-Nov- 2009 og Sonic 5 Blu 4142 5057 Open 7/6/2009 TVD BCSL, AIT, CNL, TLD, ECS, HNGS, BHC 20- Nov-2009 Gamma Ray 5 Blu 4142 5000 Open 7/6!2009 TVD NGR, AIT, CNL, TLD, ECS, HNGS, BHC 20-Nov- 2008 Gamma Ray 5 Blu 4142 5000 Open 7/6/2009 MD NGR, AIT, CNL, TLD, ECS, HNGS, BHC 20-Nov- 2008 L~ Induction/Resistivity 5 Blu 4142 5049 Open 7/6/2009 TVD Plat Ex, TCOM, AIT, CNL, TLD, ECS, HNGS, BHC 20-Nov-2008 I,,og Induction/Resistivity 5 Blu 4142 5049 Open 7/6/2009 MD Plat Ex, TCOM, AIT, CNL, TLD, ECS, HNGS, ' BHC 20-Nov-2008 C Asc Directional Survey 33 5081 Open 2/12/2009 pt Directional Survey 33 5081 Open 2/12/2009 • • DATA SUBMITTAL COMPLIANCE REPORT 6/29/2010 Permit to Drill 2081590 Well Name/No. MILNE PT UNIT UGNU S-41 Operator BP EXPLORATION (ALASKA INC API No. 50-029-23401-00-00 MD 5081 TVD 4074 Completion Date 12/7/2008 Completion Status P8~A Current Status P&A UIC N Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ N pp~~ ~~ Daily History Received? ~ N Chips Received? ~#~ ~~~Q Wq~\ Q,p,~.L ~ „y~ ~ Formation Tops ~/ N Analysis Y~ Received? Comments: ` pp `` ff ~~~~ ut_~S~ TV~ow~ o v1~t,ro~ e v~ C~.-q ~w.~i., ~. d ~0) t-~ Compliance Reviewed By: ___ ___.___ Date: ~-- ~l ~1 06/26/09 ~~I~m~~~~~~' N0.5289 Alaska Data t§ Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, Ak 99503-2838 Attn: Christine MahnkE~n ATTIV: Beth 333 West 7th Ave, Suite 100 .Anchorage, AK 99501 Well Job # Log Description Date BL Color CD • A-44 09AKA0048 OH MWD/LWD EDIT '°~' -~ 04/26/09 2 1 4-04AIT-30 09AKA0040 OH MWD/LWD EDIT 03/28!09 2 1 18-O1A 62WY-00003 MCNL 04/30/09 1 1 15-29B 09AKA0143 OH MWD/LWD EDIT 05/30/09 2 1 OS-35A 40017778 OH MWD/LWD EDIT ~U$'^ ~ 09!10/08 2 1 V-115L2 11962618 OH WIRELINE 08/22/08 1 1 MPS-41 11966289 OH WIRELINE ~~ /'"~'a^ 11/19/08 6 1 G-01A BOOR-00006 _ MCNL ~~'~.- ~ ~ 04/01/09 1 1 4-04A/T-30 BOCV-00014 CH EDI1 rv~.~-GR (SCMT) (REVISE DATA) - ~ ~ /27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) ~ 12/03/08 1 07-146 AYOO-00029 CH EDIT PDCL-GR (LDL) - L 05/26/09 1 I_3-08 AWL9-00028 RST / 06/11/09 1 1 ~.... .,......v v. ~.-v..n~ ~~~v~,r ~ ~r~ ~a1~alY11YV MIYV IIGI VIlIY11Y~] VIYG liVrT CNli ll 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • WELL L®G TRANSMITTAL To: State of Alaska February 6, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data MPS-41 AK-MW-6150038 1 LIS formatted CD with verification listing. API#: 50-029-23401-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com -~ r ~~~ ~.~.. Date: ~ ~`~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Signed: Q7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-41 February 10, 2009 AK-MW-6150038 MPS-41: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-23401-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-23401-00 2" x 5" MD MRIL PreMRIAN Logs: 1 Color Logs 50-029-23401-00 2" x 5" TVD MRIL PreMRIAN Logs: 1 Color Logs 50-029-23401-00 2" x 5" MD MRIL MRIAN Logs: 1 Color Logs 50-029-23401-00 2" x 5" TVD MRIL MRIAN Logs: 1 Color Logs 50-029-23401-00 Digital Log Images: 1 CD Rom 50-029-23401-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bry ~ °~;n.com ~~~-l5 ~ t'~ ~~ i Date: ~ -~ "~ Signed: ~% ~,~,~ nr~ HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-41 Dear Christine Mahnken 10-Feb-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey: 33.74' MD 0.00' MD (if applicable) 5,081.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 Date /~. F~~ q Signed (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) MY~-43 Y l ll correction (Y l ll#~~-1 "/6) • Maunder, Thomas E (DOA) From: Hanson, Paul [Paul.Hanson1@bp.com] Sent: Monday, February 09, 2009 2:05 PM To: Maunder, Thomas E (DOA) Cc: Crane, Lowell R; Kara, Danny T; Engel, Harry R Subject: MPS-41 (208-159) and MPS-41A (208-161) `l'om. its I indicated on Friday, here is my response to your inquiry o1' last. Thursday. Yage 1 of 3 1. Was the surface casing reciprocated while cementing? PU and SO weight is given for circulating the last joint down, but I don't find any mention of moving pipe thereafter. 'l"lie cas~~g «as lanelecl on a mandrel h~~ngcr. I.(3us it i~-as not mc.~ved eluring the cemcnt,job. 2. Was it intended to cut the 9-5/8" cement volume so "close"? '~Io, it ~~ as i:~ot plai~.necl to be so close;. I pl.anr~ed 150`;~<~ ~~cess through. th.c permafrost and ~{)°% e;xco.ss for the remainder'. A lesson learned. from ~~TI'S-~1 surface hole ~~%as the iollr~~~•ing: Because of the DLS<4 degrees/100' constraint for running a co-rod pump, we spent mare time than anticipated - both wiping out doglegs and trying to drill the line. We achieved our objective; however, the net result was a mare washed out hole than was anticipated. So on MPS-43 and 39 vre increased the excess to 200°/U across the permafrost. "l'hus, ~~~~; piztnl~ed enough cement......but just enough. 3. For running the 7" liner, were the 7" rams tested? Also, were the 2-7/8" x 5" tested on 2-7/8" for the inner string? It is stated on the report of the BOP test on12/6 that both rams were tested with 5" and 4- 1/2" test joints. It appears that you all planned accordingly to have the BOP equipped with rams to cover all the tubular combinations. I look forward to your reply. Call or message with any questions. ~~•~e dicl plan accordingl`, and did have rams (~l-1/?" x 7" and 2-7;`8" x ~" t%BRs} tlxat cc,uld test agai~~st T' az~d 2-7%8" pipe. E:lo~vever, the did trot actually test trio rams agai~~st 7" and ~ 7/8" pipe or test ,joint . "Phis ~~-as an iznforturiate oversight and i Dave infc~~-med our rnat~a=,?oment team. ~~'~ ~~-ill take tl~e folloe~-ing actions tc> ensure ful(complia~zce ~vifh the regulations. - C;o7~~nntnicate this ineiclent across AI)1,~' c>peratic.~ns anel in our Knc~tivlodge 11~-1ai~agenltY~tfl,csson5 Lear~~ed syste~r~ - ~pecity ram sizes that require testing for oath test cycle in e~-cry Well Plan T- I:trclude apprapriato 13{.}P.E testing requirornents its each. place for~~~ard docutne:nt generated ley the V'§''ell5~t~` I~~:i~.dlr4 Ifyou have any questions or concr;rres, please lot cne krcc>tiv -especially ~vitlc regard to tc.> our mitigation mc;asiz~•es for question _~ above: regarding B()PF testing. Since;rel`-. Paul I-Iat1SC3n 2/9/2009 ivir~-4s r i li correcuon ~r i li~t~u~- i i c~) rage ~ of 3 From: Hanson, Paul Sent: Friday, February 06, 2009 5:13 PM To: 'Maunder, Thomas E (DOA)' Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) Tom, 1 just wanted you to know that your inquiry below was forwarded to the wrong Paul Hanson in our address book. The Paul J Hanson listed below works in Landon, and he forwarded to me last night. I`ve been in meetings most of the day and only started sorting this out this afternoon. I will provide you with a complete response on Monday. Best Regards; Paul From: Hanson, Paul J Sent: Thursday, February 05, 2009 10:54 PM To: Hanson, Paul Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) From: McLellan, Bryan J Sent: 05 February 2009 19:50 To: Hanson, Paul J Cc: Stewman, Sondra D; Maunder, Thomas E (DOA) Subject: FW: MPS-41 (208-159) and MPS-41A (208-161) Paul, Please see Tom's note below. 1 think his questions are meant for you. Bryan From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 05, 2009 9:23 AM To: McLellan, Bryan J Cc: Stewman, Sondra D; Regg, James B (DOA) Subject: MPS-41 (208-159) and MPS-41A (208-161) Bryan, I am reviewing the 407 recently submitted for these wells. 1. Was the surface casing reciprocated while cementing? PU and SO weight is given for circulating the last joint down, but I don't find any mention of moving pipe thereafter. 2. Was it intended to cut the 9-5/8" cement volume so "close"? 3. For running the 7" liner, were the 7" rams tested? Also, were the 2-7/8" x 5" tested on 2-7/8" for the inner string? It is stated on the report of the BOP test onl2/6 that both rams were tested with 5" and 4- 1/2" test joints. It appears that you all planned accordingly to have the BOP equipped with rams to cover all the tubular combinations. I look forward to your reply. Call or message with any questions. Tom Maunder, PE 2/9/2009 STATE OF ALASKA RC ~~~~ ALASKA~L AND GAS CONSERVATION COM~SION ,JAN ~: 3 2009 ~~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas ~~ns. C~mmissiof~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/7/2008 12. Permit to Drill Number 208-159 308-362 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/08/2008 13. API Number 50-029-23401-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11 /15/2008 14. Well Name and Number: MPS-41 FEL, SEC. 12, T12N, R10E, UM 3224 FSL, 518 Top of Productive Horizon: 3858' FNL, 4209' FEL, SEC. 07, T12N, R11 E, UM 8. KB (ft above MSL): 71.53' Ground (ft MSL): 37.79' 15. Field /Pool(s): Milne Point Unit / Ugnu Total Depth: 4060' FNL; 3902' FEL, SEC. 07, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 4140' 4140' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 565493 y- 5999889 Zone- ASP4 10. Total Depth (MD+TVD) 5081' 4074' 16. Property Designation: ADL 380110 TPI: x- 566607 y_ 5998096 Zone- ASP4 - 5997897 Zone- ASP4 th: x- 566917 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No S ni nd rin d i f i n r 2 25. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, GYRO, IFR / CASANDRA, DEN / NEU w/ACAL, DIR, MRIL / GABI, 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 9 H-4 1 1 6 Ar i r 7" 4 77' 407 ' -1 la ' 23. Open to production or inject ion? ^Yes ®No 24. TuawG RECORD If Yes, list each i MD+TVD m P f T & B tt nterval open n Size and Number): rf r ti SIZE DEPTH SET MD PACKER SET MD ; ( o op o o e o a o None 4-1/2", 12.6#, L-80 (Kill String) 2153' None MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 4650' Set EZSV with 11.5 Bbls of Class 'G' on top 4140' P&A with 25 Bbls Class'G' 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CBSIng Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ®Yes ^ No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. See Attached documents. (Please note Laboratory Analytical results will be submitted once available from Lab). ~ ~li .L~ .`r`i`p ±. ~~ ~ ~ ~ I~ ~ 2909 Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE • C~ '28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top 37.79' 37.79' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1451' 1435' detailed test information per 20 AAC 25.071. MDT Ran Summary Attached SV2 2039' 1978' TUZC 4072' 3440' M87S 4423' 3637 M87F 4550' 3717' M80T 4582' 3738' M80_1 RFlood 4665' 3794' M80S 4807' 3888' M70S 4880' 3937 M68F 4904' 3953' M68S 4957' 3989' Formation at Total Depth (Name): Ugnu / M80T 4582' 3738' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Recovered Sidewall Core Points and MDT Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ndra Stewm .---Title Drilling Technologist Date l " MPS-41 208-159 308-362 Prepared ByNamenVumber. Sondra Stewman, 564-4750 Well Number A r Drilling Engineer: paul Hanson, 564-4195 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this fomt and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only ~~~ ~ ~ ~ ' ~~ ~ l'N. 1~ ,. BPXA ,`; MPS-41 P & A Schematic Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" 5K Soud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casina 436 Bbls, 10.7 ppg g-5/g" DeepCrete 471bs/ft 150% Excess L-80, In Permafrost BTC-M 40% below PF Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 45 bbls,12.0 ppg TOC (pre ST) 4045' DeepCrete Casing Point 4,147 3,480' ~~. 12-1/4" Casing Cut 4,277 ~ 7~ Cla s G ES Cementer at 4297 M87S M87F (Ugnu Ma) 15.8 Class G M80T Prod.. Casina MWD/GR/RES M80L Perf int. 7" Neu/Den w/ACA M80_t Rflood 15.8 Class G ;EZSV tagged 26 Ibs/ft MRIUGABI EZSV 4,650' tested L-80, M80L Perf int. 9.3 ppg brine BTC-M M-80S Int. Yield 7240 psi Collaspse 6600 psi M70S/SBF2-Top NA Top NB (f/ MPS-11) 47° TD 5,081' 4,075' 47° 8-1/2" 1/12/2009 MPS-41 P and A Schematic_Actual.xls t I • BP Page 1 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date:. 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2008 16:00 - 17:30 1.50 MOB P PRE 17:30 - 18:30 1.00 MOB P PRE 18:30 - 20:30 2.00 MOB P PRE 20:30 - 21:00 0.50 MOB P PRE 21:00 - 22:00 1.00 MOB P PRE 22:00 - 00:00 2.00 MOB P PRE 11/6/2008 00:00 - 04:00 4.00 MOB P PRE 04:00 - 08:30 4.50 MOB P PRE 08:30 - 10:30 2.00 MOB P PRE 10:30 - 12:00 1.50 MOB P PRE 12:00 - 13:00 1.00 MOB P PRE 13:00 - 15:30 2.50 RIGU P PRE 15:30 - 19:00 3.50 RIGU P PRE 19:00 - 22:00 ~ 3.00 ~ RIGU ~ P ~ ~ PRE 22:00 - 00:00 2.00 RIGU P PRE 11/7/2008 00:00 - 00:30 0.50 RIGU P PRE 00:30 - 02:30 2.00 RIGU P PRE 02:30 - 12:00 9.50 RIGU P PRE 12:00 - 14:00 2.00 RIGU P PRE 14:00 - 14:30 0.50 RIGU P PRE 14:30 - 20:00 5.50 RIGU P PRE 20:00 - 20:30 0.50 RIGU P PRE Blow Down lines on Rig Floor. -Prep Floor to skid. Skid Rig Floor to MOB Position. Move Rig off of well. -Spot rig by entrance of L pad. Prep Cellar for Move: -Remove Heaters. -Remove Mouse Hole. -Remove Doors from Cellar. Prep Cellar for Move: -Install Boosters. Moving Rig: -Move rig from L pad to V Pad. Continue Moving Rig from L-Pad. -Move rig from V pad to Milne point turn off. .Move Rig from MPU turn off to S-pad. Spot rig on MPS Pad. -Remove rear Booster Tires. -Set Rig Mats around Well. Spot Rig over MPS 41 Well. -Shim Rig in Place. PJSM for Skidding Rig Floor. -Skid Rig Floor to Drilling Position. RU Rig Floor. -Hook Up Conveyor. Install Surface Stack. -Install 4" Valves on Conductor. -Install Mouse Hote. -Install Cellar Doors. -Prepare Pits for Mud. Offload Spud Mud into Pits. -_Acceat riq ~ 16:00 hrs. Inspect Derrick and Top Drive. -Change Saver Sub on Top Drive to 4-1/2" IF. -Change Screens on Shaker (125, 100 mesh). -Send Riser to Welding Shop to have shortened by 3'. Install Riser and Turn Buckles. -Install Flow Line and Flow Line covers. Install Turn buckles on Riser. Install Diverter Line in Cellar. Load in Pipe Shed: -5" HWDP. -8" Non-Mag DC's. -5" DP. All crews go to camp for MPU ATP meeting. -Motor man left on Rig. Service Rig. Inspect derrick. -PJSM on PU 5" DP. PU 5" DP from pipe shed 1 X 1. -Rack back 48 Stds of DP. Diverter Function test: -Knife Valve on Diverter Line - 2 secs for Knife to full open. -29 seconds for Hydril to Close. -20" MSP 2000 Hydril - ~ ~ BP Page 2 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/7/2008 20:00 - 20:30 0.50 RIGU P PRE -Accumulator: 200 psi increase = 32 secs. -Full pressure 2 min. 39 secs. -4 bottles 2200 psi. AOGCC test witness waived by Bob Noble. 20:30 - 21:30 1.00 RIGU P PRE PU HWDP. -Hole Clear to 90' md. -PU Jars, Non Mag DC's, Rack Back in Derrick. 21:30 - 00:00 2.50 RIGU P PRE MOB BHA to Rig Floor. -Clear Floor of all Tools not needed. -RUG ro E ui ment. 11/8/2008 00:00 - 01:00 1.00 RIGU P PRE Continue to RU Gyro Equipment. 01:00 - 02:30 1.50 RIGU P PRE PU BHA #1 -MU 12.25" Bit. -PU Motor. Load Batteries in ABI. -MU Float Sub, UBHO and Orient. -MU 1 Stand HWDP. 02:30 - 03:00 0.50 RIGU P SURF Hold Pre Spud Meeting with Crew. -Fill Stack and check for Leaks. 03:00 - 05:00 2.00 DRILL P SURF S ud in ~ 03:00 hrs. -Drill 1 Stand down. -RU and Run Gyro. -Drill second stand down to 230' md. -Pump Rate of 504 gpm ~ 800 psi. 05:00 - 07:00 2.00 DRILL P SURF Continue drilling ahead....from 230'to 316' and -Gyro as needed from 112' to 316' and 07:00 - 07:30 0.50 DRILL P SURF POH stand back HWDP. 07:30 - 10:00 2.50 DRILL P SURF PU & MU MWD tools. 10:00 - 11:00 1.00 DRILL N RREP SURF Replace cable on skate. 11:00 - 12:00 1.00 DRILL P SURF Continue to MU MWD tools. 12:00 - 15:00 3.00 DRILL P SURF MU: TM, UBHO sub. -Upload MWD. PU 1 NM Flex collar. -PJSM on Nukes -Load Nukes. -PU: 2 NM Flex collars, XO, 1 Std HWDP. -Shallow pulse test MWD. Set MWD depth. 15:00 - 00:00 9.00 DRILL P SURF Set Block height f/ MWD. -Drill f/ 316' to 900' md. -PUW 101 k, SOW 98k, ROT wt 100k, -462 gpm / 1260 psi. ART - 5.64 hrs AST - 1.55 hrs ADT - 7.19 hrs 11/9/2008 00:00 - 05:00 5.00 DRILL P SURF Continue to directionally drill 12 1/4" surface hole from 900' to 1,298' md. -PUW 103k, SOW 101 k, ROT wt 103k, gpm 405 / 1550 psi on Btm. -1390 psi off Btm, 2-5k Tq ~ 80 RPM, WOB 25k. 05:00 - 12:00 7.00 DRILL P SURF Continue to directionally drill ahead. -Drill from 1,298' to 1,815' md. -PUW 117k, SOW 112k, Rot wt 115k. -GPM 500 / 1940 psi on, 1720 psi off. -Tq 2k on, Tq 2k off ~ 80 RPM, WOB 25k. ~ ~ BP Page 3 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~ 11/9/2008 ~ 05:00 - 12:00 ~ 7.00 ~ DRILL ~ P 12:00 - 15:30 ~ 3.50 ~ DRILL ~ P 15:30 - 16:30 ~ 1.00 ~ DRILL ~ P 16:30 - 18:00 1.50 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 00:00 I 5.00 DRILL I P ~ 11/10/2008 ~ 00:00 - 05:00 ~ 5.00 ~ DRILL ~ P 05:00 - 12:00 I 7.00 I DRILL I P 12:00 - 00:00 12.00 I DRILL I P X11/11/2008 X00:00-00:30 ~ 0.50~DRILL ~P SURF AST - 2.48 hrs. ART - 3.4 hrs. ADT - 5.88 hrs. SURF Directionally drill from 1,815'to 2,265' md. -PUW 123k, SOW 114k, ROT wt 120k. -GPM 500 / 1700 psi on, 1680 psi off. -Tq 3k on, Tq 2k off ~ 80 RPM, WOB 25k. -Increase pump rate to: -550 gpm w/ 2000 psi on & 1950 psi off. SURF Circulate bottoms up X 2. -550 gpm / 1930 psi. -MW in = 9.4 ppg. MW out = 9.45 ppg. SURF Pump out of the hole ~ Drlg rate. -550 gpm / 1900 psi. SURF RIH from 759' to 2,172' md. -Wash down from 2,175' to 2,265' md. -No fill noted. SURF Drill ahead from 2,265' to 2,551' md. -PUW 131k, SOW 115k, ROT wt 127k. -GPM 550 / 1890 psi on, 1840 psi off. -Tq 4k on, Tq 3k off ~ 80 RPM, WOB 25k. AST - 1.58 hrs. Total daily AST - 4.06 hrs. ART - 1.1 hrs. Total daily ART - 4.5 hrs. ADT - 2.68 hrs. Total daily ADT - 8.56 hrs. SURF Continue directionally drilling ahead. -Drill from 2,551' to 2,962' md. -PUW 135k, SOW 115k, ROT wt 125k. -GPM 550 / 2170 psi on, 1940 psi off. -Tq 5k on, Tq 3k off ®80 RPM, WOB 10-20k. SURF Continue directionally drilling ahead. -Drill from 2,962' and to 3,615' md. -PUW 145k, SOW 115k, ROT wt. 130k. -GPM 550 / 2,070 psi off, 2,230 psi on. -Tq 4k off / 6k on ~ 80 RPM. -WOB 15-20k. ART - 3.51 hrs. AST - 3.51 hrs. ADT - 7.02 hrs. SURF Continue directionally drilling ahead. -Drill from 3,615' and to 4,030' md. -PUW 150k, SOW 117k, ROT wt. 132k. -GPM 550 / 2,080 psi off, 2,140 psi on. -Tq 7k off / 9k on ~ 80 RPM. -WOB 15-20k. ART - 1.58 hrs. Total ART - 5.09 hrs. AST - 1.44 hrs. Total AST - 4.95 hrs. ADT - 3.02 hrs. Total ADT - 10.04 hrs. SURF Continue directional drilling ahead. -Drill from 4,030' and to 4,052' md. B F Page 4 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/11/2008 00:00 - 00:30 0.50 DRILL P SURF -PUW 150k, SOW 117k, ROT 134k. -GPM 550 2,070 psi off / 2,260 psi on. -RPM 80 ~ 6k off / 7-10k on. -WOB 30k. 00:30 - 02:00 1.50 DRILL P SURF Circulating BU for Samples. -Evaluate Logs. 02:00 - 03:00 1.00 DRILL P SURF h t -Drill from 4,052' and to 4 147' and (3,480' tvd) -PUW 150k, SOW 117k, ROT 135k. -GPM 550 ~ 2,100 psi off / 2,270 psi on. -RPM 80 ~ 7k off / 8-10 k on. -WOB 30k. ART - 0.23 hrs. Total ART - 16.48 hrs. AST - 0.67 hrs. Total AST - 12.46 hrs. ADT - 0.93 hrs. Total ADT - 28.94 hrs. 03:00 - 04:30 1.50 DRILL P SURF Circulating Hole clean. -Rotate ~ 80 RPM, Reciprocate. -GPM 550 ~ 2,010 psi. 04:30 - 08:00 3.50 DRILL P SURF Pump out of hole. (From 4,146' and to 1,449' md) -GPM 550 ~ 2,000 psi. 08:00 - 11:00 3.00 DRILL P SURF Mad Pass from 1,449' and to 1,061' md. (Recorded) -180 FPH ~ 35 RPM. 11:00 - 11:30 0.50 DRILL P SURF Continue to pump out of hole. (From 1,061' and to 759' md). -GPM 550 ~ 2,000 psi. -Flow check well - No Flow. 11:30 - 13:30 2.00 DRILL P SURF RIH from 759' and to 4,054" md. -Wash down last stand from 4,054' and to 4,147' md. -GPM 450 ~ 1,530 psi. No problems. No fill observed. 13:30 - 15:00 1.50 DRILL P SURF Circulate 2 BU to clean hole. -GPM 450 ~ 1,530 psi. -Rotate and Reciprocate ~ 90', RPM 60 - Torq 6k. 15:00 - 19:00 4.00 DRILL P SURF Pump out of Hole. (From 4,147' and to 759' md.) -GPM 450 ~ 1,400 psi. -Flow Check well - No Flow 19:00 - 23:30 4.50 DRILL P SURF LD BHA: -Rack Back SWDP, and Jars. -LD 2 Flex DC's. -PJSM on Nukes, Removed Nukes. -Download MWD. -LD Flex DC, TM, Nuke tool, RLL, DM, XO, Stab., Float Sub. -Drain Motor, Break Bit off and LD Motor. 23:30 - 00:00 0.50 DRILL P SURF Clean and Clear Rig Floor. 11/12/2008 00:00 - 00:30 0.50 DRILL P SURF Clear rig Floor of MWD Tools. 00:30 - 01:00 0.50 DRILL P SURF Lubricate Rig. -Inspect Top Drive. 01:00 - 03:00 2.00 CASE P SURF Ri U to run 9-5/8" 47# L80 BTC-M CSG. -RU Franks Tool, Csg tongs. -RU Long bails, Slips. -PU Safety Valve. (9-5/8" X 1502 Swage w/full opening) 03:00 - 10:30 7.50 CASE P SURF Run 106 Jts. 9-5/8" 47# L80 BTC-M CSG. DAMn.i• 19/3l1Mf1l1R 1T'id~11 PM BP Page 5 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2008 03:00 - 10:30 7.50 CASE P SURF - Utilized Best-O-Life 2000 Thread Compound. -Run 1 straight Bladed Centrilizer on First 25 Jts. -Baker Lock all jts below Float Collar. -Fill every Jt w/ Franks tool. -Break Circulation every 25 Jts. -Circulate last jt. Down. ~ 210 gpm / 370 psi. -PUW 237k. SOW 150k. Noted tight spots ~ -2,400' and & -3,820' md. Circulate and wash through spots noted above. 10:30 - 11:00 0.50 CASE P SURF MU Hanger and Landing Jt. -Remove air slips. -Land Casing w/ Shoe ~ 4,140' md. 11:00 - 13:30 2.50 CASE P SURF Circulate hole Clean. -Stage up from 126 gpm to 336 gpm ~ 490 psi. -Condition Mud for Cement Job. Lower yP. 13:30 - 17:00 3.50 CEMT P SURF PJSM -Schlumberger pump 5 bbls water. -Test lines to 3,000 psi. -Pump 70.5 bbls 10 ppg Mud Push ~ 210 gpm / 150 psi. -Drop bottom plug. -Pum 436 bbls 10.7 Lead Dee CRETE) ~ 294 gpm / 230 psi. -Pump 45 bbls 12 0 pag Tail (Deep CRETE) ~ 210 gpm / 260 psi. -Drop Top Plug. -Kick Plug out with 10 bbls water. -Schlumberger turned pumping over to rig. -Rig Pumped 283 bbls bumped plug ~ 126 gpm / 530 psi. -Pressure u to 1 500 si for 10 min. Charted .Good Test. -Check Floats. -CIP at 17:00 hrs. eived 12 bbls cement to surface. 17:00 - 20:30 3.50 CEMT P SURF PJSM -Flush Diverter X 3. -Clean Casing Tools. -LD Landing Jt. -LD Tools not needed. 20:30 - 00:00 3.50 DIVRTR P SURF PJSM - ND Diverter. -Remove Flow Line. -Remove Turnbuckles, Bleed off Line. -Remove Hole Fill Line. -LD Riser, ND Diverter Line, ND Accumulator Lines. -ND Diverter Spool -Install Csg Speed Head, Tbg Spool. -Test Csg Speed Head Void to 1,000 psi. for 15 Min. Good Test. 11/13/2008 00:00 - 03:00 3.00 BOPSU P PROD1 NU Tubing Spool. -NU BOPE's. -Extend Choke Line. -NU Riser and Flow Line. 03:00 - 04:00 1.00 BOPSU P PRODi RU to Test BOPE. -Install Test Plug. 04:00 - 11:00 7.00 BOPSU P PROD1 BOPE Test: c~~rod• i~iannnnR 1T3d~11 PM a • BP Page 6 of 32 Operations Summary Report 11:00 - 11:30 0.50 BOPSU P 11:30 - 12:00 0.50 DRILL P 12:00 - 13:30 1.50 DRILL P 13:30 - 14:00 I 0.501 DRILL P 14:00 - 16:30 2.50 DRILL P 16:30 - 17:00 I 0.501 DRILL I P 17:00 - 17:30 0.50 DRILL P 17:30 - 18:30 ~ 1.00 ~ CASE ~ P 18:30 - 21:30 ~ 3.00 ~ DRILL ~ P 21:30 - 23:00 I 1.501 DRILL ~ P PROD1 -PJSM for testing BOPE's. -Be in testin BOPE's. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool -2 7/8" X 5" Variables. Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 5" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test choke valve #7. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Top & bottom Rams w/ 5" test joint. -All tests are a Pass. Accumulator: -33 seconds for 200 psi increase. -2 minutes 45 seconds for full pressure. -Bottles 4 X 2200 psi. -Test witness waived by John Crisp AOGCC. -Test witnessed by Well Ske Leaders. PRODi RD test equipment. -Pull test plug. PRODi Install Wear ring. PROD1 RD Floor Valves. -Install Bails and Elevators. -MOB BHA to Rig Floor. PROD1 MU BHA, Blt, Bit Sub, Float Sub. -PU 3 NMDC's, SWDP, and Jars. PROD1 PU DP 5" DP from pipe shed. -PU 1X1 for 7 Stds. RIH f/derrick to 4,051' and . -Fill pipe ~ 2,531' md. PROD1 Circulate BU ®4,051' md. -GPM 411 ~ 460 psi. PROD1 Mouse hole 1 jt of 5" DP. -Blow down Top Drive. -RU to Test Csg. PROD1 Test 9 5/8" 47# L-80 BTC-M Csg. -Fill lines. -Test Csg to 2 500 psi for 30 min. (Chartedl Good Test_ -RD Test Equipment. PROD1 Slip and Cut Drilling Line: -PJSM for Slip and Cut. -Cut 1,600' of Drilling Line. PROD1 Drill Float equipment. -Drill from 4,058' and to 4,140' md. -Drill out Float collar, Shoe & 20' of new hole to 4,167' md. Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~ 11/13/2008 ~ 04:00 - 11:00 ~ 7.00 ~ BOPSUF~ P BP Page 7 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/13/2008 21:30 - 23:00 1.50 DRILL P PROD1 - PUW 145k, SOW 110k, ROT wt 125k. - 420 gpm / 500 psi. Tq 7k ~ 80 RPM. 23:00 - 00:00 1.00 DRILL P PROD1 Circulate hole clean. Rotate & reciprocate. -420 gpm / 510 psi. 11/14/2008 00:00 - 01:30 1.50 DRILL P PROD1 Displace to 9.4 ppg Bland coring fluid. -420 gpm / 680 psi. -Reciprocate & rotate during displacement. 01:30 - 02:30 1.00 DRILL P PROD1 Stand back 1 Std. RU test equipment to perform LOT ~ 3 SPM. -760 si leak off ressure w/ 9.4 mud ~ 3 480 TVD. -EMW= 13.6 . RD test a ui ment. 02:30 - 04:00 1.50 DRILL P PROD1 Drill ahead from 4,167' to 4,265' md. -PUW 140k, SOW 100k, ROT wt 120k. -450 gpm / 920 psi off / 1040 psi on. -Tq 7k r,~ 80 rpm. WOB 25k. 04:00 - 04:30 0.50 DRILL P PROD1 Circulate hole clean 450 gpm / 920 psi. -Monitor well -Static. -MW in 9.4 ppg. MW out 9.4 ppg. 04:30 - 07:30 3.00 DRILL P PROD1 POH w/ cleanout BHA on 5" DP. -LD BHA. 07:30 - 08:00 0.50 DRILL P PROD1 Clean Rig Floor. 08:00 - 08:30 0.50 DRILL P PRODi MOB MWD tools to Rig Floor. -Hook Up Geo Skid. 08:30 - 09:00 0.50 DRILL P PROD1 Service Rig: -Grease Blocks, Top Drive, and Draw works. 09:00 - 12:30 3.50 DRILL P PROD1 PJSM for PU BHA. -MU BHA. 12:30 - 13:00 0.50 DRILL P PROD1 Shallow Test MWD. -Pulse Test MWD. Good Test. 13:00 - 15:00 2.00 DRILL P PROD1 RIH from 339' to 4,110' md. -Filled pipe ~ 2,321' md. 15:00 - 15:30 0.50 DRILL P PRODi Filled Pipe and check MWD. -No Pulse from MWD. -Trouble Shoot MWD. 15:30 - 16:00 0.50 DRILL N DFAL PROD1 POH from 4,110' to 2,321' md. -Wet trip pipe. 16:00 - 16:30 0.50 DRILL N DFAL PROD1 Test MWD. -Pulse Test MWD. No Good. 16:30 - 18:00 1.50 DRILL N DFAL PROD1 POH from 2,321' to 339' md. -Wet trip Pipe. 18:00 - 18:30 0.50 DRILL N DFAL PROD1 Test MWD. -Pulse Test MWD. Good Test. 18:30 - 19:00 0.50 DRILL N DFAL PROD1 Rack Back 1 Stand SWDP. -Rack Back 1 Stand NMFC. 19:00 - 20:30 1.50 DRILL N DFAL PROD1 Download MRIL. -PJSM on Nukes and Remove. -Download MWD. -LD MRIL, TM. -Replace Pulser. -MU TM, MRIL. 20:30 - 23:00 2.50 DRILL N DFAL PROD1 MU float sub, Stabilizer, 1 Std NMFC, 1 Std SWDP. 23:00 - 23:30 0.50 DRILL N DFAL PROD1 Pulse test MWD 550 gpm / 1350 psi. -Blow down Top Drive &Geo-Span. c~„ro~~ ~~isnnnne 12.3411 PM ~. BP Page 8 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2008 23:30 - 00:00 0.50 DRILL N DFAL PROD1 RIH w/Geo-pilot on 5" DP from 431' to 900' md. 11/15/2008 00:00 - 02:00 2.00 DRILL N DFAL PRODi Continue to RIH f/ 900' to 4,155' md. -Pulse test MWD every 10 Stds. -PUW 115k, SOW 100k, ROT wt 115k. -Tq 5k ~ 10 RPM. 02:00 - 03:30 1.50 DRILL P PROD1 MU Top Drive. Wash down, Rotate f/ 4,155' to 4,266' md. -Tq 5-7 k ~ 10 RPM. 03:30 - 12:00 8.50 DRILL P PROD1 Directionally drill ahead from 4,266' to 4,667' md. -PUW 138k, SOW 103k, ROT wt 120k. -WOB 7-15k, Tq 6k ~ 120 RPM on Btm. -Tq off Btm 4-5k. 450 GPM. -Pressure on Btm 1720 psi, off Btm 1670 psi. ART - 7.68 hrs. 12:00 - 00:00 12.00 DRILL P PROD1 Directionally Drill ahead f/ 4,667' and to TD ~ 5,081' and / 4 075' tvd. -PUW 162k, SOW 114k, ROT wt 132k. -Tq on 7-9k, off 7k. 450 GPM. -Pressure on Btm 1,750 psi, off Btm 1,650 psi. ------------Formation Tops------------ -M80T = 4,572' md. -M80S = 4,808' md. -M70S = 4,890' md. -Nb = 4,940' md. ART - 10.52 hrs. Total daily ART = 18.20 hrs 11/16/2008 00:00 - 00:30 0.50 DRILL P PROD1 Circulate /Geo discussion w/ Asset group. -440 gpm / 1540 psi. -Set Geo-pilot into home position. ------------Formation Tops------------ -M80T = 4,572' md. -M80S = 4,808' md. -M70S = 4,890' md. -Nb = 4,940' md. 00:30 - 10:30 10.00 DRILL P PROD1 Pump out of hole for MAD pass per geologist. -Pump out from 5,081' to 4,251' and -420 gpm / 1500 psi. -Rig crew pertorm hazard hunt. 10:30 - 11:00 0.50 DRILL P PROD1 Observe well -static. -RIH f/ 4,251' to 5,081' md. -PUW 165k, SOW 115k, ROT wt 135k. -Tq 5k ~ 50 RPM. 11:00 - 12:30 1.50 DRILL P PROD1 Condition Mud for logging. -Circulate two surface to surface volumes. -450 gpm / 1250 psi. 12:30 - 13:30 1.00 DRILL P PROD1 Observe well -static. -Drop rabbit w/ wire. -Pump out of the hole f/ 5,081' to 4,110' md. c~~,od• »isnnnna i2sa:n PM BP Page 9 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2008 12:30 - 13:30 1.00 DRILL P PROD1 - 400 gpm / 1080 psi. 13:30 - 14:00 0.50 DRILL P PROD1 CBU. Blow down Top Drive. -Observe well -static. ' 14:00 - 16:00 2.00 DRILL P PROD1 POH wet from 4,110' to BHA ~ 155' and 16:00 - 19:30 3.50 DRILL P PRODi LD BHA: -LD Stab & Float sub. -Plug in MRIL tool. PJSM on nukes. -Remove nukes from tool. -Down load MWD. Flush BHA w/ water. -LD MRIL, TM, Nuke tool, HCIM, Smart stab, EWR. -LD Geo-Flex, Geo-pilot & Bit. -Rig crew perform hazard hunt. 19:30 - 21:00 1.50 DRILL P PRODt Clear Rig floor of all tools not needed for upcoming operations. -Clean Rig floor. 21:00 - 00:00 3.00 DRILL P PROD1 PJSM. -PU SLB E-line tools to Ri floor. -MU Tools. 11/17/2008 00:00 - 01:30 1.50 EVAL P PROD1 PJSM... -DP conveyed Logs. Check wet head connection. 01:30 - 03:30 2.00 EVAL P PROD1 MU XO. RIH w/ 5" DP from 167' to 3,815' md. -Circulate every 1,000'. 126 gpm / 180 psi. 03:30 - 04:00 0.50 EVAL P PRODi Circulate pipe volume. -PU SLB E-line tools & equipment. 04:00 - 07:30 3.50 EVAL P PRODi PJSM... -RU sheaves. MU Side door entry sub. -Pump down Wet Head. Latch up. Secure cable in door. 07:30 - 15:00 7.50 EVAL P PROD1 RIH w/ logging tools & 5" DP from 3,815' to 4,337' md. -4~ 4.670'. 4.698'. 4,715', 4,716', 4,790', 4,792', 4,830', 11/18/2008 I00 00 - 012:00 I 12 OO I EVAL I P 12:00 - 00:00 ~ 12.00 ~ EVAL ~ P 11 /19/2008 ~ 00:00 - 03:30 ~ 3.50 ~ EVAL ~ P 03:30 - 04:30 1.00 I EVAL I P 04:30 - 06:30 2.00 EVAL P ---all depths = md. -PUW 143k, SOW 112k. PRODi Begin sampling formation. -Formation Sam le ints 4 895' & 4 755' md. PRODi Continue Schlumberger taking MDT fluid samples w/ tools ~ 4 755' and 4696' md. -Rig crew continues to clean, scrub, paint and work on Rig. PRODi Continue Schlumberger taking MDT fluid samples w/ tools ~ 4 635' and 4628' md. -Rig crew continues to clean, scrub, paint and work on Rig. -Sam lin ~ 4635' failed due to lost seal while s m ling. Moved tools up to 4628' md. -PUW 140k /SOW 112k PROD1 Continue Schlumberger taking MDT fluid samples w/ tools ~ 4628' md. -Take pressure values ~ 4610', 4600', 4595' and 4585' -Rig crew continues to clean, scrub, paint and work on Rig. PROD1 POOH f/ 4585' to 3777', until side entry sub ~ rotary table. PROD1 -RD side entry sub. -Pull off wet connector f/ head. Printed: 12/30/2008 12:34:11 PM i BP Page 10 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC... Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/19/2008 04:30 - 06:30 2.00 EVAL P PROD1 -Pull a-line out of drill pipe. -LD side entry sub and sheaves 06:30 - 08:00 1.50 EVAL P PROD1 Cont. POOH 5" DP w/ MDT logging assy. f/ 3777' to surface. 08:00 - 11:00 3.00 EVAL P PROD1 LD MDT to in ass .Clear ri floor 11:00 - 12:00 1.00 EVAL P PROD1 MU cleanout BHA w 8-1/2" tricone bit + 1 jt NMDC + Stabilizer + 2 jts NMDCs + 3 jts 5" HWDP +jars + 2 jts 5" HWDP. 12:00 - 12:30 0.50 EVAL P PROD1 Service top drive, blocks and drawworks. 12:30 - 14:30 2.00 EVAL P PROD1 RIH w/ cleanout BHA to TD ~ 5081'. -Fill pipe ~ 2180' and 4140'. -Wash last stand to bottom. 14:30 - 16:00 1.50 EVAL P PROD1 Circulate until hole clean. Rotate and reciprocate pipe while circulating. -110 RPM ~ 7k torque / ROTW 133k. -504 gpm ®890 psi. 16:00 - 17:00 1.00 EVAL P PRODi Pump out of the hole f/ 5081' to 4062' (inside 9-5/8" shoe). 17:00 - 17:30 0.50 EVAL P PROD1 CBU. 546 gpm ~ 870 psi. -Blow down top drive -Flow check well. 17:30 - 19:00 1.50 EVAL P PROD1 Cont. POOH f/ 4062' to 290' (BHA) 19:00 - 20:00 1.00 EVAL P PRODi -Rack Back HWDP and NMDCs. -LD Stabilizer, float sub, bit sub and bit. 20:00 - 20:30 0.50 EVAL P PROD1 Clear rig floor of tools not needed for next operations. Clean rig floor. 20:30 - 22:30 2.00 EVAL P PROD1 r - ~ i 22:30 - 00:00 1.50 EVAL P PROD1 -RIH w/ logging tools on a-line to TD (5083' WLM).. 11/20/2008 00:00 - 01:30 1.50 EVAL P PROD1 -Continue log section in 8-1/2" hole f/ 4900' to 4200'. (AIT/CN UTLD/ECS/HNGS/BHC) -POOH a-line w/ logging tools to surface. 01:30 - 03:00 1.50 EVAL P PROD1 RD & LD logging tools. 03:00 - 04:00 1.00 EVAL P PROD1 Check and prepare firing head. 04:00 - 05:30 1.50 EVAL P PRODi Mobilize to rig floor and RU sidewall core tools. -Radio silence when arming tools on rig floor and until tools ~ 200' below rotary table. 05:30 - 09:30 4.00 EVAL P PROD1 RIH w/sidewall core tools nn a-lire Attempt 45 sidewall cores. Misfire 19, recover 26: 4858' - _ 4856' 4845' 4831' 4805' 4656' 4654' 4653' 4646' 4638' 4627' 4620' 4611' 4602' 4595' 4587' 4581' 4554' 4530' ndoo~ ddiQ' daaa~ asaa' d348'_ 4335' and 4310'. -POOH to 200' 09:30 - 11:00 1.50 EVAL P PROD1 -Establish radio silence. -POOH f/ 200' to surface. -LD sidewall core tools. -Fire test head. PU sidewall core tools. 11:00 - 12:00 1.00 EVAL N DFAL PROD1 -Establish radio silence. -MU sidewall core tools and RIH to 200'. 12:00 - 15:00 3.00 EVAL N DFAL PROD1 RIH w/sidewall core tools on a-line -Attem t 24 sidewall cores. Misfire 18 recover 6: 4805', 4799', 4784' and 4772' -POOH to 200' 15:00 - 17:30 2.50 EVAL N DFAL PROD1 -Establish radio silence -POOH f/ 200' to surface. LD sidewall core tools. .,__._~. ,o~onnnno ,rnvn•,~ one BP Page 11 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/20/2008 15:00 - 17:30 2.50 EVAL N DFAL PRODi - PU and MU sidewall core tools. RIH to 200' 17:30 - 22:00 4.50 EVAL N DFAL PROD1 RIH w/ sidewall core tools on a-line. -Attempt 21 sidewall cores Misfire 1 recover 20: 4722', 472.0 4715' 4710' 4700' 4698' 4691' 4685' 4678' 4675' 4 71' 4761' 4743' 4735' .4731' 4870' 481 4 -POOH to 200'. Establish radio silence. -POOH to surface. LD tools 22:00 - 23:30 1.50 EVAL P PROD1 RD Schlumberger a-line equipment. 23:30 - 00:00 0.50 BOPSU P PROD1 Function test BOPs~ top rams, blind rams, bottom rams, annular preventer, HCR kill and HCR choke (use one stand 5" DP to function test top and bottom rams and annular preventer). 11 /21!2008 00:00 - 00:30 0.50 CASE P PROD1 MU cleanout BHA: 8-1/2" tricone bit + bit sub + float sub + 1 jt NMDC + stabilizer + 2 jts NMDC + 3 jts 5" HWDP + jars + 2jts 5" HWDP. 00:30 - 03:00 2.50 CASE P PROD1 RIH w/ cleanout BHA f/ 290' to 5000'. -Fill pipe ~ 2180' and 4125'. -Obtain parameters: PUW 150k /SOW 115k / ROTW 130k. -Establish circulation ~ 504 gpm / 950 psi. Rotate down to TD ®5081'. 03:00 - 05:00 2.00 CASE P PROD1 CBU 4x and condition mud, 504 gpm ~ 950 psi. Rotate and reciprocate, 110 RPM / 7k torque. 05:00 - 06:00 1.00 CASE P PROD1 Pump out of the hole to the shoe. 06:00 - 06:30 0.50 CASE P PROD1 CBU ~ shoe. 504 gpm ~ 740 psi 06:30 - 08:30 2.00 CASE P PRODi -Blow down top drive. -Flow check well. -POOH to 290' (BHA) 08:30 - 10:00 1.50 CASE P PROD1 LD BHA: HWDP, NMDCs, jars, float sub, bit sub and bit. 10:00 - 11:00 1.00 WHSUR P PROD1 -Pull wear bushing. -Install test plug. 11:00 - 12:30 1.50 BOPSU P PROD1 O to 3-1/2" x 6" VBR to 7" rams. 12:30 - 13:30 1.00 BOPSU P PROD1 -Install 7" test jt and RU testing equipment. -Test 7" rams (top) to 250 psi low - 3500 psi high x 5 min each on chart. -RD testing equipment. LD 7" test jt and pull test plug. 13:30 - 15:30 2.00 CASE P PROD1 RU to run 7" casing: C/O bales, install air spiders and elevators, install Frank's fill up tool. 15:30 - 21:30 6.00 CASE P PROD1 Run 7" 26# L-80 BTC-M casin to 9-5/8" shoe per running order. -Install ES-Cementer and pup jt w/ RA tag in string per plan. Bakerlok connections at ES-Cementer. -Install 2 straight centralizers per jt on all jts below ES-Cementer (except on jts to be placed in front of intervals to be perforated later). Install bow flex centralizer 10' below and 10' above ES-Cementer. -Break circulation half way in, 210 gpm ~ 450 psi. 21:30 - 22:30 1.00 CASE P PROD1 Circulate string volume prior to entering open hole. 210 gpm ~ 550 psi. -Check parameters ~ shoe: PUW: 145k /SOW 112k. 22:30 - 00:00 1.50 CASE P PROD1 Cont. runnin 7" 26# L-80 BTC-M casing per running order to 5077'. -Total jts run: 123 -PUW: 155k /SOW: 120k. Printad• 12/'i(V2008 12:34:11 PM ~ ~ BP Page 12 of 32 Operations Summary Report 'Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/22/2008 ~ 00:00 - 01:30 ~ 1.50 ~ CASE ~ P 01:30 - 02:00 ~ 0.50 ~ CASE ~ P 02:00 - 02:30 I 0.501 CASE P 02:30 - 03:30 1.00 CEMT P 03:30 - 04:00 ~ 0.50 ~ CEMT ~ P 04:00 - 05:00 ~ 1.00 ~ CASE ~ P 05:00 - 06:00 ~ 1.00 ~ CASE ~ P 06:00 - 08:00 ~ 2.00 ~ CASE ~ P 08:00-10:30 ~ 2.50~WHSUR~P 10:30 - 12:00 ~ 1.50 ~ BOPSUF~ P 12:00 - 14:00 2.00 BOPSU~P 14:00 - 18:30 4.50 BOPSU P PROD1 -MU landing jt w/mandrel hanger. -Circulate down and land casing. 126 gpm ~ 250 psi -Circulate 2 casing volumes and condition mud. 210 gpm ~ 590 psi. Reciprocate casing (20' strokes) while circulating. -Hold PJSM on cementing casing while circulating. PROD1 -LD Franks fill up tool. -RU XO and cementing head. PROD1 Cont. circulating while Schlumberger batch cement. PROD1 Give it to Schlumberger: 1. Pump 5 bbls of water and test lines to 3500 psi. 2. Pump 52 bbls 10.0 ppg Mudpush ~ 5 BPM. 3. Drop bottom plug. 4. Pump 38.5 bbls 15.8 ppg class "G" cement ~ 5 BPM. 5. Drop top plug and kick out w/ 10 bbls of water. PROD1 Switch to rig pumps: -Displace cement w/ 182 bbls 9.2 ppg mud ~ 5 BPM, reducing rate to 3 BPM before bumping plug. FCP: 650 psi. -Bump plug w/ 1650 psi. -Bleed off pressure. Disconnect cement line and check floats. OK -Cement in place ~ 04:00 hours -Reciprocate casing (20' strokes) until bumping plug,.. PROD1 -Line up cementing head. -Pressure u to 3600 si and o en ES-Cementer. -Circulate through ES-Cementer, 5 BPM ~ 560 psi. Observe returns of all Mudpush pumped. No cement to surface. PROD1 -Pump 30 bbls Biozan pill. -Drop closing plug. Displace pill down casing through ES-Cementer. FCP= 350 psi. -Land closing plug. Pressure up and observe ES-Cementer close ~ 1450 psi. Cont Pressure up to 2500 psi and hold x 1 min per HES Rep. Biozan pill is spotted in annulus from - amen er u . -Bleed off pressure and observe no flow back. PROD1 -Blow down cement line. -LD cement head and XO. -Back out landing jt and LD same. -Blow down choke line and kill line. -Vac out stack. PROD1 -MU packoff running tool and install mandrel hanger packoff. Damage seal in the process. -Pull packoff, replace seal and reinstall. RILDS. -Test packoff to 4300 psi per FMC Rep. Clear rig floor. PROD1 -C/O to rams to 3-1/2" x 6" VBR. -C/O saver sub to 4" HT38 PROD1 RU to test BOP. PROD1 Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi - high x 5 min each on chart w/ 3-1/2" test jt. Test top and bottom rams w/ 5" and 3-1/2" test jts. Test witnessed by WSL and Toolpusher. Chuck Scheve, AOGCC Rep, waived witness of test. BP Page 13 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/22/2008 14:00 - 18:30 4.50 BOPSU P PROD1 - Perform koomey test: 1. System Pressure: 3000 psi 2. Pressure after close: 1700 psi 3. 200 psi attained at 30 sec 4. Full pressure attained at 2 min 55 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 31 components: 1.13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 5" Inside BOP and FOSV (ball type), 4° Inside BOP and FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 18:30 - 19:00 0.50 BOPSU P PROD1 RD testing equipment. 19:00 - 19:30 0.50 WHSUR P PRODi -Install wear bushing. -Blow down choke and kill lines. 19:30 - 21:00 1.50 CASE P PROD1 MU cleanout BHA w/ 6-1/8" tricone bit + bit sub + (12) 4-3/4" DCs +jar (PU 4-3/4" DCs and jar 1x1 f/pipe shed). -PU 1 jt 4" DP. 21:00 - 23:00 2.00 CASE P PROD1 -Cut and slip drilling line (59.5') -Inspect and service top drive. 23:00 - 00:00 1.00 CASE P PROD1 PU 4" DP 1x1 f/ pipe shed and RIH w/ cleanout BHA to +/- 1000'. 11/23/2008 00:00 - 00:30 0.50 CASE P PROD1 -Inspect and service top drive, blocks and drawworks. -Blow down choke and bleeder. 00:30 - 03:00 2.50 CASE P PRODi Cont. PU 4" DP 1x1 f/ pipe shed and RIH w/ cleanout BHA f/ 1000' to 4100'. 03:00 - 03:30 0.50 CASE P PRODi CBU to break gels, 231 gpm ~ 1120 psi. 03:30 - 04:00 0.50 CASE P PRODi -RU testing equipment. -Test casino to 3000 osi x 10 min on chart. -RD testing equipment 04:00 - 04:30 0.50 CASE P PROD1 Cont. PU 4" DP 1x1 f/ pipe shed and RIH f/ 4100'. Tag ES-Cementer ~ 4297'. -PUW 120k /SOW 90k / ROTW 100k. 04:30 - 05:00 0.50 DRILL P PRODi Drill out ES-Cementer. 2-10k WOB, 80 RPM ~ 2k torque, 252 gpm ~ 1300 psi. -Ream several times through ES-Cementer after drilling out. -Wash down to 4322'. 05:00 - 06:00 1.00 CASE P PROD1 Cont. PU 4" DP and RIH f/ 4322'. Tag cement stringers ~ 4944'. Clean cment stringers to 4965'. Wash and ream to 4991'. 06:00 - 07:00 1.00 CASE P PROD1 CBU, 336 gpm ~ 1250 psi. 07:00 - 08:30 1.50 CASE P PROD1 -RU testing equipment. -Test casin to 3500 psi x 30 min on chart. -RD testing equipment. 08:30 - 10:00 1.50 CASE P PROD1 -Pump Hi-vis spacer sweep and flush well w/ 400 bbls 8.5 ppg seawater. -Displace seawater w/ 9.3 ppg brine (demulsifier in brine ~ 1 P~,,,o,,• ,~i~nnnnR ~2sa_ii ann BP Page 14 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 111/23/2008 00:00 - 101:30 I 1.50 CASE P I I PRODi 11:30 - 14:30 3.00 CASE P PROD1 14:30 - 15:00 0.50 CASE P PRODi 15:00 - 16:30 1.50 EVAL P PROD1 16:30 - 20:30 4.00 EVAL P PROD1 20:30 - 21:30 ~ 1.00 ~ EVAL ~ N ~ DPRB ~ PROD1 21:30 - 00:00 2.50 EVAL N DPRB PROD1 11/24/2008 00:00 - 01:30 1.50 EVAL N DPRB PROD1 01:30 - 02:00 0.501 CASE I N I DPRB I PRODi 02:00 - 03:30 1.50 CASE N DPRB PROD1 03:30 - 04:30 1.00 CASE N DPRB PROD1 04:30 - 06:30 2.00 CASE N DPRB PROD1 06:30 - 07:00 0.50 CASE N DPRB PROD1 07:00 - 08:00 1.00 EVAL P PROD1 08:00 - 10:30 2.50 EVAL P PROD1 110:30 - 12 00 I 0.501 EVAL P I I PROD1 12:00 - 13:30 1.50 EVAL P PROD1 13:30 - 16:30 3.00 EVAL P PRODi 16:30 - 17:30 1.00 EVAL P PROD1 17:30 - 00:00 6.50 EVAL P PROD1 11/25/2008 ~ 00:00 - 03:00 ~ 3.00 ~ EVAL I P I I PROD1 gal/ 1000 bbls concentration per Schlumberger). -RU testing equipment. -Test casing to 4000 psi on chart. Pressure bleeds down 100 psi in 15 min. Bump up to 4000 psi. Pressure bleeds down 100 psi in 30 min. Test good. -RD testing equipment. Blow down kill line. POOH and rack back 4" DP to 401' (BHA). -Rack back 3 stands 4-3/4" DCs. -LD jars, bit sub and bit. RU Schlumberger a-line equipment. -RIH w/ USIT/CBUCCUGR lop to 4121'. Slack off (~ 4121', -Pull and get stuck ~ 4080'. Work a-line and pull until 4000 ~~ Ibs tension on head. Pull tools free. -POOH to check tools. -Tools ~ surface: centralizers OK, all tools out. USIT sensor cage was missing (sensor OK). LD tools. -PU junk basket w/ 6-1/8" ring gauge and MU to GR/CCL. -RIH w/ ring gauge/junk baskeUCCUGR on a-line. Tag junk (sensor cage) ®4080'. Work and push junk to 4315'. Got stuck. -Work a-line and pull free. POOH w/drag indicating possible junk. -Tools at surface: junk basket empty, marks in ring gauge. -LD tools. RD Schlumberger a-line equipment and clear rig floor. MU BHA w/ 6-1/8" tricone bit + 7" casing scraper + bit sub + 4 stands 4-3/4" DCs. clran~~t sHA ~n 4" fir. Ta~jyP~2'. PU and check again, observe no tag. Cont. RIH to_ 4.991'. CBU, 336 gpm ~ 2020 psi POOH f/ 4991' to 375' (BHA) -Rack back 4 stands 4-3/4" DCs. -LD bit, bit sub and casing scraper. RU Sclumberger a-line equipment. -RIH w/ USIT/GPIT/GR/CCL on a-line to 4975'. -Take USIT/GPIT/GR/CCL to f/ 4975' to 100'. -Observe TOC ~ 4335' WLM. Observe RA tag in casing ~ 4251' WLM RD Schlumberger tools and a-line equipment. Clear rig floor. -RD 4" DP elevators. -Mobilize to rig floor 3-1/2" tubing elevators, slips, powwer tongs and torque tum equipment. RU to run TCP/DST assembly MU and RIH TCP/DST assembl per Schlumberger Rep. -Will perforate and evaluate int. 4710'-4730' RU to run 3-1/2" tubing: install long bale and compensator, power tongs and torque turn equipment. PU 3-1/2" 9.2# L-80 1x1 f/ pipe shed and RIH with TCP/DST assembly. -Run 51 jts TCII followed by NSCT jts on top. -Torque turn connections to opt. MU torque according to connection type. Cont. RIH 3-1/2" 9.2# L-80 (TCII on bottom 51 jts, NSCT on n--.-~. ~ninn MnnO 17•nA~11 DAA BP Page 15 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/25/2008 00:00 - 03:00 3.00 EVAL P PROD1 t op) with TCP/DST assy. to 4757'. -Run total 136 jts of 3-1/2" tubing. -PUW 100k /SOW 80k 03:00 - 05:00 2.00 EVAL P PROD1 RU Schlumberger a-line equipment to correlate packer and guns position. 05:00 - 06:30 1.50 EVAL P PROD1 -Run correlation log on a-line to position packer and TCP guns. -POOH a-line and RD. 06:30 - 07:30 1.00 EVAL P PRODi -LD jt #136 and #135. -MU 5.87' pup jt. MU jt #135 and RIH. Set on slips. 07:30 - 08:30 1.00 EVAL P PRODi -Mobilize flowhead and pump in sub to rig floor. -Install pump in sub on top of flowhead. -MU flowhead and XO to string. 08:30 - 09:30 1.00 EVAL P PROD1 -Line up injection line to IA. -Pressure up IA to 200 psi x 5 min and verify CV valve shut. 09:30 - 10:30 1.00 EVAL P PROD1 -Line up cement line on flowhead wing valve. -Test tubin strin to 4000 six 10 min on chart. -Blow down and RD cement line. 10:30 - 11:30 1.00 EVAL P PRODi -PU tubing string and engage packer. Slack off, position guns in front of int 4710'-4730' and set packer. -Pressure up to 1000 psi and verify packer set. 11:30 - 12:00 0.50 EVAL P PROD1 -Blow down and RD infection ine. -Mobilize hard fine f/ nitrogen to rig floor. 12:00 - 15:00 3.00 EVAL P PROD1 -RU lines to flowhead to inject nitrogen and for DST test. -Test lines with nitrogen to 4000 psi. 15:00 - 16:00 1.00 EVAL P PROD1 -Pressure up IA to 1000 psi to enable IRDV valve. -Bleed off. Pressure up IA to 1400 psi and open IRDV valve. Observe 200 psi drop indicating IRDV open. 16:00 - 18:00 2.00 EVAL P PRODi Displace 37 bbls brine out of tubing with nitrogen, locatin fluid level ~ +/-4257'. Wait 30 min for stabilization. -Total nitrogen pumped: 52 MSCF. 18:00 - 19:00 1.00 EVAL P PROD1 Pump 10 bbls down IA and pressure up to 600 psi. Bleed back (8 bbls returned). Close circ. valve. 19:00 - 19:30 0.50 EVAL P PROD1 Pressure up in IA to 500 psi. Bleed off. Pressure up to 1400 psi. Repeat process. Open ball/tester valve above pert. guns. 19:30 - 20:00 0.50 EVAL P PROD1 -Open swab valve in flowhead and drop bar to fire guns and erforate int. 4710'-4730'. Nitrogen pressure in tubing ~ 1450 psi. -There was no indication of firin on surface. Continue with procedure per BP Heavy Oil Team P.E (James Young). 20:00 - 00:00 4.00 EVAL P PROD1 -Initial nitrogen pressure in tubing ~ 1450 psi. Bleed down 25 psi to tiger tank. Continue bleed down 15 psi to tiger tank every hour per P.E schedule. -RU Schlumberger wireline equipment and pressure control on top of flowhead. 11/26/2008 00:00 - 02:30 2.50 EVAL P PRODi -Cont. bleeding off tubing pressure (nitrogen) 15 psi every hour per schedule. -Test wireline pressure control to 2000 psi x 5 min (had to change o'ring 2x) 02:30 - 05:30 3.00 EVAL P PROD1 -Cont. bleeding off tubing pressure (nitrogen) per schedule. -RIH PBMS + weight bars + fire bar retrieving tool on a-line. -Detect fluid level ~ 4070'. Cont. RIH wireline and could not get passed 4190' (top of 4-3/4" DCs on DSt strin -P OH wireline. o....~...1• 17/•ll1Ml1l1A 17~!~d•17 P~u1 ~ ~ BP Page 16 of 32 Operations Summary Report ,Legal Well Name: MPS-41 'Common Well Name: MPS-41 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 11/26/2008 05:30 - 07:30 2.00 EVAL P 07:30 - 08:30 1.00 EVAL P 08:30 - 11:00 2.50 EVAL P 11:00 - 13:30 2.50 EVAL P 13:30 - 20:30 7.00 EVAL P 20:30 - 22:30 2.00 EVAL P 22:30 - 00:00 1.50 EVAL P 11/27/2008 00:00 - 06:30 6.50 EVAL P 06:30 - 08:00 1.50 EVAL P 08:00 - 15:00 7.00 EVAL P 15:00 - 16:30 1.50 EVAL P 16:30 - 18:30 2.00 EVAL P Spud Date: 11 /7/2008 Start: 11/6/2008 End: Rig Release: 12/17/2008 Rig Number: Phase Description of Operations PROD1 -RD wireline. Install bull nose extension. -RIH w/bull nose extension on a-line and tag bar ~ 4570'. Bar is sitting on top of IRDV which did not open before. TCP guns did not fire. POOH w/wireline. -Cont. bleeding off tubing pressure per schedule while RIH w/ wireline. PROD1 -Build pressure in tubing back to 1302 psi w/nitrogen. -Pressure up IA to 1000 psi and bleed back to 500 psi x 2min. Run pressure up to 1000 psi and IRDV open. -Bar drops f/ top of IRDV after it opened and fire TCP guns in int. 4710'-4730'. Good indication on surface of guns firing. PROD1 -RD nitrogen hard line. -Establish tubing bleed off schedule. PROD1 -RIH w/ PBMS tool on a-line. Tag fluid level ~ 4010'. POOH w/ a-line. -Cont. bleeding off tubing per schedule while running wireline. PROD1 -Install sample tool on a-line. Reinstall lubricator and test quick test sub to 3000 psi. -RIH w/ sample tool on a-line and tag fluid level ~ 3916'. Cont. RIH to 4623' and collect fluid sample. -PO H e-lin a I t PROD1 -Remove sam le tool tool came covered in oil on the outsi -Install new sam le tool. -Reinstall lubricator. Attempt to test quick test sub. Change o-rings. Test to 3000 psi. PROD1 -RIH w/ new sample tool on a-line. -Pressure up IA to 2450 psi to open SCAR. Hold pressure x 1 hr. PROD1 -Bleed off pressure in IA. -Cont. RIH second sample tool on a-line. Tag fluid level ~ +/- 3810' -Collect fluid sample. Correlate w/ RA tag in tubing. Corrected fl id level de th after correlatin to 3784'. -POOH a-line w/ second sample tool. Observe fluid level when ullin out ®3750' (+/- 3-1/2 hrs between fluid level readings). PROD1 Shut in swab valve -Bleed pressure from lubricator -Remove sam le tool tool came covered in oil on the outside . -Install new sample tool. -Reinstall lubricator -Test quick test sub to 3000 psi. Equalize lubricator. PROD1 -RIH w/ sample tool on a-line. -Take third fluid sample ~ 3705'. -POOH a-line w/ sample tool. PROD1 -Shut in swab valve and bleed pressure f/ lubricator. -Retrieve sample tool. RD a-line equipment. -Pressure up IA to 1000 psi and enable IRDV. Bleed off pressure. -Pressure u IA to 1400 si. Close tester valve. Hold pressure x 1 min to open circulating valve. Observe pressure drop as circulating valve open. PROD1 -Bleed nitrogen out of tubing to tiger tank, while cirulating top of hole to keep same full (25 bbls to keep hole full). • • BP Page 17 of 32 Operations Summary Report ,Legal Well Name: MPS-41 'Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2008 ~ 16:30 - 18:30 ~ 2.00 ~ EVAL ~ P ~ PROD1 18:30 - 20:00 ~ 1.50 ~ EVAL ~ P ~ ~ PROD1 20:00 - 21:30 ~ 1.50 ~ EVAL ~ P ~ ~ PRODi 21:30 - 22:30 ~ 1.00 ~ EVAL ~ P ~ ~ PROD1 22:30 - 23:30 1.00 EVAL P PROD1 23:30 - 00:00 0.50 EVAL P PROD1 11/28/2008 00:00 - 00:30 0.50 EVAL P PROD1 00:30 - 06:30 6.00 EVAL P PROD1 06:30 - 10:30 4.00 EVAL P PRODi 10:30 - 11:30 1.00 EVAL P PROD1 11:30 - 14:30 3.00 EVAL P PROD1 15:00 - 15:30 I 0.50 EVAL I P I PRODi 15:30 - 17:00 1.50 EVAL P PROD1 17:00 - 17:30 0.50 EVAL P PROD1 17:30 - 19:00 1.50 EVAL P PROD1 19:00 - 19:30 0.50 EVAL P PROD1 19:30 - 23:00 3.50 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 11/29/2008 ~ 00:00 - 08:00 ~ 8.00 ~ EVAL ~ P ~ ~ PROD1 -Collect dead crude samples on surface when tubing pressure bled completely (0 psi) and oil reached surface. -Reverse circulate tubing volume with 37 bbls 9.3 ppg brine, taking returns out to tiger tank. 165 gpm ~ 740 psi -Cont. reverse circulating 60 bbls 9.8 ppg brine, taking clean returns back to pits and oil contaminated returns to rockwasher. 170 gpm ~ 680 psi. -Pressure up IA to 600 psi and hold x 6 min, then bleed off. This closes circulating valve. -Open tester valve by pressuring up IA to 500 psi x 2 min. Then up to 1000 psi and hold x 4 min. Cont. up to 1400 psi to lock tester valve open. Bleed off. -Bullhead 4 bbls down tubing and inject to formation, 0.5 BPM ~ 620 psi. Stop pump and hold pressure. Pressure bled to formation 500 psi in 20 min. Finish bleeding off. (This operation bullheads to formation volume between circulating valve and bottom of DST string not reverse circulated in previous steps, and prior to open packer by-pass). -PU string to open packer by-pass. -Reverse circulate through packer by-pass 60 bbls 9.3 ppg brine, taking clean returns back to pits and oil contaminated returns to rockwasher. 114 gpm ~ 280 psi. -Unseat acker. Observe well U-tubin f/ IA to tubin . -Circulate well volume (165 bbls) w/ 9.3 ppg brine. Observe well static. LD flowhead and mobilize off rig floor. RU to pull and LD 3-1/2" tubing Finish RU to pull and LD 3-1/2" tubing. POOH and LD 3-1/2" 9.2# L-80 (NSCT &TCII) tubing to pipe shed. -Use compensator to LD tubing. -Rack back 4-3/4" DCs. -LD DST tools. Clear rig floor MU 7" EZSV bride lu and RIH w/ 4-3/4" DCs f/derrick. -Cont. RIH 7" EZSV bridge plug and 4-3/4" DCs on 4" DP to 4650'. -Circulate and reciprocate pipe x 5min, 144 gpm ~ 240 psi. -Set EZSV bride lu ~ 4650' COE Isolate int. 4710'-4730 CBU - 370 gpm ~ 1280 psi. -RU testing equipment. -Test 7" casin and bride lu to 4000 six 10 min on chart. -RD testing equipment. POOH and rack back 4" DP to 350' (DCs). Lubricate rig and inspect top drive. Rack back 4-3/4" DCs. -Drift same to 2-1/16" while racking back. LD HES running tool and clear rig floor. MU and RIH TCP/DST strip per Schlumberger Rep. RU to run 3-1/2" tubing: C/O bales, install compensator and torque turn equipment. RIH 3-1/2" 9.2# L-80 (TCII &NSCT) tubing 1x1 with TCP/DST -Torque turn connections to opt. torque according to BP Page 18 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/29/2008 00:00 - 08:00 8.00 EVAL P PROD1 connection type. - Total jts 3-1/2" tubing run: 132 -PUW 95k /SOW 80k 08:00 - 11:00 3.00 EVAL P PROD1 -RU Schlumberger a-line. -RIH GR/CCL on a-line to correlate guns position. Could not get past 1785'. -POOH a-line. Log tool came covered with oil on the outside. 11:00 - 12:00 1.00 EVAL N PROD1 Reverse circulate 9.3 ppg brine, 210 gpm ~ 740 psi 12:00 - 14:00 2.00 EVAL N DPRB PROD1 -Spot 35 bbls heated 9.3 ppg brine+ ScreenKleen pill in tubing. Let it soak f/ 40 min. -Reverse circulate out pill. -Circulate surface-surface w/ 9.3 ppg brine, 215 gpm ~ 740 psi. -Close circulation valve in DST string per Schlumberger Rep. 14:00 - 15:30 1.50 EVAL N DPRB PROD1 -Attem t to run GR/CCL to on a-line. Could not et ast 2000'. -P OH and hang tool onside. Log tool came covered with oil on the outside. 15:30 - 17:30 2.00 EVAL N DPRB PROD1 -Open circulating valve in DST string per Schlumberger Rep. -Reverse circulate 9.3 ppg brine while waiting for Little Red Services to pump heated diesel. 17:30 - 22:30 5.00 EVAL N DPRB PRODi -RU Little Red Services. -Pump down tubing 35 bbls ScreenKleen pill (w/ rig pumps), followed by 36 bbls 130 degF diesel (w/ Little Red). -Let heated diesel soak in tubing (soak f/ 3.5 hrs while waiting f/ new 9.3 ppg brine). -RD Little Red. 22:30 - 23:00 0.50 EVAL N DPRB PRODi -Reverse circulate diesel out of tubing to tiger tank. -Reverse circulate ScreenKleen pill out to rockwasher. 23:00 - 00:00 1.00 EVAL N DPRB PROD1 -Pump 30 bbls hi-vis sweep. -Displace well w/ 160 bbls new 9.3 ppg brine. 290 gpm ~ 700 psi. 11/30/2008 00:00 - 01:00 1.00 EVAL P PROD1 -RIH w/ correlation log on a-line. -Observe RA tag in tubing ~ 4373 W LM (1.5' shallow from tubing tally) -POOH a-line 01:00 - 02:00 1.00 EVAL P PROD1 -LD jts #132 and #131. -MU space out pup jts (3.85' & 5.87') on top of jt #130. -MU jt #131. RIH and position puns on death to perforate int. 4585'-4605'. 02:00 - 04:00 2.00 EVAL P PROD1 -RD compensator. C/0 elevators. -Mobilize flowhead to rig floor. -RU pump in sub on top of flowhead. -C/O XO on bottom of flowhead. MU flowhead and XO to string -Close circulating valve in DST string per Schlumberger Rep. 04:00 - 05:00 1.00 EVAL P PROD1 -RU cement line to flowhead and testing equipment. -Test tubing to 4000 psi x 10 min on chart. Test good. 05:00 - 06:00 1.00 EVAL P PROD1 Set DST acker and set 25k down -Test same to 1000 psi per Schlumberger Rep. -Open Circ. valve -Load BHF firing bar 06:00 - 09:30 3.50 EVAL P PROD1 RU wireline lubricator, grease head, fast test sub, W.L. BOP & sheaves Printed: 12/30/2008 12:34:11 PM BP Page 19 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/30/2008 06:00 - 09:30 3.50 EVAL P PROD1 - Test lubricator to 2000 psi f/ 5 min. 09:30 - 11:30 2.00 EVAL P PROD1 RU lines for N2 displacement - Purge all lines w/ N2 -Test lines to 4000 psi -PJSM w/ all involved w/ upcoming operation 11:30 - 13:30 2.00 EVAL N PROD1 Dis lacin tubin w/ N2 t b Is awa and monitor tri tan -Continue pumping N2 -Overdis laced tubin allowin N2 into annulus 13:30 - 15:30 2.00 EVAL N PROD1 Bleed N2 into slop tank while filling annulus and keeping backpressure at 700-1100 psi on annulus -Reverse circ. tubing volume + 10 bbls -Circulate N2 out of annulus through choke and gas buster -Shut in and observe for pressure - OK -Open well and circ. surface to surface -Blow down lines 15:30 - 17:30 2.00 EVAL P PROD1 Cycle C.V. to ensure DST equip. operable - OK -PJSM on N2 displacement -Displace tubing w/ N2 -Track volume in trip tank -Total displacement = 36.62 bbls -Calculated displacement to top of IRDV = 37.25 bbls -Total N2 pumped = 31.417 Mscf 17:30 - 18:30 1.00 EVAL P PROD1 -Close circulating valve. -O en tester valve and lock it o en. 18:30 - 19:30 1.00 EVAL P PROD1 -Open swab valve and drop bar to fire guns. No indication on surface of firing. -Repeat process to open tester valve in case bar was sitting on top of it. No indication of firing on surface. 19:30 - 22:30 3.00 EVAL P PROD1 -RIH a-line w/ correlation log. Detect fluid level ~ 4157'. Talc - ' t. bar ~ 4550' on to of firin head. Guns fired and 4585'-4605' when bar to ed with a-line. Indication of firing on surface. -Bleed off 25 psi in tubing and check fluid level again. Fluid level ~ 4146'. -Wait 10 min and check fluid level again. Fluid level ~ 4138'. -POOH w/ a-line 22:30 - 00:00 1.50 EVAL P PRODi -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -Install oil sampler on a-line. -Connect lubricator and test on fast test sub to 2000 psi. -Bled 59 psi during change of tools on a-line. 12/1/2008 00:00 - 05:30 5.50 EVAL P PROD1 -Equalize pressure in lubricator and open swab valve. ' . -RIH w/fluid sampler on a-line. Tag fluid level ~ 3950 -Bleed nitrogen pressure in tubing as required. -Collect first fluid sample. -POOH a-line w/ fluid sampler. 05:30 - 06:30 1.00 EVAL P PROD1 -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -C/O oil sampler tool. -Connect lubricator and test on fast test sub to 2000 psi. 06:30 - 12:00 5.50 EVAL P PROD1 -Equalize pressure in lubricator and open swab valve. ' . -RIH w/ fluid sampler on a-line. Tag fluid level ~ 3790 o~.,fo.a• i~iannnna 174id~11 PM . ' ! BP Page 20 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 12/1/2008 06:30 - 12:00 5.50 EVAL P PROD1 - Bleed nitrogen pressure in tubing as required. -Collect second fluid sample. -POOH a-line w/fluid sampler. 12:00 - 13:30 1.50 EVAL P PROD1 -Shut in swab valve. -Bleed off lubricator and disconnect same at fast test sub. -Disconnet second sampler. Install 2 new oil sampler tools set at different opening times. -Connect lubricator and test on fast test sub to 2000 psi. 13:30 - 21:30 8.00 EVAL P PROD1 -Equalize pressure in lubricator and open swab valve. -RIH w/fluid samplers #3 and #4 on a-line. -Collect 3rd and 4th fluid samples ~ 3657' and 3641' (sampler tools open at different times). -POOH a-line w/fluid sampler tools. 21:30 - 22:30 1.00 EVAL P PROD1 -LD a-line tools. -RD lubricator, wireline BOP and rest of a-line equipment. 22:30 - 00:00 1.50 EVAL P PROD1 -Close tester valve and open circulating valve per Schlumberger Rep. -Bleed off nitrogen pressure to tiger tank while keeping IA full w/ 9.3 ppg brine. Take 19.5 bbls brine to fill IA. -After nitrogen bled, cont. reverse circulating w/ 9.3 ppg brine, taking retums out to tiger tank until clean enough to divert to rockwasher. Reverse circulate total 28 bbls, 114 gpm ~ 600 psi. 12/2/2008 00:00 - 01:00 1.00 EVAL P PROD1 Reverse circulate well w/ 9.3 ppg brine, taking dirty returns to rockwasher and clean returns to pits. 01:00 - 02:00 1.00 EVAL P PROD1 -RU Little Red and test lines. -Little Red pumps 38 bbis 130 degF diesel and spot in tubing. 2 BPM G~ 750 psi. -RD Little Red. 02:00 - 03:00 1.00 EVAL P PROD1 Let heated diesel soak in tubing. 03:00 - 03:30 0.50 EVAL P PROD1 -Reverse circulate diesel out to tiger tank w/ 38 bbis 9.3 ppg brine. -Cont. reverse circulating to pits w/ 38 bbis 9.3 ppg brine. Returns clean. 03:30 - 05:00 1.50 EVAL P PROD1 -Close circulating valve and open tester valve per Schlumberger Rep. -Bullhead 3 bbis to formation, hesitating at max. 800 psi w/ 0.5 BPM. -Let pressure bleed to formation after bullheading. - Pressure bleeds 700 psi in 15 min. 05:00 - 05:30 0.50 EVAL P PROD1 -PU. Open packer by-pass and unseat packer. -Reverse circulate 60 bbis 9.3 ppg brine, taking retums to pits. 05:30 - 06:00 0.50 EVAL P PROD1 - LD Flowhead. 06:00 - 07:00 1.00 EVAL P PROD1 - RU to LD 3.5" tubing with compensator. 07:00 - 12:00 5.00 EVAL P PROD1 -POOH LD 3.5" tubing from 4,630' to 535' md. 12:00 - 14:00 2.00 EVAL P PROD1 - RD 3.5" tubing equipment. Remove long bails. -Install short bails. Clear rig floor. 14:00 - 17:30 3.50 EVAL P PROD1 Stand back one stand of collars, LD the rest of the D.C's. -PJSM on laying down Guns -All Guns fired. -LD DST tools and guns. 17:30 - 18:30 1.00 EVAL P PROD1 -Clear rig floor of vendors tools. 18:30 - 20:30 2.00 PXA P PROD1 -RIH from derrick with 4" DP. -Tag top of EZSV ~ 4,650' md. Printed: 12/30/2006 12:34:11 PM BF Page 21 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/2/2008 20:30 - 23:00 2.50 PXA P PROD1 - CBU at 284 gpm / 580 psi. -Reci rotate while waitin for SLB cement unit to ri u . -PUW 105k SOW 95k. 23:00 - 23:30 0.50 PXA P PROD1 PJSM on cementing. -SLB pumped: -11.1 bbls of water ahead. -Test lines to 3000 psi -OK. -11.5 bbls of 15.8 class "G" Cmt. -Follow with 5 bbls of water. -Displace Cmt with Rig pumps. -Balance lu on bottom w/ 39 bbls of 9.0 ppg NaCI. -164 gpm / 50 - 140 psi. 23:30 - 00:00 0.50 PXA P PROD1 -POOH slowly to 4,300' md. -Fluid column is in balance. 12/3/2008 00:00 - 00:30 0.50 PXA P PROD1 Continue to POH slowly w/ 4" DP to 4,265' md. 00:30 - 01:30 1.00 PXA P PROD1 PU 1 Jt of 4" DP,,Drop wiper ball. . -Girt out Cmt -Trace amounts of Cmt to surf ce. -504 gpm / 1480 psi. -Reciprocate 4,286' to 4,255' md. -Rotate ~ 80 rpm. 01:30 - 03:30 2.00 PXA P PROD1 LD 1 single. Stand back 1 stand to 4,170' md. -Cut & slip 1 1/4" Drlg line (59.5'). -Service Top Drive. Inspect brake bands. -Continue to circulate to warm OA annulus fluids. -Fluid temp in = 88 F. Fluid temp out = 79 F. 03:30 - 05:00 1.50 PXA P PROD1 Flow check -Dry job -Blow down -POH w/ Mule shoe on 4" DP f/ 4,170' and to surface. -LD Mule shoe. 05:00 - 05:30 0.50 PXA P PROD1 MU 5 1/2" Multi-Strin Cutter dressed for 7" 26# c -RIH on 4" DP 2 stands. 05:30 - 06:30 1.00 PXA P PROD1 Cut & slip 1 1/4" drilling line to remove bad spot. 06:30 - 08:30 2.00 PXA P PROD1 Continue RIH w/ 4" DP to 4,275' md. 08:30 - 11:00 2.50 PXA P PROD1 Circulate heated brine w/ 147 gpm / 510 psi. -Returns are 85-87 degF 11:00 - 12:00 1.00 PXA P PRODi RU test equipment. -Test 9 5/8" casing /cement plug to 1000 psi f/ 10min on chart - OK. -RD test equipment. 12:00 - 13:00 1.00 PXA P PROD1 PU single DP -Pumping w/ 84 gpm / 180 psi. -Tag casing collar at 4,297' md. -Stop pumps - PU & spot knives at 4,277' md. -Rotating w/ 60 rpm / 2k torque. -Bring pumps on and stage up to 202 gpm / 900 psi. -Observe torque increase -Increase rotary to 100 rpm. -Observe pressure drop, went to 350 psi when pipe cut out. 13:00 - 14:00 1.00 PXA P PROD1 Close annular preventer. -Open "OA" valve to pits. -Break circ. w/ 218 gpm / 570 psi. -Circulate mud and Biozan ill out of 9 5/8" X 7" annulus. -Open Annular preventer. Flow check well -Static. 14:00 - 16:00 2.00 PXA P PROD1 POH w/ Cutter on 4" DP f/ 4,277' to surface. -Knives showed good wear pattern. 16:00 - 16:30 0.50 PXA P PROD1 LD BHA. Clear Rig floor of Vendor tools. o,;~,od• ~~iannnna 19~3d~71 PM BP Page 22 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 12/3/2008 16:30 - 17:00 0.50 PXA P PROD1 Pull Wear ring. -Install Test plug. 17:00 - 18:00 1.00 PXA P PROD1 Change Top Rams from 3 1/2" X 6" to 4 1/2" X 7". 18:00 - 19:00 1.00 PXA P PROD1 Test Top Rams to 250 psi low / 3500 psi high. -Test each f/ 5 minutes & chart.- Pass. 19:00 - 20:00 1.00 PXA P PROD1 MU Spear on 1 Jt of 4" DP. 20:00 - 22:30 2.50 PXA P PROD1 Spear into 7" Csg & engage Spear. -Pull 175k on 7" Csg & Hanger. Hanger started m 22:30 - 23:30 1.00 PXA P PROD1 23:30 - 00:00 0.50 PXA P PROD1 12/4/2008 00:00 - 00:30 0.50 PXA P PROD1 00:30 - 01:00 0.50 PXA P PRODi 01:00 - 01:30 I 0.50 PXA I P ( I PROD1 01:30 - 02:00 0.50 PXA P PROD1 02:00 - 04:30 2.50 PXA P PROD1 04:30 - 06:00 ~ 1.50I PXA ~ P ~ ~ PROD1 06:00 - 06:30 0.50 PXA P PROD1 06:30 - 07:00 0.50 PXA P PROD1 07:00 - 07:30 0.50 PXA P PROD1 07:30 - 08:00 0.50 PXA P PROD1 08:00 - 08:30 0.50 PXA P PROD1 08:30 - 09:00 0.50 PXA P PROD1 09:00 - 09:30 0.50 PXA P PROD1 010 00 - 10:30 0.50 PXA p I PROD1 PROD1 10:30 - 12:00 I 1.501 PXA I P I I PROD1 12:00 - 12:30 0.50 PXA P PROD1 -Work up Csg pull from 175 - 375k. Pump 420 gpm / 450 psi. -Frozen mud & cuttings seen in returns. -Pump Hi Vis Sweep. -Csg would not pull free. LD Spear. Pull Packoff. Install Test plug. Change Top Rams back to 3 1/2" X 6" Continue to change Rams to 3 1/2" X 6" Rams. RU & test Rams. -Test to 250 psi low & 3500 psi high. -Hold each test for 5 charted minutes -Pass. Pull test plug. 'Install Wear ring. ~ MU Multi-String cutter, Stab & XO on 4" DP. -RIH w/ Cutter on 4" DP to 3,898' md. -PUW 101, SOW 90k, ROT wt 98k. -Pump 84 gpm / 150 psi. -Wash down & tag collar ~ 3,966' md. -Tum off pumps. PU 20'. -En a e Cutter ~ 3 946' md. -Pump rate: 84 - 252 gpm / 150 - 780 psi. -40 - 100 rpm / 2 - 7k Tq. -Observed pressure drop from 750 to 400 psi after cut. POH w/ Multi-String cutter on 4" DP from 3,946' md. -POH to surface. Pull wear ring. Install test plug & 7" test Jt. Change out Top Rams to 4 1/2" X 7" Variables. fiest Top Rams - 250 low psi / 3500 psi high psi. -Test each for 5 charted minutes -Pass. Pull Test plug. LD 7" Test Jt. MU Spear, XO & 1 Jt of 4" DP. RIH. Engage Hanger. -Pull Han er free w/ 155k. -Pull to Rig floor w/ 145k to~175k (25-30k overpull). CBU 336 gpm / 690 psi. Dis-engage from Fish. -Make service breaks & LD Spear, XO & DP. -LD Hanger & pup Jt. -C/O Elevators. Blow down Top Drive. RU Csg equipment. -POH LD 7" Csg from 3,946' to 3,461' md. Lubricate Rig. Inspect Top drive. B F Page 23 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 12/4/2008 12:30 - 16:30 4.00 PXA P PROD1 16:30 - 17:00 0.50 PXA P PRODi 17:00 - 19:00 2.00 PXA P PROD1 19:00 - 19:30 0.50 PXA P PROD1 19:30 - 20:00 0.50 PXA P PROD1 20:00 - 22:00 2.00 PXA P PRODi 22:00 - 00:00 2.00 PXA P PROD1 12/5/2008 00:00 - 03:00 3.00 PXA P PROD1 03:00 - 04:00 1.00 PXA P PROD1 04:00 - 05:30 1.50 PXA P PROD1 05:30 - 07:00 1.50 PXA P PROD1 07:00 - 07:30 0.50 PXA P PROD1 07:30 - 08:30 ~ 1.00 ~ PXA I P I I PROD1 08:30 - 09:30 1.00 PXA P PRODi 09:30 - 10:00 0.50 PXA P PROD1 10:00 - 12:00 2.00 PXA P PROD1 12:00 - 14:00 ~ 2.00 ~ PXA ~ P ~ I PROD1 14:00 - 15:30 ~ 1.50 ~ PXA I P I I PROD1 15:30 - 16:00 ~ 0.50 ~ PXA ~ P ~ ~ PROD1 Continue to LD 7" Csg from 3,461' and to surface. -Recovered 95 full Jts & 1 cut Jt ~ 21.99'. RD Csg equipment. Change out Saver sub, Bell guide & Jaws to 5" on Top Drive. Install Wear ring. PU Fishing BHA to Rig floor: -Spear, pear xt, ,Oil jar & Intensifier jar. MU BHA to 324' md. RIH w/ Fishing assy from 324' to 3,900' and on 5" DP. Break circulation 228 gpm 300 psi. U 145k, Sow 110k. -Tum pumps off. Tagged fish C~ 3,94T md. -Start jarring 225k up wt. Work up to 300k up wt. -Jarred 16 times before i e started movin . -Tum on pumps to help w/ hydraulicing out of the hole. -Pump rate: 150 - 300 gpm / 200 - 600 psi. -Pi a stared movin ~ 00:45 hrs. -Moved fish 40' up. Stood back 1 Std. -PU 1 single of 5" DP. -Continued Jarring w/ pump on to 3,720' md. -Pull without Jarrinst to 3,625' md. Circulate hole clean ~ 231 gpm / 430 psi. -Inspect derrick. POH w/ Fish on 5" DP from 3,625' and to BHA ®324' md. LD BHA. -Acc. jars, 9- 6 1/4" DC's, oil jars and bumper sub. RU casing tongs and 7" handling tools. -PJSM. -LD spear and cut jt. - 7 full its (# 97-1 -1 1'Up wi HH 1:aQ I:S.OZI - ~+ut luu n is ~ .vim ~ RD casing tools. -Clear floor of casing equip. and Baker fishing tools. Clean rig floor. -Rehang make up tongs. MU 3 1/2" muleshoe, XO, 1 stand 4" DP & XO. -RIH w/ 5" DP. T~ fill at 4 158' and (18' out of 9 5/8" shoe). Screw in T.D. -Obtain parameters: -PUW 126k -SOW 105k -ROW 118k. -Break circulation w/ 126 gpm 90 psi. -Stage pumps up to 336 gpm / 220 psi. -Rotate w/ 20 rpm -Wash and ream down from 4,158' md. -Ta hard s of /cement at 4,342' md. Pump H.V. sweep around. -336 gpm / 280 psi. -PJSM w/ cementers and truck drivers. -Sand back w/ sweep. Schlumberger pump: -22 bbls fresh water. -Test lines to 3000 psi. -Pump 25 bbls 17 ppg Class "G" cement. -8 bbls fresh water behind. Printed: 12/30/2008 12:34:11 PM BP Page 24 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2008 16:00 - 16:30 0.50 PXA P PROD1 Displace w/ 9.0 ppg brine using rig pumps. -336 gpm / 200 psi. -Pumped a total of 55.7 bbls to balance cement plug. -CIP at 16:30 hrs. 16:30 - 17:00 0.50 PXA P PROD1 POH slowly. -Stand back 4 stands to 3,967' md. -Drop HES DP wiper ball. 17:00 - 18:00 1.00 PXA P PROD1 Screw in T.D. -Circulate w/ 336 gpm / 200 psi. -Trace of cement observed upon bottoms up. 18:00 - 19:30 1.50 PXA P PROD1 POH from 3,967' and to surface. -LD XO's & Mule shoe. 19:30 - 00:00 4.50 PXA P PROD1 PJSM on LD 4" DP & 4 3/4" D.C's. from derrick. -LD 4 3/4" D.C's & 4" DP from derrick. 12/6/2008 00:00 - 00:30 0.50 PXA P PROD1 Lubricate Rig. Inspect Top Drive. 00:30 - 01:30 1.00 PXA P PROD1 Continue to LD 4" DP from derrick in mouse hole. -Clean pits for OBM. 01:30 - 02:30 1.00 PXA P PROD1 Move BHA in Pipe shed. 02:30 - 03:00 0.50 PXA P PROD1 Drain Stack. Pull Wear ring. 03:00 - 03:30 0.50 PXA P PROD1 Install Test plug with a 5" Test Jt. 03:30 - 05:00 1.50 PXA P PROD1 RU to Test BOP's. 05:00 - 10:30 5.50 PXA P PROD1 Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5 min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 5" test jt. Test top and bottom rams w/ 5" and 4-1/2" test jts. Test witnessed by WSL, Toolpusher, Jeff Jones, AOGCC Rep -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1750 psi 3. 200 psi attained at 32 sec 4. Full pressure attained at 2 min 37 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 31 components: 1. 13-5/8" annular 2. 4-1/2" x 7" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 5" Inside BOP and FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 10:30 - 13:30 3.00 PXA P PROD1 Change out HCR Choke valve. 13:30 - 16:00 2.50 PXA P PROD1 Sim Ops:RU to test HCR Choke and Choke line. -PU BHA to Rig floor. -Test HCR Choke valve and Choke line. 16:00 - 17:00 1.00 PXA P PROD1 Pull Test Plug. -Install Wear ring. 17:00 - 17:30 0.50 PXA P PROD1 RU Geo-Pilot skid. -Blow down Choke line & Kill line. 17:30 - 21:30 0.00 DRILL P PROD2 PJSM on Nukes. oa~~ea• ~~ivnnnna 199d~11 PM BP Page 25 of 32 Operations Summary Report Legal Well Name: MPS-41 Common Well Name: MPS-41 Spud Date: 11/7/2008 Event Name: DRILL+COMPLETE Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/17/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2008 17:30 - 21:30 0.00 DRILL P PROD2 - MU BHA: PDC bit, Geo-Pilot, DM, EWR, Stab, PWD. -Load Nukes. MU TM, Float sub, Stab & (3) Flex D.C's. 21:30 - 22:00 0.00 DRILL P PROD2 Shallow Pulse test MWD. Blow down Top Drive. 22:00 - 22:30 0.50 DRILL P PROD2 PU 5 Jts of SWDP & Jars. 22:30 - 00:00 1.50 DRILL P PROD2 PU 5" DP from Pipe shed 1 X 1. -Single in hole to 1,972' md. 12/7/2008 00:00 - 01:00 1.00 DRILL P PROD2 Continue to PU DP from Pipe shed 1 X lfrom 1,972' to 2,604' md. 01:00 - 01:30 0.50 DRILL P PROD2 RIH w/ 5" DP from derrick to 3,800' md. 01:30 - 02:30 1.00 DRILL P PROD2 Cut & slip 59.5' of 1 1/4" drilling line. -Service Top Drive. 02:30 - 03:30 1.00 DRILL P PROD2 RIH f/ 3,800'to 4,045' md. Tag hard Cmt ~ 4,045' md. -Set down 15k to verify. 03:30 - 04:30 1.00 DRILL P PROD2 Circulate surface to surface ®420 gpm / 950 psi. -Reciprocate DP. 04:30 - 06:00 1.50 DRILL P PROD2 RU & test Csg to 1000 psi for 10 charted minutes. -Record pressure drop down for 10 minutes. -Prepare Pits for MOBM. 06:00 - 07:30 1.50 DRILL P PROD2 Bring on MOBM to Pits. 07:30 - 09:00 1.50 DRILL P PROD2 PJSM on fluid displacement. -Displace brine to 9.2 ppg Rheliant MOBM. -Pump rate 400 gpm / 1210 psi. 09:00 - 10:00 1.00 DRILL P PROD2 RU & test Cs to 1000 si for 10 charted min tes. -Record pressure drop down for 10 minutes. -Blow down Top Drive. 10:00 - 11:00 1.00 DRILL P PROD2 Drill Cmt from 4,045' to Csg shoe ~ 4,140' md. -PUW 138k, SOW 110k, ROT wt 123k. -RPM 70 ~ 3-8k Tq, WOB 10k, 450 gpm / 1560 psi. ~-~ ~~ 11:00 - 12:00 1.00 DRILL P PROD2 Time drill f/ 4,140' to 4,145' md. -PUW 138k, SOW 110k, ROT wt 123k. -RPM 70 ~ 3-8k Tq, WOB 10k, 450 gpm / 1560 psi. .,. ~ ~ ` AST = 1 hr ADT = 1 hr 12:00 - 18:30 6.50 DRILL P PROD2 Continue to Time drill f/ 4,145' to 4,203' md. -4,182' and = 60% formation. 4,188' and = 65% formation. 18:30 - 19:00 0.50 DRILL P PROD2 CBU. Condition mud for F.I T. to 11.5 ppg EMW. -RU test equipment. 19:00 - 20:30 1.50 DRILL P PROD2 Perform F.I.T.. MW = 9.2 ppg. TVD = 3,477'. -Impose 420 psi & hold -Pass. -RD test equipment. 20:30 - 00:00 3.50 DRILL P PROD2 Directionally drill ahead from 4,203' to 4,346' md. -PUW 136k, SOW 110k, ROT wt 125k. -RPM 110, Tq on 5, Tq off 3-4k, 530 gpm / 1980 psi. -WOB 5k. AST = 8.21 hrs ADT = 9.21 hrs. 12/8/2008 00:00 - 02:30 2.50 DRILL P PROD2 Continue directionally drilling from 4,346' to 4,450' md. -PUW 135k, SOW 110k, ROT wt 125k. -475 gpm / 1660 psi off, 1710 psi on Btm. -WOB 10k, RPM 100, Tq 5k off, 6k on Btm 02:30 - 03:00 0.50 DRILL P PROD2 Pump out of hole to 4,070' and ~ Drlg rate. Printed: 12/30/2008 12:34:11 PM Sperry Drilling Services Survey Report Company: BP Amoco llate: 12/27/2008 Time: 14:18:18 Yage: f I Field: Milne Point Co-ordinate(NE) Reference: Wel l: MPS-41, True North 'I Site: M Pt S Pad Vertical (TVD) Reference: MPS-41 71.5 '~ WeIL• MPS-41 Section (VS) Reference. Wel l (O.OON,O.OOE,1 44.94Azi) '~~ Wellpath: MPS-41 Survey Calculation Method: Mini mum Curvature llb: Ora cle - Field: Milne Point ___ _ - - - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: MPS-41 Slot Name: 5002923401 Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft Latitude: 70 24 3 6.523 N +E/-W -852.55 ft Easting : 565493.29 ft Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Wellpath: MPS-41 Drilled From: Well Ref. Point 5002923401 00 Tie-on Depth: 33.74 ft Current Datum: MPS -41 Height 71.53 ft Above System Datum: Mean Sea Level Magnetic Data: 11 /15/2008 Declination: 22.64 deg Field Strength: 57671 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.74 0.00 0.00 144.94 Survey Program for Definitive Wellpath Date: 11/14/2008 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 33.74 442.00 MPS-41 CB-GYRO-MS (33.74-442.0 CB-GYRO-MS Camera based gyro multishot 442.00 5048.10 MPS-41 MW D+SAG+CA+IIFR+MS (44 MWD+IFR+MS MWD+IFR+ Multi Station Survey I Nlll Incl Azim T\'D Sys TVD N/S E/W VIapN MapE Tool ft .deg deg ft ft ft ft ft ft 33.74 0.00 0.00 33.74 -37.79 0.00 0.00 5999888.58 565493.29 TIE LINE 73.00 0.38 334.02 73.00 1.47 0.12 -0.06 5999888.70 565493.23 CB-GYRO-MS 162.00 0.21 222.16 162.00 90.47 0.26 -0.30 5999888.84 565492.99 CB-GYRO-MS 251.00 0.46 272.88 251.00 179.47 0.16 -0.76 5999888.73 565492.53 CB-GYRO-MS 351.00 0.42 232.13 350.99 279.46 -0.05 -1.45 5999888.52 565491.84 CB-GYRO-MS 442.00 0.74 181.86 441.99 370.46 -0.84 -1.73 5999887.73 565491.56 CB-GYRO-MS 528.63 1.47 146.58 528.60 457.07 -2.33 -1.14 5999886.25 565492.17 MWD+IFR+MS 618.13 3.06 135.98 618.03 546.50 -5.00 1.15 5999883.59 565494.49 MWD+IFR+MS 706.57 3.91 137.59 706.31 634.78 -8.93 4.83 5999879.70 565498.19 MWD+IFR+MS 803.02 4.62 140.99 802.49 730.96 -14.37 9.49 5999874.29 565502.90 MWD+IFR+MS 896.82 5.85 144.37 895.90 824.37 -21.19 14.65 5999867.52 565508.13 MWD+IFR+MS 989.19 8.31 143.02 987.56 916.03 -30.35 21.41 5999858.42 565514.96 MWD+IFR+MS 1083.61 10.18 145.31 1080.75 1009.22 -42.66 30.26 5999846.19 565523.92 MWD+IFR+MS 1180.79 12.08 149.01 1176.10 1104.57 -58.45 40.39 5999830.50 565534.19 MWD+IFR+MS 1275.09 15.30 145.49 1267.71 1196.18 -77.16 52.52 5999811.89 565546.48 MWD+IFR+MS 1366.86 17.89 144.26 1355.65 1284.12 -98.58 67.62 5999790.60 565561.76 MWD+IFR+MS 1460.55 19.33 146.04 1444.44 1372.91 -123.13 84.69 5999766.21 565579.04 MWD+IFR+MS 1553.82 19.10 144.74 1532.51 1460.98 -148.39 102.12 5999741.10 565596.70 MWD+IFR+MS 1648.35 20.12 146.37 1621.56 1550.03 -174.56 120.05 5999715.10 565614.86 MWD+IFR+MS 1742.45 22.69 144.96 1709.16 1637.63 -202.90 139.44 5999686.93 565634.49 MWD+IFR+MS 1837.55 25.49 142.98 1795.97 1724.44 -234.26 162.30 5999655.77 565657.62 MWD+IFR+MS 1931.98 25.42 142.91 1881.23 1809.70 -266.65 186.75 5999623.60 565682.36 MWD+IFR+MS 2024.99 26.28 147.47 1964.94 1893.41 -299.94 209.87 5999590.52 565705.76 MWD+IFR+MS 2119.30 26.53 149.59 2049.42 1977.89 -335.71 231.75 5999554.95 565727.96 MWD+IFR+MS 2213.60 26.59 153.10 2133.77 2062.24 -372.69 251.96 5999518.15 565748.49 MWD+IFR+MS 2307.25 29.86 155.79 2216.28 2144.75 -412.66 271.01 5999478.35 565767.89 MWD+IFR+MS 2402.97 33.72 158.11 2297.62 2226.09 -459.06 290.70 5999432.13 565787.98 MWD+IFR+MS 2499.15 34.51 159.04 2377.25 2305.72 -509.28 310.40 5999382.09 565808.11 MWD+IFR+MS 2593.48 38.00 160.17 2453.31 2381.78 -561.57 329.81 5999329.98 565827.98 MWD+IFR+MS • Sperry Drilling Services Survey Report Company: BP Amoco Date: 12/27/2008 Time: 14:18:18 Yage: 2 Field: Mil ne Point Co-ordinate(NE) Reference: Well: MPS-41, True North Site: M Pt S Pad Vertical (TVD) Refer ence: MPS-41 71.5 !Nell: MPS-41 Section (VS) Referen ce: Well (O.OON,O.OOE,1 44.94Azi) ~'Vcllpath: MPS-41 Survey Calculation ~ Icthod: Mi nimum Curvature Db: Or acle Survey MD lucl Azim 1'VD Sys'1'VD N/S E/VV --- blapN -- MapF, Tool -i ft deg deg ft ft ft ft ft ft 2687.91 39.94 163.58 2526.73 2455.20 -618.00 348.25 5999273.72 565846.91 MWD+IFR+MS 2782.87 43.38 166.17 2597.67 2526.14 -678.92 364.67 5999212.94 565863.86 MWD+IFR+MS 2876.92 44.01 169.75 2665.68 2594.15 -742.45 378.20 5999149.55 565877.95 MWD+IFR+MS 2972.26 44.46 168.93 2733.99 2662.46 -807.81 390.51 5999084.30 565890.83 MWD+IFR+MS 3067.08 45.04 167.41 2801.33 2729.80 -873.14 404.20 5999019.10 565905.09 MWD+IFR+MS 3159.00 46.30 164.77 2865.57 2794.04 -936.95 420.01 5998955.44 565921.46 MWD+IFR+MS 3251.92 48.12 161.29 2928.70 2857.17 -1002.14 439.94 5998890.43 565941.96 MWD+IFR+MS 3344.07 48.12 159.70 2990.22 2918.69 -1066.81 462.85 5998825.98 565965.43 MWD+IFR+MS 3433.40 48.76 155.08 3049.50 2977.97 -1128.47 488.54 5998764.54 565991.66 MWD+IFR+MS 3531.19 49.57 150.38 3113.46 3041.93 -1194.19 522.44 5998699.13 566026.13 MWD+IFR+MS 3624.43 49.43 147.26 3174.03 3102.50 -1254.84 559.14 5998638.81 566063.36 MWD+IFR+MS 3713.98 49.24 143.87 3232.39 3160.86 -1310.85 597.54 5998583.14 566102.24 MWD+IFR+MS 3812.99 51.90 141.18 3295.27 3223.74 -1371.51 644.08 5998522.90 566149.31 MWD+IFR+MS 3910.89 55.17 138.75 3353.46 3281.93 -1431.75 694.74 5998463.11 566200.49 MWD+IFR+MS 4003.51 57.73 135.56 3404.65 3333.12 -1488.31 747.24 5998407.02 566253.48 MWD+IFR+MS 4098.42 58.16 134.31 3455.02 3383.49 -1545.12 804.18 5998350.72 566310.91 MWD+IFR+MS 4137.28 57.92 134.10 3475.59 3404.06 -1568.11 827.81 5998327.94 566334.74 9 5/8" 4140.00 57.90 134.09 3477.04 3405.51 -1569.71 829.47 5998326.35 566336.41 MWD+IFR+MS 4164.97 57.74 133.96 3490.34 3418.81 -1584.40 844.67 5998311.80 566351.74 MWD+IFR+MS 4263.88 56.26 134.15 3544.21 3472.68 -1642.08 904.28 5998254.65 566411.85 MWD+IFR+MS 4350.27 53.75 130.68 3593.76 3522.23 -1689.82 956.49 5998207.37 566464.47 MWD+IFR+MS 4449.74 51.41 128.40 3654.20 3582.67 -1740.12 1017.39 5998157.61 566525.80 MWD+IFR+MS 4538.28 49.62 127.27 3710.50 3638.97 -1782.04 1071.35 5998116.17 566580.12 MWD+IFR+MS 4629.06 48.02 125.02 3770.28 3698.75 -1822.35 1126.50 5998076.35 566635.62 MWD+IFR+MS 4727.28 48.27 123.43 3835.81 3764.28 -1863.49 1186.99 5998035.75 566696.46 MWD+IFR+MS 4820.97 47.94 122.43 3898.38 3826.85 -1901.40 1245.52 5997998.35 566755.32 MWD+IFR+MS 4919.97 47.56 121.70 3964.94 3893.41 -1940.31 1307.62 5997960.00 566817.75 MWD+IFR+MS 5010.11 46.35 123.19 4026.47 3954.94 -1975.64 1363.22 5997925.16 566873.65 MWD+IFR+MS 5048.10 46.92 123.32 4052.56 3981.03 -1990.78 1386.31 5997910.22 566896.87 MWD+IFR+MS 5073.75 46.92 123.32 4070.08 3998.55 -2001.08 1401.97 5997900.06 566912.62 7" 5081.00 46.92 123.32 4075.03 4003.50 -2003.99 1406.39 5997897.19 566917.07 PROJECTED to TD Actual Sidewall Core Points Thurs 20 Nov. 2008 Core Gun Run Open Hole Wireline MD Depth Time Shot Recovered Yeslno Core Gun Run Open Hole Time Wireline MD Depth Shot Recovered Yes/no Core Gun Run Open Hole Wireline MD Depth Time Shot Recovered Yes/no Run 1 4310 8:11 yes Run 2 4772 13:38 yes Run 3 4556 20:14 yes Run 1 4335 8:14 yes Run 2 4784 13:37 yes Run 3 4671 19:20 yes Run 1 4348 8:13 yes Run 2 4800 13:35 yes Run 3 4675 19:19 yes Run 1 4384 8:11 yes Run 2 4805 13:35 yes Run 3 4678 19:19 yes Run 1 4394 8:11 yes Run 2 4853 13:28 yes Run 3 4685 19:18 yes Run 1 4419 8:09 yes Run 2 4882 13:24 es Run 3 4891 19:15 yes Run 1 4499 8:06 yes Run 3 4898 19:14 yes Run 1 4530 8:05 yes Run 2 sub total 6 recovered Run 3 4700 19:12 yes Run 1 4554 8:03 yes 18 misfires Run 3 4710 19:12 yes Run 1 4581 8:02 yes Run 3 4715 19:11 yes Run 1 4587 8:02 yes Run 2 4816, 4792, 4761, 4746, 4743, 4735, 4731, 4722, Run 3 4720 19:10 yes Run 1 4595 8:01 yes misfires 4720, 4715, 4710, 4700, 4698, 4691, 4585, 4678, Run 3 4722 19:09 yes Run 1 4602 yes 4675, 4671 Run 3 4731 19:38 yes Run 1 4611 yes Run 3 4735 19:38 yes Run 1 4620 7:59 yes Run 3 4743 19:37 yes Run 1 4627 7:58 yes Run 3 4748 19:35 no Run 1 4838 7:57 yes Run 3 4747 20:08 yes Run 1 4846 7:56 yes Run 3 4761 19:35 yes Run 1 4653 7:55 yes Run 3 4792 8:05 yes Run 1 4654 7:30 yes Run 3 4816 20:03 yes Run 1 4656 yes Run 3 4870 20:01 es Run 1 4831 yes Run 1 4845 yes Run 3 sub total 20 recovered Run 1 4858 yes 1 misfire 4746' Run 1 4858 yes Grand Total 51 cores recovered Run 1 sub total 25 recovered 19 misfires Run 1 4882, 4853, 4816, 4800, 4792, 4784, 4772, 4761, 4746, 4743, 4731, 4722, 4712, 4710, 4698, 4691, 4685, 4678, 4671 misfires • RECOVERED SIDEWALL CORES Thurs 20 Nov. 2008 MPS-41 FORMATION Wireline MD De th Core Open Hole Run TUCZ 4310 Run 3 4335 Runt 4348 Run 1 4384 Run 2 4394 Runt 4419 Run 1 M87 U er 4499 Run 3 4530 Run 2 M87 Lower 4554 Run 2 4556 Run 3 M80 Upper 4581 Run 2 4587 Run 2 4595 Run 3 4602 Run 3 4611 Run 3 4620 Run 3 4627 Run 3 4638 Run 3 4646 Run 3 4653 Run 3 4654 Run 3 4656 Run 3 M80 Lower 4671 Run 3 4675 Run 3 4678 Run 3 4685 Run 3 4691 Run 3 4698 Run 3 4700 Run 3 4710 Run 3 4715 Run 3 4720 Run 3 4722 Run 3 4731 Run 3 4735 Run 3 4743 Run 3 4747 Run 3 4761 Run 3 4772 Run 2 4784 Run 2 4792 Run 3 4800 Run 2 4805 Run 2 M70 4816 Run 3 4831 Runt 4845 Run 1 4853 Run 2 4856 Run 1 4858 Run 1 4870 Run 3 4882 Run 2 ICJ NF NF NF NF NF NF NF Grand Total 51 cores recovered Run 1 sub total 25 recovered 19 misfires Run 2 sub total 6 recovered 18 misfires Run 3 sub total 20 recovered 1 misfire 4746' UPDATED November 20, 2008 MPS-41 -- - - Core points have been chosen from the LWD logs measured at time of drlg These depths correspond to sands. -- -- - Please check depth shift once final survey's are complete and change the sample pt. .depths to corresponds with the sands. Sample Points MWD Log Open Hole Priorit Sample Points MWD Log Open Hole Priority Sand reference no. Depth Wireline Depth Sand reference no. Depth Wireline Depth MD MD MD MD TUZC 4277 Delete 26 4691 4691 Hi h 4293 Delete 27 4698 4698 Hi h 1 4309 4310 4700 Hi h 2 4337 4335 28 4707 4710 Hi h 3 4350 4348 MDT SAMP 29 4715 4715 Hi h 4720 Hi h 4 4385 4384 30 4722 4722 Hi h 5 4395 4394 31 4730 4731 Hi h 6 4418 4419 4735 Hi h M87 U er 4448 Delete 32 4739 4743 Hi h 4474 Delete 33 4745 4746 Hi h 7 4499 4499 34 4772 4772 Hi h 8 4530 4530 M87 Lower 9 4555 4554 35 4782 4784 Hi h M80 U er 10 4585 4581 Hi h 36 4790 4792 Hi h Attem ted MDT SAM P -failed 11 4590 4587 Add Hi h M70 37 4797 4800 Hi h 12 4595 4595 Hi h 38 4805 4805 Hi h 13 4602 4602 Hi h 39 4813 4816 Hi h 14 4610 4611 Hi h 40 4830 4831 15 4619 4620 Hi h 41 4843 4845 16 4625 4627 Hi h MDT SAMP 42 4852 4853 Hi h No flash tst 17 4636 4638 Hi h 43 4855 4856 Add Hi h No flash tst 18 4646 4646 Hi h 44 4857 4858 Hi h 19 4652 4653 Add Hi h No flash tst 45 4877 4882 20 4653 4654 Add Hi h No flash tst MDT SAMP 21 4655 4656 Hi h No flash tst M80Lower 22 4670 4671 Hi h 23 4675 24 4677 4678 Hi h 25 4685 4685 Hi h • chlumberger nnnT yob Repo ...; DATE 9/6Y2006 - ~` Pagel of __ .. _ _ -- I - _ i MRPA MRML ~_ CLIENT BP ! Upper Element _ _ - ~~ '~. ~ Lower Element _ WELL: L-2191 MRPS 2'. MRPS 1. SO # Time file Time end Tool Zone De th TVD TVDSS Mud Before Pretest Mud Aker Formation Pressure Mob Tem Pum Time Flow V Flow ressure Chamber # Comments 20:00 19 s/ latch check 23:05 23 s Oed 9976 4742 4664 2324 10+10 2310 1739 4.70 95 good test 23:26 24 s OBd 10003 4747 4669 2338 10+10 2318 1746 84.00 95 good test 25 s OBd 10058 4756 4678 2343 10+10 2314 1965 0.60 95 supercharge 0:34 26 s OBd 10257 4770 4692 2333 10+10 2318 2027 0.30 95 supercharge 1:20 27 s OBd 10430 4764 4686 2333 10+10 2317 95 Lost Seal 1:35 28 s OBd 10431 4764 4686 2318 10+10 2314 1875 69.00 95 oodtest 2:02 29 s OBd 10547 4769 4691 2327 10+10 2317 1913 296.70 95 oodtest 2:31 30 s OBd 10640 4773 4695 2331 10+t0 2319 1943 314.40 95 oodtest 3:00 31 s OBd 10752 4777 4699 2331 10+10 2320 1978 75.70 95 oodtest 328 32 s OBd 10889 4783 4705 2336 10+10 2322 2013 107.50 95 oodtest 3:56 33 s OBd 11004 4788 4710 2336 10+10 2325 2028 129.20 95 ood test 4:21 34 s OBd 11100 4791 4712 2347 10+10 2325 2033 5.20 95 ood test 4:47 35 s OBd 11191 4795 4717 2352 10+10 2328 2036 33.20 95 ood test 5:09 36 s OBd 11260 4797 4719 2366 10+10 2331 2038 33.00 95 oodtest 5:32 37 s OBd 11395 4802 4724 2369 10+10 95 Lost Seal 5:43 38 s OBd 11396 4802 4724 2343 10+10 95 Lost Seal 5:51 39 s OBd 11397 4802 4724 2344 95 Lost Seal 6:22 40 s OBd 11574 4809 4731 2383 10+10 95 Low Perm. 6:36 41 s OBd 11575 4809 4731 2344 10+10 2330 2198 1.40 95 oodtest 7:05 42 s OBd 11614 4811 4733 2380 10+10 2332 2150 1.60 95 ood test 7:29 45 s OBd 11716 4817 4739 2378 10+10 2334 2086 95 D Test 7:54 46 s OBd 11776 4820 4742 2384 10+10 2337 2097 28.70 95 oodtest 8:15 47 s OBd 11845 4825 4746 2392 10+10 2346 2055 76.20 95 oodtest 8:42 48 s OBd 11964 4832 4754 2383 10+10 2342 2069 110.80 95 oodtest 9:08 49 s OBd 12039 4835 4757 2385 10+10 2356 2061 442.70 95 oodtest 9:24 50 s OBd 12108 4837 4759 2398 10+10 2356 2062 776.10 95 oodtest 9:50 53 10:50 s OBd 12108 4837 4759 2398 10+10 2337 2062 618.00 95 40 Min 8.8 al 2048 2868/1400 Sam le Point #1. MRMS #3, bottles 1 and 2. 12:15 56 17:30 a OBd 11776 4820 4742 2333 10 + 10 2323 2052 95 160 12 al 2050 2670/1295 Sam le Point #2. MRMS #3, bottles 3 and 4. 18:30 57 23:50 a OBd 11574 4809 4731 2353 10+10 2315 1610 95 252 5.1 1200 2865Y2876 Sam le Paint #3. MRMS #3, bottles 5 and 6. 0:30 58 1:15 OBd 11191 No seal usin MRPA 1:30 60 6:25 PA OBd 11191 4795 4717 2316 2309 2035 96 167 min 13 al 2022 1292!1290 Sam le Point #4. MRMS 2, Bottles 1 and 2 7:00 61 7:15 PO OBd 10890 -78 2308 10 + 10 2013 Lost seal after 1.5 hrs um in w/ uard 8:58 62 8:59 PO OBd 10892 No seal usin MRPO 9:10 63 PO OBd 10888 No seal usin MRPA 9:30 65 2:40 PA OBd 10890 4783 4705 150 9.2 1995 1397/1399 Sam le oint # 5 MRMS #2 Bottles 3 and 4 11'00 68 latch check 1:38 73 s Mb1 7803 4115 4037 2040 10+10 2020 1855 61.20 83 ood lest 1 5 74 ps Mb1 7899 4151 4073 2063 10+10 2038 1867 78.80 83 oodtest _ '0 .s ~ _, i us _ Ano ~~~ 4167 4089 2070 10+10 2043 1876 44.60 83 oodtest S. Thornhill Page 1 L-219i MDT_State Data_worksheet_12-28-07.x1s 1/9/2009 Ch~11t11bCPJ@P MDT Job Report DATE s/e/zoos Page 1 of -. ?'~ MRMU = ' MRML __ CLIENT BP ~~~,+ "- ~ Upper Element - _ _ - _ r- - _ Lower Element WELL: L-2191 - - ~ MRPS 2: MRPS 1. SO # Time File Time end Tool Zone De th TVD TVDSS Mud Before Pretest Mud After Formation Pressure Mob Tem Pum Time Flow V Fbw ressure Chamber # Comments 2:34 76 s Mb2 8080 4219 4141 2091 10+10 2068 1892 480.20 83 ood test 2:47 77 s Mb2 8124 4236 4157 2100 10+10 2070 1899 568.10 84 ood test 3:06 78 s Mb2 8204 4264 4186 2111 10+10 2085 1912 250.00 84 ood test 4:02 79 s Na 8440 4342 4264 2132 10+10 2103 1931 0.80 85 ood test 4:30 80 s Na 8456 4348 4270 2161 10+10 2120 1919 28.80 86 ood lest 4:50 81 s Na 8476 4355 4277 2164 10+10 2121 86 D Test 5:11 82 s Nc 8540 4377 4299 2172 10+10 2124 1950 2.90 86 ood test 5:40 83 s Ne 8622 4404 4326 2185 10+10 2131 2056 0.60 87 ood test 6:40 84 s OA 6893 4486 4408 2212 10+10 2187 2005 15.60 87 ood test 7:03 85 s OA 8927 4495 4417 2224 10+10 2200 2008 112.9 88 ood test 7:19 86 s OA 8977 4508 4430 2236 10+10 2201 2014 9.4 88 ood test 7:54 87 s OBa 9182 4559 4481 2258 10+10 2231 1994 124.2 88 ood test 8:12 88 s OBa 9207 4565 4487 2267 10+10 2234 1995 14.3 88 ood test 8:37 89 s OBa 9254 4577 4499 2355 10+10 2333 2017 1.9 89 ood test 8:56 90 s OBa 9267 4581 4502 2331 10+10 2324 2008 361.4 89 ood test 9:09 91 s OBa 9308 4591 4512 2325 10+10 2322 lost seal 9:22 92 s OBa 9309 4591 4513 2321 10+10 2318 89 lost seal 9:37 93 s OBb 9404 4614 4536 2331 10+10 2331 89 lost seal 9'.51 94 s OBb 9405 4614 4536 2336 10+10 2334 1965 2.6 90 ood test 10.13 95 ps OBb 9420 4618 4539 2337 10+10 2334 1960 3.4 90 and test 10.31 96 s OBb 9432 4620 4542 2334 10+10 2326 1960 47.0 90 ood test 11:08 97 s OBb 9646 4670 4592 2350 10+10 2343 90 lost seal 11:27 98 s OBb 9612 4662 4584 2343 10+10 2341 91 lost seal 11:46 99 s OBc 9660 4673 4595 2346 10 2344 lost seal 11:53 100 ps OBc 9661 4673 4595 2348 10 2342 lost seal 12:11 101 s OBc 9672 4676 4598 2343 10 2340 lost seal 12:47 102 s OBc 9736 4690 4612 2301 10 2346 lost seal 12.49 103 s OBc 9737 4690 4612 2344 2343 lost seal 106 Down to 12/26/07 14:20 108 18:28 a OBd 10547 4769 4691 2347 93 127 1860 2866, 2871 MRMS 2 123 Bottles 1 & 2 19:50 109 23.05 a OBd 10003 4747 4669 2320 2302 1746 93 130 14.7 1675 2867, 2872 MRMS 2 _123 Bottles 3 & 4 2867, 287 12/27/07 1 ~,30 110 6:30 a OBc 9672 4675 4597 2283 2256 1990 90 210 1950 1780 1291, 2875 MRMS 2 123 Bottles 5 & 6 1291 287 7:00 111 11:49 a Oeb 9432 4620 4542 2246 2211 1959 90 220 18.1 1952 1294, 2873 MRMS 1 1322 Bottles 1 & 2 1294 2873 13:05 112 0:00 a Na 8456 4348 4270 2121 2084 1864 85 167 10.8 1766 1401, 2869 MRMS 1 1322 Bottles 3 8 4 1401 2869 S. Thornhill Page 2 L-2191 MDT_State Data_worksheet_12-28-07.x1s 11912009 ~ # o a Depth Hydro Before Form Press Hydro After Form. Temp. Mobility TVD Depth ~ E $ z ~ a 3 J rn ~ ~ ~ u, J ~ ° E a' N E m ~ Remarks 13 1 4337 1779 1709.68 1770 77 19 3586 8:30am 20min 10ccX2 14 1 4350 1788 1705.62 1774 78 21 3593.6 9:OOam 20min 10ccX2 15 1 4395 1798 1690.2 1787 78 23 3620.6 9:30am 20min 10ccX2 17 1 4499 1830 1694.83 1820 79 18 3685.3 9:45am 15min 10ccX2 18 1 4530 1841 1721.04 1827 79 1 3705.2 10:OOam 20min 8.9cc & 4.Scc 19 1 4555 1846 1699.1 1835 79 14.6 3721.9 10:25am 20min 10ccX2 53 1 4584.0 1842 1700.19 1845 79 75 3740.3 2x10cc 47 pa 4588.0 1848.00 1698 78 lost seal with packer 20 1 4590 1859 1699.64 1849 79 142 3730 10:45am 15min 10ccX2 52 1 4595.0 1821 1703.49 1848 79 29 3747.6 2x10cc 46 pa 4595.0 1853.00 1702 poor seal with packers 51 1 4600.0 1843 1704.74 1835 79 80 3751.4 2x10cc 21 1 4605 1865 1703.86 1851 79 81 3754.4 11:OOam 20min 10ccX2 + 20cc 50 1 4610.0 1842.00 1706.3 1851 79 16.1 3757.8 2x10cc 43 pa 4655.0 1870.00 1747 79 3787.7 sample MS3 3,2 with packer 22 1 4655 1879 X 10ccX2 23 1 4655 1870 1746.98 1867 80 24 3787.7 11:45am 20cc 24 1 4670 1885 1740.4 1873 80 10.4 3797.8 12:OOpm 10ccX2 25 1 4698 1895 1750.36 1882 80 11.3 3816.33 12:15pm 10ccX2 26 1 4715 1905 X Set 2X 10ccX2 each 27 1 4716 1905 1755.3 1888 81 13.9 3828.4 12:45pm 20cc 42 pa 4716.0 1898.00 1755 80 3828.4 sample MS2 ,2,1 MS3 6,5 with packer 28 1 4790 X Set 2X 10ccX2 then 10ccX1 29 1 4792 1928 1763.38 1915 81 44 3879 1:30pm 10ccX2 30 1 4830 1943 X Set 2X 10ccX2 each 31 1 4828 1925 X 2:OOpm Moved pipe up 2' to retest 10ccX2 32 1 4854 1955 X 2:10 Reset 10ccX2 each time 33 1 4856 1955 1806.62 1932 81 9 3921.2 2:30 2X 10cc 38 1 4856 1930 attempt sample with probe 39 4855 1949 3921.2 48 pa 4588.0 attempt to pump down restart log in same place-los Page _ of Client: BP Exploration Alaska Well: MPS<1 Mutl type: WBM Fieltl: Milne Rig name: D-14 Deployment: DP H rlros[a[ic Initial Final Time to clean-u Time to sam le Sam le Size Distribution Station Sam le no MD (ft) TVD SS Zone Name Pressure Formation pressure Formation ressure Temp min min cc No. chambers Comments 1 1 4855 3921.2 1949 1806.2 81 170 15 450 1290 50%oil PVT ex ress 2 4855 3921.2 1949 1806.2 81 10 450 1399 70% oil H cal 3 4855 3921.2 1949 1806.2 81 13 450 3165 90 % oil H cal 2 4 4715 3827.6 1898 1755.3 80 300 15 450 3162 60% oil H cal 5 4715 3827.6 1898 1755.3 80 15 450 2875 50% oil PVT ex ress 6 4715 3827.6 1898 1755.3 BO 15 450 3161 60%0ll H cal 7 4715 ° 3827.6 3787 1898 ~ ~ 1870 1755.3 - 80 ~" 15 450 "' ~ °° -'- 450 3166 2871 60% oil 90%oil H cal H I : - 4 no sam le ' ~ 4590 3787 : , '-' 1870 ~ 1699.64 80% oil flowin u waro but no bott les available. Lower u '-, 450 s woultl not um to fill u the lower b 3182 orttles 90%0ll cal *' • 01/23/09 ~chlumherger Alaska Data & Consulting Services 0(~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ a ATTN: Beth ~J G a~~~~ CQ W/ all \ O _Inh IF ~ .... n.......:..a:__ N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1 -11 12111927 IBP & CROSS-FLOW STP .- 1 11/24/08 1 1 MPS-41 11966291 SCMT - '~ 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE V _ ~-'j"a 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE Q -~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~''` 12!30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - a ~,j 01/10/09 1 1 01-29 AP30-00011 USIT ~ - ~ ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP ~:-~• G.{ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT - 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILElWFL ~ (~'~ 01/08/09 1 1 07-OVA AYOO-00009 USIT - L 01/22/09 1 1 N-12 12014053 RST - 09/30!08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) t )~,4? 06/15/07 1 B-27A 11999059 RST ~ D~ ~ ~~' 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT _~L '~'~-' 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~~ ~ '"' 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT - C 12/07/08 2 1 ,G S~ ~ -~~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ n Anchorage, Alaska 99508 ' I Date Delivered Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 903 2 ~ .ne ATTN: Beth , Received by: ~,,-, to pn+,ee n .o~., .. _ :r . , n d^~"~ d t~, hs: asA~i~i _'N~-.. Sundry Permit to P & A MPS-41 (308-362) Page 1 of ! i ~- Maunder, Thomas E (DQA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 02, 2008 9:52 AM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 {208-159) (308-362) Paul, I concur. The first plug will be set on the retainer which itself will have been weight tested when set and pressure tested as well. will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Tuesday, December 02, 2008 9:18 AM To: Maunder, l`homas E (DOA) Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 (208-159) (308-362) Tom, Per our earlier conversation, the procedure written below (specifically "Tag TOC and pressure up to 1,000 psi and hold for 5 minutes " in step 4 was intended to address 2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. I could save some WOC time if I pressure tested the plug as described, proceeded with the cut and pull, and then tagged/tested the second 17 ppg KO plug with a drill bit. I believe this would be consistent with the intent of the regulation in that the abandonment will have been tagged and tested, and zones will have been adequately isolated. Please let me know if this is acceptable. Best Regards, Paul Hanson Office: 564-4195 Cell: 360-0388 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December Ol, 2008 3:11 PM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 (208-159) (308362) Paul, 12/2/2008 Sundry Permit to P & A MPS.(308-362) • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 01, 2008 3:11 PM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 (208-159) (308-362) Paul, Leaving the bridge plug in place will not alter the effectiveness of the proposed plugging. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Monday, December 01, 2008 2:07 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 (208-159) (308-362) Tom, Per our discussion earlier, our P&A Procedure as described below would change in that we would not drill out the bridge plug described in 1. below. This bridge plug is at 4650' and has been tested to 4000 psi. We would fill the 7" with 15.8 ppg Class G to below our cut and pull depth, and then spot a 17 ppg cement plug filling the remainder of the 7" and bringing cement 100' into the 9-5/8". Nat drilling out the plug will save us a round trip. I've included a new "cartoon" of the P&A with the changes and pertinent depths highlighted in yellow. Please let me know if this is satisfactory. Best Regards, Paul Hanson OfFce: (907) 564-4195 Cell: (907) 360-0388 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 01, 2008 1:22 PM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: Sundry Permit to P & A MPS-41 (208-159) (308-362) Paul, Sorry to have been delayed getting back to you on this. This information is sufficient. If there is a departure from these plans, please let us know. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansoni@bp.com] Sent: Thursday, November 20, 2008 11:19 AM To: Maunder, Thomas E (DOA) 12/1/2008 Sundry Permit to P & A MPS•(308-362) • Page 2 of 3 Cc: Kara, Danny T Subject: Sundry Permit to P & A MPS-41 (308-362) «MPS-41 P and A Schematic_11_19_08.x1s» Tom, In response to the requirement "provide specific plugging information via a-mail before proceeding" written on the Sundry Permit referenced above, I have included the specific procedures as they appear in the well program for MPS-41 below. 1. PU 4" drill pipe and "dumb-iron" BHA and RIH. Tag bridge plug and attempt break up or drill out. Push debris to bottom and record depth. POOH. LD BHA. 2. RU SLB Cementing. 3. RIH w/ 4" drill pipe (open-ended). Assuming that TD is approximately 4992'± MD, and the ES Cementer is at ~4296'MD, spot a 25 bbl of 15.8 Premium Class G cement (110 sx @ 1.17 ft3/sx) balanced plug. Balance the plug with seawater ahead and behind. This cement volume assumes TOC 50' below the ES Cementer. POOH. 4. RIH with a hydraulic multi-string casing cutter w/ "cut-rite" blades. Tag TOC and pressure up to 1,000 psi and hold for 5 minutes. Cut the 7" casing approximately mid- joint above the ES Cementer -minimum ~75' to 100' below the 9-5/8" shoe. Check for casing collars per Baker Fishing Services procedure before initiating the cut. 5. POOH and LD cutter. 6. Pull the pack-off. Pick up and run a 7", 26# casing spear and pack-off. Engage the 7" casing and pull approximately 2-3 feet. Note that if the casing does not pull after working and jarring pipe (pressuring up), a second cut may be necessary. Cut above the previous cut*. Assuming that the pipe is free- 7. Circulate through the cut to clean up the 7" x 9-5/8" annulus. 8. RU casing crew and POOH laying down the 7" above the cut. Note that some of this casing will be re-used in the 7" liner section of MPS-41 A. 9. RIH with drill pipe and tag TOC if possible. Spot ~ 31 bbl (~ 174 sx) of class G, 17 ppg balanced cement plug from the top of the first cement plug to ±100 ft. inside casing at + 4047' MD. It is critical that this kick-off plug setup in reasonable time, and this needs to be communicated to SLB prior to the job. Balance the plug with seawater ahead and behind. POOH above TOC and CBU. POOH and WOC. (Note: cement volume will depend on actual depths). When we run back in the hole with our drilling assembly to drill out, we will tag cement and (re) pressure test the 9-5/8" to 1000 psi to verify integrity after the DST testing and cut-&-pull operations. included a "cartoon" showing how the abandonment should look, assuming that our casing run goes as planned, and the pert intervals don't change from what is planned (locations highlighted in yellow). 12/1 /2008 l ~~ ~ { ,~ a BPXA r MPS-41 P ~ A Schematic Field: Milne Point ENG: P. Hanson UGNU HEAVY OIL TEST WELL on 14 RIG: Do Pad: S-Pad y RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-i n Wel Ihead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" SK Saud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACAL 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/sx 47 Ibs/ft DeepCrete 150°~ Excess L-80, In Permafrost BTC-M 40% below PF Int. Yield 6870 psi Collaspse 4750 psi TBII Cement 45 bbls, 113 sx TOC (pre ST) 4047' Casing Point 4,147' 3,480' 61.9° 12-1/4" Casing Cut -4,250' 17#ClassG ES Cementer at 4296' 15.8 Class G Actual Prod.. Casing Position of bridge plug Bridge PIUg defined by lags and Tested to 4585- perforations 4000 psi M80U Perfs 4605 7" Neu/Den w/ACAL 15.8 ClassG 26 Ibs/ft MRIL/GABI Bridge Plug 4650' L-80, MSOL Perf int. 4710'- 9.3 ppg BTC-M M-808 4730' Brine Int. Yield 7240 psi Collaspse 6600 psi M70S/SBF2-Top N 4,851' 3,927 Top NB (f/ MPS-11) 4,975' 4,008' 49° TD 5,081' 4,073' 49° 8-1/2" 12/1/2008 MPS-41 P and A Schematic 12_01_2008.x1s r~ ~1 ^' ~ ..,E ~' Y. BPXA MPS-41 P & A Schematic Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD ND SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106. 48" Welded/Isulated 11" 5K Spud Mud MWD/GR/RES None w Test Csg to NeulDen w/ACA ~ 2500 psi Gyro BPF 1,958' 1,903 Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/s 47 Ibs/ft DeepCrete 150% Excess ~~,> L_80, In Permafrost ~n BTC-M 40% below PF 'a. k~ ~ Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 45 bbls, 113 sx TOC (pre ST) 4047' Casing Point 4,147' 3,480' S8° 12-1/4" Casing Cut 4,238' 17# Class G E ES Cementer at 4296' M87S 4,430' 3,652' M87F (Ugnu Ma) 4,534' 3,719' 15.8 Class G Actual .. Casi Prod Position of _ bridge plug '4585'-4605' defined by logs and EMD -Upper perforations MWD/GR/RES M80U Perfint. :Pert 7" Neu/Den w/ACA M80_1 Rflood 4,674' 3,811 15.8 Class G 26 Ibs/ft MRIUGABI L-80, E4710'-4730' EMD -Lower MSOL Perfint. 15.8 Class G :Pert BTC-M M-80S 4,793' 3,889 Int. Yield 7240 psi Collaspse 6600 psi :Baffle Adaptor M70S/SBF2-Top N 4,851' 3,927 at 4992' MD. E BP and Perf Top NB (f/ MPS-11) 4,975' 4,008' 47 :Debris on top. ~ ~ 5,081' 4,075' 47° 8-1/2" 12/1/2008 MPS-41 P and A Schematic_11_19_08.x1s SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Milne Point Unit / Ugnu, MPS-41 Sundry Number: 308-362 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED thisZsl' day of October, 2008 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL. ~n aac ~s ~~n ~~ /o-~=off ,~"' V~~~ 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ AHer Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory o?08/S9 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- C?~i9o,?,3~/0000 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: MPS-41 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380110 Planned 72.5' Milne Point Unit / Ugnu ~ . 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5073' 4073' 5073' 4073' None None in L n M r II ru r I r ,~ ~ ~ 4 rf ce 1 -5/ " 41 8' 7 47 I r i p 7 1 'n r Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: , ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Pro ram 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 1, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Signature Phone 564-•`7 Date ~J o? DAR Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: PC'OV~c~~ S G~~ C ~~~~c~.n '~c~~~r~~".`,`c~ V ~,C11.~-i~G1~ ~' ~ C~ ~:~~ pro~~~~~~ ~~ Subsequent Form Required: `~~~ v APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date D - Z-~-d Form 10-403 Revised O6 6 .~ ~ ~ Submit In Duplicate k a ~h {~e~: ~ _ ~jr~lit a.,-. ~ `~ To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Paul Hanson, ODE Date: October 3, 2008 by Re: Permits to Drill MPS-41 and MPS-41A, and Sundry Permit to abandon MPS-41. MPS-41/41A will be the first of three wells drilled at Milne Point in Q4 of 2008 to test production methods for UGNU Heavy Oil. This well is part of a larger program to advance heavy oil production to commercial scale. ~~ Qr~® The MPS-41/MPS-41A appraisal well/ Horizontal Producer is scheduled to be drilled by Doyon Rig #14 with an estimated spud date of 11/01/08. Operations are expected to require 33 days to complete. The basic drilling plan is to spud the well with a 12-1/4" bit and drill to TD at 4138' t MD where 9-5/8" casing will be run and cemented to surface. An 8-1/2" hole (MPS-41) will then be drilled to TD at 5073' ± MD. After gathering extensive a-line logs, MDT samples and sidewall cores, 7" casing will be run and cemented to accommodate a planned cased hole DST program. The objective is to collect PVT-quality oil samples from the UGNU sands. . .~~ After the DST program, the open perforations of the 7" casing plugged and ~,~ abandoned prior to cuttin and pullin the 7" from 100' below the surface casin shoe to drill the U NU Horizontal Producer-leg of this well (MPS-41 A). The horizontal section of this well (8-1/2" hole) will be drilled off a cement Kick-off plug to ~~Q' a final depth of 7542' ± MD, with approximately 2000' of horizontal exposure in the ~~- upper UGNU sands targeted. After a MAD PASS logging and conditioning run, a 7" slotted x blank liner will be run with approximately 150' of lap with 9-5/8" casing. A retrievable bridge plug will be set above the liner top and pressure tested prior to circulating the well to 9.7 ppg NaCI brine (-2° TCT). The well will be temporarily completed with a kill string and dry-hole tree and freeze protected to 200' TVD: Attached for your review is a Well Plan Summary, directional plans, Wellbore Schematics, PTD forms 10-401 (2) for MPS-41 and MPS 41A, and Sundry Permit Application 10-403 for P&A of MPS-41. If you should have any questions concerning these applications or supporting documentation, please give me a call at (907) 564-4195. Thank you for your assistance. egards, Paul Hanson ADW-ACT Drilling Engineer MPS-41 Page 1 in the interpreted location of this fault plane; the P50 is expected at -3306 TVDss, however, the fault could be encountered as early in the well as -3223 TVDss (P10, 3769' MD) or as late as -3241 TVDss (P90, 3799' MD). Though this fault is interpreted to be a single fault plane, there is a possibility that it could be a zone of disruption affecting tens of MD feet of the wellbore, all within the defined zone of uncertainty. (Note that measured depths given are interpolated from MPS-41 WP(6). Hydrogen Sulfide • Hydrogen sulfide is not anticipated. The closest wells had <2 ppm. r Anti-collision Issues • All off-set wells Pass Major Risk for this wellplan. Distance to Nearest Prouerty • 687' (shortest distance from well path to MPU/PBU unit boundary). Distance to Nearest Well Within Pool • 280' from MPS-11 UGNU M80 penetration. DRILL & COMPLETION PROCEDURE Pre-Rig Operations 20" conductor casing has been installed to 112' MD. Drillin MPS-41 & 41 A Basic Plan 1. MIRU Doyon 14 and install diverter on conductor pipe and function test. 2. PU 5" DP. Drill 12-1/4' surface hole to 4138' MD (3483 TVDrkb) with water-base spud mud. Condition to run casing. 3. Run 9-5/8" surface casing and cement to surface. 4. ND Diverter, NU and test BOPE (Test BOPs to 3500 psi). 5. Drill out 9-5/8" casing plus 20'. Perform a LOT. 6. Drill 8-1/2" "pilot " (MPS-41) with water based mud through the Ugnu and Schrader N -sands to 5073' MD (4073' TVDrkb). Condition hole for MDT, a-Line logs, and sidewall cores. 7. Conduct open hole evaluation (MDT - M70 (Schrader NA) and M80L) in water based mud per MDT Sampling Plan and well-site geologist. POOH. 8. Evaluate MPS-41 per E-line Logging Program including sidewall cores. MPS-41 Page 7 • 9. RIH w/clean-out assembly and condition for casing. 10. Run and cement 7" casing. Bring cement to approximately 150' above the Ugnu M87S at 4430' MD, 3652 TVDrkb). TOC to be at 4288' MD, 3569' TVDrkb. Note that this is 150' below the 9-5/8" surface casing shoe and approximately 300' above the uppermost perforation depth for DST testing. Pressure up to open the ES Cementer. Cement will be circulated out above desired TOC through a Halliburton ES Cementer w/ seawater to reduce cut-&-pull risk. After returns clean up, displace seawater followed by 30 bbl of 3 ppb Biozan (cement contamination) pill. Kick out closing plug. Close the ES-Cementer with 1600 psi and check for flow. 11. Test BOPE. 12. MU 6-1/8" clean-out assembly, RIH to ES Cementer depth. 13. Test 7" casing to 2,000 psi and hold for 10 minutes (record). 14. Drill out closing plug and TIH and tag baffle adapter. Use viscous sweeps as needed and clean out wellbore. 15. Test 7" 26# L-80 BTC-M casing to 3000 psi f/ 30 mins -Record on chart . 16. Run USIT log from TD to surface to identify channeling, TOC and insure cut-&- pull. 17. Rig up and conduct DSTs of the M80L and M80U Ugnu as detailed in the DST Sampling Plan. RD DST equipment. Note that two individual zones will be ~ perforated and tested. The upper zone will be isolated from the lower zone by a cast iron bridge plug prior to the perforating and testing of the upper zone. 18. RIH w/DP and P&A the MPS-41 leg (open perfs) with cement. • RIH and drill out the cast iron bridge plug. POOH ~~~,~ Pick up a cement stinger and RIH. Lay in a balanced plug of 15.8 Class G 1 ~v.~ cement of sufficient volume to fill the volume from PBTD/top of fill to 100' above `~-\ the upper perfs. Circulate above TOC. POOH "~~ 19. PU Cut and pull assembly and tag and test TOC. Cut 7" casing 50' above cement (approximately 4230' MD -approximately 50' above the ES Cementer and 100' below the 9-5/8" shoe). Pump balanced cement kick-off plug and bring cement ~ 100' into the 9-5/8" casing. 20. RIH w/drilling assembly and tag/test cement. Displace to 9.2 ppg Rheliant MOBM per MI Swaco displacement procedures 21. Drill 8-1/2" hole from surface casing C~34138'MD to 7543' MD (3855' TVDrkb) per plan MPS-41A Wp 13. 22. Condition hole for LWD logging. MPS-41 Page 8 • 23. MAD PASS horizontal wellbore (DIR/GR/RES/DEN/NEU/ACAL) to define slot and blank pipe distribution in lateral. ACAL for appraising wellbore stability/condition. 24. Condition the wellbore and displace the wellbore to VERSAPRO SF prior to running 7" (Slot x Blank) liner. POOH. 25. Run 7" production liner. Note that this string will. be a combination of 7" 29# L- 80 slotted pipe and blank for approximately 2000' based on rock quality (logs) and solid 26# L-80 pipe to 150' above the 9-5/8" shoe. 26. RIH with a 9-5/8" RBP to just above the liner top and set and test to 1500 psi. 27. Displace the well above the RBP to 9.7 ppg brine to insure sufficient freeze protection from ~ 200' below surface to below the base of permafrost (diesel above). 28. Run 4-1/2" 12.6# L-80 Kill string to 2070' MD. 29. Land tubing hanger and test. 30. ND BOPE/NU and test tree. 31. Freeze protect w/diesel from 200' TVD to surface. . 32. RDMO. MPS-41 Page 9 ~~ ,~ BPXA ~ _ -.. .-. _ ''~ MPS-41 Test Well for Logging, MDT and Cased-hole DST Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" 5K Spud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/sx 471bs/ft DeepCrete t50%Excess L-80, In Permafrost BTC-M 40 % below PF Int. Yield 6870 psi Collaspse 4750 psi Teil Cement 69 bbls, 173 sx 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" USIT € ES Cementer LSND Mud M67S 4,430' 3,652' at 4288' Run 1 MDT M87F (Ugnu Ma) 4,534' 3,719' 49° Run 2 M80T 4,585' 3,752' Prod.. Casino Test Csg to MWD/GRlRES NGT/PEX/ECS/ 7° 3000 psi Neu/Den w/ACA AIT M80_1 Rflood 4,674' 3,811 49° 26 Ibs/ft Tail Cement MRIL/GABI L-80, 44 bbls, 210 sx Run 3 BTC-M 15.8 ppg-1.16 ft3/sx Sonic Scanner M-BOS 4,793' 3,889 PBTD-MSOS Int. Yield 72ao psi FMI Collaspse 6600 psi Run 4 M70S/SBF2-Top N 4,851' 3,927 SWCs Top NB (f/ MPS-11) 4,975' 4,008' 49` CH DST M80L & M80U TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 Well Plan Schematic.xls ~' BPXA - - • t ~:~: MPS-41 P & A Schematic Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 tt DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" 5K Soud Mud MWD/GR/RES None Test Csg to Neu/Den wlACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casino 415 Bbis, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/s 471bs/ft DeepCrete t5oi Excess L-80, In Permafrost BTC-M 40 / below PF Int. Yield 6670 psi Collaspse 4750 psi Tail Cement 69 bbls, 173 sx TOC (pre ST) 4038' Casing Point 4,138' 3,493' 61.9° 12-1/4" Casing Cut 4,238' 15.8 Class G E ES Cementer at 4288' M87S 4,430' 3,652' M87F (Ugnu Ma) 4,534' 3,719' 15.8 Class G Actual M801 4,585' 3,/5'L' Prod.. Casing Position of retainer plugs defined by logs. MWD/GR/RES M80L Perf int. 7" Neu/Den w/ACA M80_1 Rflood 4,674' 3,811 15.8 Class G 26 Ibs/ft MRIUGABI L-80, MBOL Perf int. 15.8 Class G BTC-M M-SOS 4,793' 3,889 Int. Yield 7240 psi Collaspse 6600 psi M70S/SBF2-Top N 4,851' 3,927 Top NB (f/ MPS-11) 4,975' 4,008' 49° TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 P and A Schematic.xls ~~ .I~ ::; MPS-41 A Horizontal Producer Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS! DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost ~. 91.1-Ib/ft H-40 FMC Gen 5 -106' ~ m 48" Welded/Insulated 11" 5K 200' ~ Saud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' -2,000' 4-1/2" Kill String Lead Cement Surface. Casing 415 Bbls, 606 sx 9.7 ppg 9-5/8" 10.7 ppg-3.85 ft3/sx NaCI 471bs/ft DeepCrete 150% Excess -2° TCT L-80, In Permafrost BTC-M 40 % below PF RBP -3400' Int. Yield 6870 psi Collaspse 4750 psi Tail Cement Liner Top 3,988' 3,418' 69 bbls, 173 sx VERSAPRO -150' Liner lap 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' SF DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" Rheliant MOBM will be used to drill the M87S 4,543' 3,652' 72° UGNU hOrlZOntal Prod. Liner MWD/GR/RES 7" Mw = 9.0 to 9.3 ppg Neu/Den w/ACA M87F 4,774' 3,714 77° 29 Ibs/ft ABI L-80, VERSAPRO SF BTC-M MOBM will be M-80T 44,946' 3,746 82° Slotted with 2" long, complete to drill the 0.125" width UGNU horizontal staggered slots - 32 M80_1 Rflood 6,224' 3,805 88° spf and blank pipe throughout horizontal. 7" 26# will cover the the curve and the lap TD 7,542' 3,855' 88° 8-1/2" 10/3/2008 MPS-41A Wefl Plan Schematic.xls SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit, Ugnu Undefined Oil Pool, MPS-41 BP Exploration Alaska Inc. Permit No: 208-159 Surface Location: 3224' FSL, 518' FEL, SEC. I2, T12N, R10E, UM Bottomhole Location: 4060' FNL, 3907' FEL, SEC. 07, T12N, R11E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seainount, Jr. Chair DATED thisa day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL `~"b(~ 20 AAC 25.005 ~~ /O /.rl08 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. S~pecify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well .Bond No. 6194193 11. Well Name and Number: MPS-41 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 5073 TVD 4073 12. Field /Pool(s): Milne Point Unit / Ugnu 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 380110 FEL, SEC. 12, T12N, R10E, UM 3224 FSL, 518 Top of Productive Horizon: UM 3844' FNL 4190 FEL SEC. 07 T12N R11E 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2008 , , , , , Total Depth: 4060' FNL, 3907' FEL, SEC. 07, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 687' 4b. Location of Well (State Base Plane Coordinates): Surface: x-565493 y-5999889 Zone-ASP4 10. KB Elevation Planned (Height above GL): 7 ~ feet 15. Distance to Nearest well Within Pool: 280' 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole An le: 61.90 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1687 Surface: 1305 1 in ~ n i h- Bo f .f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data " H 1 a rf 1 1 2 xAr r 1 -1/4" /8" 47# B 4 8' rf 41 x D r 17 " ~~ 7 , ~ g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Reentry Operations) Total Depth MD (tt): Total Depth TVD (tt): Plugs (measured): Effective Depth MD (tt): Effective Depth TVD (tt): Junk (measured): Casing Len th ize Cement Volume MD TVD Conductor /Structural Surface Intermediate r Liner Perforation Depth MD (ft): Perforation Depth TVD (tt): 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. Printed Name D Ka a Si nature ~ Contact Paul Hanson, 564-4195 Title Senior Drillin En leer Prepared By Name/Number: Phone 564-5667 Date '~ ? O Sondra Stewman, 564-4750 Commission Use On! Permit To Drill r; a?O~ fS API Number: 50- OoT 9- l7G~D Permit Approval See cover letter for O O r r 'r n Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes L?D No Mud Log Req'd: ^ yes ~No \ HZS Measures: Yes ^ No Directional Sunray Req'd: Yes ^ No Other: o es~ ~©~ ~~` O 2Q (~ Date APPROVED BY T COMM SSIONER Form 10-401 Revised i 2/2005 ~ ', ,. ~ j' _ ~ ~ su~mrc m uupucate • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Paul Hanson, ODE Date: October 3, 2008 by Re: Permits to Drill MPS-41 and MPS-41 A, and Sundry Permit to abandon MPS-41. MPS-41/41A will be the first of three wells drilled at Milne Point in Q4 of 2008 to test production methods for UGNU Heavy Oil. This well is part of a larger program to advance heavy oil production to commercial scale. The MPS-41/MPS-41A appraisal well/ Horizontal Producer is scheduled to be drilled by Doyon Rig #14 with an estimated spud date of 11/01/08. Operations are expected to require 33 days to complete. The basic drilling plan is to spud the well with a 12-1/4" bit and drill to TD at 4138' ± MD where 9-5/8" casing will be run and cemented to surface. An 8-1/2" hole (MPS-41) will then be drilled to TD at 5073' ± MD. After gathering extensive a-line logs, MDT samples and sidewall cores, 7" casing will be run and cemented to accommodate a planned cased hole DST program. The objective is to collect PVT-quality oil samples from the UGNU sands. After the DST program, the open perforations of the 7" casing plugged and abandoned prior to cutting and pulling the 7" from 100' below the surface casing shoe to drill the UGNU Horizontal Producer-leg of this well (MPS-41 A). The horizontal section of this well (8-1/2" hole) will be drilled off a cement Kick-off plug to a final depth of 7542' ± MD, with approximately 2000' of horizontal exposure in the upper UGNU sands targeted. After a MAD PASS logging and conditioning run, a 7" slotted x blank liner will be run with approximately 150' of lap with 9-5/8" casing. A retrievable bridge plug will be set above the liner top and pressure tested prior to circulating the well to 9.7 ppg NaCI brine (-2° TCT). The well will be temporarily completed with a kill string and dry-hole tree and freeze protected to 200' TVD. Attached for your review is a Well Plan Summary, directional plans, Wellbore Schematics, PTD forms 10-401 (2) for MPS-41 and MPS 41 A, and Sundry Permit Application 10-403 for P&A of MPS-41. If you should have any questions concerning these applications or supporting documentation, please give me a call at (907) 564-4195. Thank you for your assistance. egards, Paul Hanson ADW-ACT Drilling Engineer MPS-41 Page 1 Well Name: C~ MPS-41 and Ugnu Appraisal/Horizontal Test Well ~~~ y,, ~,~-~ i Drilling and Evaluation Plan Summary T e of Well: Ap raisal Well Surface Location: 2056' FNL and 518' FEL (AS BU/lt) Section 12, T12N, R10E UM ' ' N = 5,999,889 E = 565,493 9-5/8" Surface Casing Point 3,604' FNL and 4,476' FEL Section 7, T12N, R11 E UM E = 566,337' N = 5,998,348' Z = 3,421' TVDSS T2 - 10' below top M80T in MPS- 3,844' FNL and 4.190' FEL 41 Section 7, T12N, R11 E UM E = 566,626' N = 5,998,110' Z = 3,689' TVDSS T3 - TD MPS-41 4,061' FNL and 3,907` FEL Section 7, T12N, R11 E UM E = 566,912' N = 5,997,896' Z = 4,000' TVDSS T1 -Top of pump tangent in 4,277 FNL and 3,358' FEL MPS-41 A Section 7, T12N, R11 E UM E = 567,464' N = 5,997,685' Z = 3,707' TVDSS T2 -Invert point along horizontal 4,408 FNL and 3,043' FEL in MPS-41 A Section 7, T12N, R11 E UM E = 567,780' N = 5,997,557' Z = 3,717' TVDSS T3 - TD of horizontal section in 4,501' FNL and 1,357` FEL MPS-41 A Section 7, T12N, R11 E UM E = 569,468' N = 5,997,479' Z = 3,782' TVDSS Distance to Property line 687' (shortest distance from well path to MPU/PBU unit bounda Distance to nearest well 280' from MPS-11 UGNU M80 penetration AFE Number: 337483 Estimated Start Date: 01 Nov 2008 Ri Do on 14 Ri da s to com lete: 33 5,073 4,073' MD: (MPS-41) TVD: (MP$-41) ' Max Inc: 88° KOP: 400' KBE: 72.5' / 7,543' / 3,855 MPS-41 A MPS-41 A Well Desi n: Appraisal/Horizontal Producer (7" Slotted Liner) Ob'ective: U nu M Sands -Data Acquisition and Horizontal Test MPS-41 Page 2 4 • Mud Program: 12-1/4" Surface Hole (0' - 4.138' MD): Snud Densit PV YP H API Filtrate Chlorides m 8.6 - 9.8 10 - 25 30 - 50 8.5 - 9.5 NC-8 < 1000 8-1/2" Hole - (4.138' - 5.073' MD) MPS-41: LSND Densit PV YP H API Filtrate MBT 8.8-9.4 8-15 26-32 9.0-9.5 6-8 <25 ~~S p~~~~ v 8-1/2" Hole - (4.138' - 7.5431 MPS-41 A: RHELIANT Mineral Oil-Based Densit "PV YP H HTHPFiltrate"` °!o Oit ~9.0-9.3 15-20 15 - 20 N/A < 3 75 Completion Fluid - MPS-41 A: VERSAPRO SF Mineral Oil-Based ~~~~ ~~ Densi PV YP H HTHPFltrate % Oil ~9.0-9.3 20-35 10-20 N/A N/A 50 Upon completion of running of the 7" slotted x blank liner, an RBP will be set above the liner top, and the wellbore above the liner will circulated to seawater. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program Hole Size Csg/Liner WbFt Grade Conn Burst Collapse Length Top Bottom Diam MD/ MD/ TVDrkb TVDrkb 48-in 20-in 92 H-40 Weld 1530 520 120-ft 0 120' / Insulated 120' 12.25-in 9 5/8-in 47 L-80 BTC 6870 4750 4138' 0 4138'/ 3493' 8.5-in 7-in 26** L-80 BTC-M 7240 6600 5073' 0 5073' MPS-41 ** This is the 7" long string for the temporary completion of MPS-41 for the purpose of conducting DST 8.5-in 7-in 26* L-80 BTC-M 7240 6600 3555' 3988 7543'/ MPS-41A 3855' * 26# will be used above the slotted liner. The slotted liner is 29# with 1/8`h" slots, 2-inches long at 32 spf in a "staggered" pattern. 29# was used to compensate for the weakening of the pipe due to slots. Tubing 4.5-in 12.6 L-80 IBT-M 8430 7500 2070' 0 2070'/ 2000' MPS-41 Page 3 • Cement Program: Surface Casin Size 9-5/8", 47#, L-80, BTC Surface Casin to 4,138' Basis Lead cement = 3,638' MD to surface with 40% excess below the PF and 150% excess above through the PF. Tail cement = 500' MD above shoe lus 40% excess Total Cement Volume: 463 bbl Wash 10 bbl water Spacer 100-bbl 10.0-Ib/ al Mud ush II S acer Lead 415 -Bbl, 606 sx of 10.7 ppg DeepCrete - 3.85 ft3/sx Tail 69-bbl, 173-sx 12.5 Ib/ al Dee Crete - 2.24ft /sx Tem ~60° F From To Lead Cement 0 112 112 1958 1958 3638 Tail Cement 3638 4138 4056 4138 Surface Casing Cement Volumes -Calculated MPS-41 and 41A Hole Casing Total Yield Total Length Size Size Volume Excess BBLs CuFt/sx Sacks 112 18.376 9.625 26.7 0.00% 26.7 3.85 38.9 1846 12.25 9.625 103.0 150.00% 257.4 3.85 375.4 1680 12.25 9.625 93.7 40.00% 131.2 3.85 191.3 120.4 415.3 605.6 500 13.5 9.625 43.5 40.00% 60.9 2.24 152.7 82 9.95 0 7.9 0 7.9 2.24 19.8 68.8 172.5 DST Interval -MPS-41 7", 26#, L-80, BTC-M From ES Cementer C~ 4288' to 5073' (MPS-41). Casing Size Assume 280' shoe track to control rathole below lower perf zone. Actual de th to be determined b to data. Basis Lead cement = 5073' MD to ES Cementer with 30% excess in open-hole . Total Cement Wash 5 bbl water Volume: 463 bbl Spacer 50-bbl 10.0-Ib/ al Mud ush II S acer Lead 44 -Bbl, 210 sx of 15.8 Class G - 1.16 ft /sx Temp ~71 ° F MPS-41 7", 26# Casing From TD at 5073 To ES Cementer at 4288' (MPS-41) Hole Casing Total Yield Total From To Length Size Volume Excess Size BBLs CuFt/sx Sacks 4288 5073 785 8.5 7 17.7 30.00% 23.0 1.16 111.6 4793 5073 280 8.681 0 20.5 0 20.5 1.16 99.2 43.5 210.8 MPS-41 Page 4 Evaluation Program: 12-1/4" Section Open Hole: Photo Gyro • MWD/GR/Res • IFR/CASANDRA, • Sperry InSite • DEN/NEU w/ACAL 8-1/2" Section While Drilling MPS-41 MPS-41 Evaluation • DIR/GR/RES MDT-UGNU M70 & • IFR/CASANDRA, M80 • Sperry InSite • NGT/PEX/ECS/AIT • DEN/NEU w/ACAL • Sonic Scanner/FMI • MRIL/GABI • Sidewall Cores • Mudloggers • Cutting Samples • Isotubes W hile Drilling MPS-41 A • DIR/GR/RES • DEN/NEU w/ACAL • IFR/CASANDRA, • Sperry InSite Cased Hole: . GR/USIT • DST-UGNU M80L and M80U in MPS-41 Formation Markers (MPS-41): Formation Tops MD ~~~ TVD ~~ TVDss ~~ Pore Pressure EMW ~ppg) BPRF 1958 1903 -1830 809 8.50 U nu 4a (from MPS-11) 2964 2733 -2660 1176 8.50 220 Fault (P50) 3914 3379 -3306 1461 8.50 To Coal Zone 3922 3384 -3311 1463 8.50 TUZC 4095 3473 -3400 1503 8.50 9-5/8" Casin Point 4137 3493 -3421 1512 8.50 M87S 4430 3652 -3579 1582 8.50 M87F (-U nu Ma) 4534 3719 -3646 1612 8.50 M80T (-MB1) 4585 3752 -3679 1626 8.50 M80 1Rflood 4674 3811 -3738 1312 5.5 - 8.0 M80S 4793 3889 -3816 1687 8.50 M70S/SBF2 -To NA 4851 3927 -3854 1503 6.0 - 9.0 To NB (from MPS_l l) 4975 4008 -3935 1535 6.0 - 9.0 TD 5073 4073 -4000 1560 6.0 - 9.0 MPS-41 Page 5 Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 12-1 /4" 0 - 4,138' 4,138' Baker Hughes MXL - 1 .5 - .7 550-650 2 8-1 /2" 4,138' - 5,073' 935' FM3643Z Gong gauge Poc) .7 - 1.0 550-660 3 8-1/2" 4138' - 7,543' 3,405' FM3643Z Gong gauge Poc) .7 - 1.0 550-650 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • BOP Test Frequency: • Integrity tests: • Kick tolerance: • Planned completion fluid: 1687 psi at 3816' TVDss (M80S) 1305 psi at (Based on a full column of gas at 0.1 psi/ft) 3,500 psi Every 2 weeks FIT or LOT to 11.5 Ib/gal 20' below the 9-5/8" shoe. Infinite with 9.3 Ib/gal mud at below the 9-5/8" shoe. 8.6 ppg brine above RBP. Drilling Hazards & Contingencies: • Running Gravel/heavy clay problems have been encountered in some MPU wells. High viscosity mud will be utilized to augment hole cleaning. • Hydrates could be encountered. Expected potential depth for hydrates would be from base of permafrost at 2070' MD. Keep the mud as cool as possible, targeting a flow line temperature of 60° F. Lost Circulation • Lost Circulation is not anticipated as a major problem. However, good drilling practices need to be maintained to minimize the potential for pressure induced lost circulation. Expected Pressures • Formation pressure in the Ugnu is expected to be 8.35 ppg. • Formation pressure in the Schrader is expected to be ~7.0 ppg. Pad Data Sheet • Refer to the MPS-Pad Pad Data Sheets for off-set well data. Hydrocarbons • Hydrocarbons are anticipated in the Ugnu & Schrader Bluff intervals. Faults • The wellbore will encounter one interpreted fault, the KWS_220. This is a down-to-the- west , N-S striking fault with a displacement of approximately 120'. There is uncertainty MPS-41 Page 6 ~_I in the interpreted location of this fault plane; the P50 is expected at -3306 TVDss, however, the fault could be encountered as early in the well as -3223 TVDss (P10, 3769' MD) or as late as -3241 TVDss (P90, 3799' MD). Though this fault is interpreted to be a single fault plane, there is a possibility that it could be a zone of disruption affecting tens of MD feet of the wellbore, all within the defined zone of uncertainty. (Note that measured depths given are interpolated from MPS-41 WP(6). Hydrogen Sulfide • Hydrogen sulfide is not anticipated. The closest wells had <2 ppm. Anti-collision Issues • All off-set wells Pass Major Risk for this wellplan. Distance to Nearest Proaerty • 687' (shortest distance from well path to MPU/PBU unit boundary). Distance to Nearest Well Within Pool • 280' from MPS-11 UGNU M80 penetration. DRILL & COMPLETION PROCEDURE Pre-Rig Operations 20" conductor casing has been installed to 112' MD. Drilling: MPS-41 & 41A Basic Plan 1. MIRU Doyon 14 and install diverter on conductor pipe and function test. 2. PU 5" DP. Drill 12-1/4' surface hole to 4138' MD (3483 TVDrkb) with water-base spud mud. Condition to run casing. 3. Run 9-5/8" surface casing and cement to surface. 4. ND Diverter, NU and test BOPE (Test BOPs to 3500 psi). 5. Drill out 9-5/8" casing plus 20'. Perform a LOT. 6. Drill 8-1/2" "pilot " (MPS-41) with water based mud through the Ugnu and Schrader N -sands to 5073' MD (4073' TVDrkb). Condition hole for MDT, a-Line logs, and sidewall cores. 7. Conduct open hole evaluation (MDT - M70 (Schrader NA) and M80L) in water based mud per MDT Sampling Plan and well-site geologist. POOH. 8. Evaluate MPS-41 per E-line Logging Program including sidewall cores. MPS-41 Page 7 9. RIH w/clean-out assembly and condition for casing. 10. Run and cement 7" casing. Bring cement to approximately 150' above the Ugnu M87S at 4430' MD, 3652 TVDrkb). TOC to be at 4288' MD, 3569' TVDrkb. Note that this is 150' below the 9-5/8" surface casing shoe and approximately 300' above the uppermost perforation depth for DST testing. Pressure up to open the ES Cementer. Cement will be circulated out above desired TOC through a Halliburton ES Cementer w/ seawater to reduce cut-&-pull risk. After returns clean up, displace seawater followed by 30 bbl of 3 ppb Biozan (cement contamination) pill. Kick out closing plug. Close the ES-Cementer with 1600 psi and check for flow. 11. Test BOPE. 12. MU 6-1/8" clean-out assembly, RIH to ES Cementer depth. 13. Test 7" casing to 2,000 psi and hold for 10 minutes (record). 14. Drill out closing plug and TIH and tag baffle adapter. Use viscous sweeps as needed and clean out wellbore. 15. Test 7" 26# L-80 BTC-M casing to 3000 psi f/ 30 mins -Record on chart . ~ 16. Run USIT log from TD to surface to identify channeling, TOC and insure cut-&- \~,al ~ pull. ~~ 17. Rig up and conduct DSTs of the M80L and M80U Ugnu as detailed in the DST Sampling Plan. RD DST equipment. Note that two individual zones will be perforated and tested. The upper zone will be isolated from the lower zone by a cast iron bridge plug prior to the perforating and testing of the upper zone. 18. RIH w/DP and P&A the MPS-41 leg (open perfs) with cement. • RIH and drill out the cast iron bridge plug. POOH • Pick up a cement stinger and RIH. Lay in a balanced plug of 15.8 Class G cement of sufficient volume to fill the volume from PBTD/top of fill to 100' above the upper perfs. Circulate above TOC. POOH ~C~ 19. PU Cut and pull assembly and tag and test TOC. Cut 7" casing 50' above ~~ cement (approximately 4230' MD -approximately 50' above the ES Cementer and 100' below the 9-5/8" shoe). Pump balanced cement kick-off plug and bring cement ~ 100' into the 9-5/8" casing. 20. RIH w/drilling assembly and tag/test cement. Displace to 9.2 ppg Rheliant MOBM per MI Swaco displacement procedures 21. Drill 8-1/2" hole from surface casing C~34138'MD to 7543' MD (3855' TVDrkb) per plan MPS-41 A W p 13. 22. Condition hole for LWD logging. MPS-41 Page 8 23. MAD PASS horizontal wellbore (DIR/GR/RES/DEN/NEU/ACAL) to define slot and blank pipe distribution in lateral. ACAL for appraising wellbore stability/condition. 24. Condition the wellbore and displace the wellbore to VERSAPRO SF prior to running 7" (Slot x Blank) liner. POOH. 25. Run 7" production liner. Note that this string will be a combination of 7" 29# L- 80 slotted pipe and blank for approximately 2000' based on rock quality (logs) and solid 26# L-80 pipe to 150' above the 9-5/8" shoe. 26. RIH with a 9-5/8" RBP to just above the liner top and set and test to 1500 psi. 27. Displace the well above the RBP to 9.7 ppg brine to insure sufficient freeze protection from ~ 200' below surface to below the base of permafrost (diesel above). 28. Run 4-1/2" 12.6# L-80 Kill string to 2070' MD. 29. Land tubing hanger and test. 30. ND BOPE/NU and test tree. 31. Freeze protect w/diesel from 200' TVD to surface. . 32. RDMO. MPS-41 Page 9 22 23 P~24 19 i~ I poi Qom. MPS-43 ~- MPS-41 MPS-39 ^ 37 ~ ~ PLANT - ~ 15'00'00„ GRID ^ 35 LEGEND ^ 34 ~ 3z '~- AS-BUILT CONDUCTOR ~ ~ ^ EXISTING CONDUCTOR ^ 2at ^ 28 I ^ 27 ^ 26 ^ 25 ^ 241 ^ 23 ( ^ 22 ^ 2v I ^ 20 ^ 191 .;8 ( SURVEYOR'S CERTIFICATE ^ is I I HEREBY CERTIFY THAT I AM ^ 151 PROPERLY REGISTERED AND LICENSED ^ la TO PRACTICE LAND SURVEYING IN ^t3t THE STATE OF ALASKA AND THAT j ii THIS AS-BUILT REPRESENTS A SURVEY ^ 1o MADE BY ME OR UNDER MY DIRECT ^ st SUPERVISION AND THAT ALL ^ a DIMENSIONS AND OTHER DETAILS ARE s I CORRECT AS OF JULY 1, 2008. ^~ 3 fcr IZ 4 _ -~1 ^ 2 Sf ~ 7 T ZNN' R ~E ^ 1 Rti \ fl ~~ ~ ~~~ ~-~ I\ II ~_~ ~~ 27 r._ben 26 125 `l 1 I 30 35 ~ 36/ ~ ~~ ~ 32 2 1 6 ~ J~T 3 /'YIG/1 11 12 8 9 1 VICINITY MAP N.T.S. ~Q~E°OF°A`~b °4 9 ~ ~ °9~ °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° °'F~°°° °Leonard J. °0'Hanley ° ° ° ° 11386 °°° ,° o°°.~ ~-_-_ I >~ L--~ ~ 1. DATE OF SURVEY: JULY 1, 2008. MPU S-PAD 2. REFERENCE FIELD BOOK: MP08-03, PAGES 17-19. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON BPX MPU S-PAD OPERATOR MONUMENTS S-EAST S-MID AND S-WEST. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. i nrnrFn WITNI(\I PRf1TR~CTFII SFC 1~ T 17 N R 1n F_ l1MIAT MERIDIAN- AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC ELLAR BO SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS MPS 39 Y=5,999,896.46 N= 2,237.09 70'24'36.598" 70.4101661' 37 78' 3,232' FSL - X= 565,522.28 E= 6 384.91 149'27'59.307" 149.4664742' 489' FEL MPS-41 Y=5,999,888.58 N= 2,236.98 70'24'36.523" 70.4101453' 37 79' 3,224' FSL ' X= 565,493.29 E= 6 354.86 149'28'00.159" 149.4667108' 518 FEL MPS-43 Y=5,999,880.83 N= 2,236.94 70'24'36.449" 70.4101247' 37 12' 3,217' FSL ' X= 565,464.52 E= 6 325.06 149'28'01.005" 149.4669458' FEL 547 (~ 1 _ - CHECKED: JZW „' by O DATE: FR808 MPS 01-00 SHEET: ~~UJ"1 DRA"~"G MILNE POINT UNIT S-PAD ~ ~4~D~o J~ HD AS-BUILT CONDUCTORS E,~~ µo u~ swims SCALE: 1 ~ 1 0 2 O' ISSUED FOR INFORMATION TFB .2w WELL S-39, S-41 & S-43 N0. DATE REVISION BY CNK ,,xcwanAa~~iaws~n evsaa 1'= 160 ~~ ~~~ MPS-41 Test Well for Logging, MDT and Cased-hole DST Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ FORM DEPTH HOLE CASING MUD INFO MWD CH EVAL MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" 5K Spud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.85 ft3/sx 47 Ibs/ft DeepCrete t so i Excess L-80, In Permafrost BTC-M 40 / below PF Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 69 bbls, 173 sx 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" USIT ES Cementer LSND Mud M87S 4,430' 3,652' at 4288' Run 1 MDT M87F (Ugnu Ma) 4,534' 3,719' 49° Run 2 M80T 4,585' 3,752' Prod.. Casing Test Csg to MWD/GR/RES NGT/PEX/ECS/ 7" 3000 psi Neu/Den w/ACA AIT M80_i Rflood 4,674' 3,811 49° 26 Ibs/ft Tail Cement MRIUGABI L-80, 44 bbls, 210 sx Run 3 BTC-M 15.8 ppg-1.16 ft3/sx Sonic Scanner M-80S 4,793' 3,889 PBTD-M80S int. Yield 7240 psi FMI Collaspse 6600 psi Run 4 M70S/SBF2-Top N 4,851' 3,927 SWCs Top NB (f/ MPS-11) 4,975' 4,008' 49° CH DST M80L & M80U TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 Well Plan Schematic.xls r ~~ ~~, .. BPXA - MPS-41 P & A Schematic Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO MWD CH EVAL FORM MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost 91.1-Ib/ft H-40 FMC Gen 5 -106' 48" Welded/Isulated 11" 5K Soud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' Lead Cement Surface. Casing 415 Bbls, 606 sx 9-5/8" 10.7 ppg-3.65 ft3/sx 47 1bs/ft DeepCrete 150% Excess L-80, In Permafrost BTC-M 40°/, below PF Int. Yield 6870 psi Collaspse 4750 psi Tail Cement 69 bbls, 173 sx TOC (pre ST) 4038' Casing Point 4,138' 3,493' 61.9° 12-1/4" Casing Cut 4,238' 15.8 Class G f ES Cementer at 4288' M87S 4,430' 3,652' M87F (Ugnu Ma) 4,534' 3,719' 15.8 Class G Actual MBUI 4,585' 3,/52' Prod.. Casing Position of retainer plugs defined by logs. MWD/GR/RES M80L Perf int. 7" Neu/Den w/ACA M80_1 Rflood 4,674' 3,811 15.8 Class G 26 Ibs/ft MRIUGABI L-80, M80L Perf int. 15.8 Class G BTC-M M-80S 4,793' 3,889 Int. Yield 7240 psi Collaspse 6600 psi M70S/SBF2-Top N 4,851' 3,927 Top NB (f/ MPS-11) 4,975' 4,008' 49° TD 5,073' 4,073' 49° 8-1/2" 10/3/2008 MPS-41 P and A Schematic.xls r~ ~~ k~ p ~ 'rte ~ ~ BPXA ~~ ~ >s. ,. :,~,- MPS-41 A Horizontal Producer Field: Milne Point ENG: P. Hanson Pad: S-Pad UGNU HEAVY OIL TEST WELL RIG: Doyon 14 RKB: 72.5 ft DIR / LWD OH LOGS/ DEPTH HOLE CASING MUD INFO FORM MWD CH EVAL MD TVD SIZE SPECS CEM INFO INFO 20.000-in Wellhead NONE NONE Permafrost ~ 91.1-Ib/ft H-40 FMC Gen 5 -106' m m 48" Welded/Insulated 11" 5K 200' ~ Saud Mud MWD/GR/RES None Test Csg to Neu/Den w/ACA 2500 psi Gyro BPF 1,958' 1,903' -2,000' 4-1/2" Kill String Lead Cement Surface. Casing 415 Bbls, 606 sx 9.7 ppg 9-5/8" 10.7 ppg-3.85 ft3/sx NaCI 47 Ibs/ft DeepCrete 150% Excess -2° TC7 L-80, In Permafrost BTC-M 40 % below PF RBP -3400' Int. Yield 6870 psi Collaspse 4750 psi Tail Cement Liner Top 3,988' 3,418' 69 bbls, 173 sx VERSAPRO -150' Liner lap 12.5 ppg-2.24 ft3/sx TUZC 4,095' 3,473' SF DeepCrete Casing Point 4,138' 3,493' 61.9° 12-1/4" Rheliant MOBM will be used to drill the M67S 4,543' 3,652' 72° UGNU hOflZOntal Prod. Liner MWD/GR/RES 7" MW = 9.0 to 9.3 ppg Neu/Den w/ACA M87F 4,774' 3,714 77° 29 Ibs/ft ABI L-80, VERSAPRO SF BTC-M MOBM will be M-80T 44,946' 3,746 82° Slotted with 2° long, complete to drill the 0.125" width UGNU horizontal staggered slots - 32 M80_i Rflood 6,224' 3,805 gg° spf and blank pipe throughout horizontal. 7" 26# will cover the the curve and the lap TD 7,542' 3,855' 88° 8-1/2" 10/3/2008 MPS-41A Well Plan Schematic.xls COMPANY DETAILS REFERENCE INFORh1ATION SURVEY PROGRAM BP Amoco o-urdin:ne (N; E) Reference : 44'cll Centre: Plan MPS-41 -Zed, T me North epth Fm Ucpth Tu Sun ey/Plan Tuol Plan: Plan MPS-41 Wp 6.0 (Plan MPS-41 - Zedi Plan MPS-41) ~'u Ven icul (FVD)Reference: RK8725072.At Iculation Mcthud: Minimum Curvature Section f VS) Rcfaroncc : Slot - (U.UON.O.IIOE) 4.71 8011.23 Planned: Plan MPS-31 Wp G .0 V3 CB-GYR0.SS ' Created By: Spe rry D rilling DaIC: 9/2 31 2 0118 Error System: ISC14'SA Measured Depth Reference : RKB 7250 72.50 01122 5073.02 Planned: Plan MPS-41 Wp 6.U V3 MW Di IFR i MS Scan Me[hud: Tray Cylinder North Calculation MdhuJ : Minimum Cunamre Error Surf eu: Elliptical i Casing WELL DETAILS CASING DETAILS Nauru ~ N.S ~ Ei-W' Northing Lasting Lmitude Longitude Slut No. TVD N1D Name Sic Plan MPS-41 -Zed -81.86 -85255 599988858 56549329 7U°24'3G523N 149°28'60.159W NiA I 3493.42 4137.84 9 5/8" 9.62 5 SECTION DETAILS 2 4072.49 8073.01 7" 7.000 ' i Sec MD lac Azi TVD +N/-S +E/-W DLcg TFacc VSec Target HALLIBURTON ' I --- ~! 1 3a.71 0.00 0.00 34.71 6.06 0.00 0.00 0.06 0.00 ~ i ~ - - - - - aoo.ol o.oo U.oo 400.01 0.06 0.00 0.00 0.00 0.06 - - ~ ~ ' ' - - - - ~ 3 8110.00 SAU 145AU 799.49 -1429 111.00 1.25 145A0 17.44 $6PVIC®~ Or~~~~n ~6PP - ~--.-.- - . - ---- - -. - - 4 1843.72 25.87 145A0 1800.00 -240.61 168.47 2.OU 0.00 293.73 9 ( y ' 1- ... ...-.. ---. - - - - 5 1954.86 25.87 145.00 1900.00 -280.34 196.29 O.OU U.OU 342.23 ' __ _ __ !_ _ - -_ _ - -. --.- 6 2588 33 38 27 168.54 2437.80 -588.211 315.47 2.75 55.77 662.83 . ;_ - -_ . __ _._ 7 2956.82 . 38.27 IG8.54 2727.10 -811.88 360.82 11.00 0.00 872.13 ! 8 30011.01 38.90 166.72 2760.86 -838.19 366.59 3.01 298.32 896.99 . i 9 31161.63 39.83 164.211 2808.80 -876A1 376.41 3.00 299.21 933.61 1 ~ 10 3500.01 47.79 149.03 3125.48 -IIS L51 498.71 3.00 301.48 1229.49 - - ~ - , ~ 11 3912.81 56.69 137.95 3378.80 -1411.71 693.6) 3A2 311.93 1554.45 - ~ ~ ~ Stan Dir 1.25'/100' : 00' MD, 400'l'Vp 12 4094.15 60.88 133.1 I 3472.50 -1522.21 SU2.3G 3.25 314.07 170728 ~ 13 413759 61.90 133.11 3493.30 -1548.27 830.20 2.35 360.00 1744.59 - ~ ~, o 14 4157.55 61.911 133.11 3502.711 -1860.30 843.115 OAO 0.110 176L82 --- - ~'~ IS 4501.99 48.99 12724 3697J8 -1743.66 1058.45 4.00 -161.11 2035.51 _ _ _. _ _._ ~ ~' I6 4599.10 48.99 127.24 376L50 -1788.00 I 116.78 OAO OAO 2105.28 Zed Pilm TI _ _ _ , - - _ ~ j-- Slaty Dir 271 lU0' : 8 )' MD , 799.49'TVD 17 5073A2 48.99 127.24 4072.50 -2004.43 14111.46 O.UO OAO 2445.77 . IUUO _. ,. . _._ . . __ ; _ i ; _ ~_ . -.,-. , _. - t _ . ~ . Zp _ - ~ - _ - - { c -- - .. ~ I @ndDtr:l8 3.72 'MD,I800'TVD ~ - ~ _ Scott Dir 2. 57/10 11' : 1954.86' MD, 19 U'TVb I - _ ~. - _ . 1 _ ..- , ~ ~ '~- t - I ~ ~ ~ _ _ I a : _ - __ _.. _. - . . - PRF -- -` I - _. -_ ___ r - _ 2000 2000 ~ - - - - J _ E Di 2588 33'MD 2437 'TVD ~ _ ... _ --. n r . . .: , , i _ _ > I r l ~ Sta Ul:t/lU0' : 29 rt Dir 3 6 82' MD 2727 1'TV D I- I . ,~~ . ' ' . . . ' ' - -,- -- - I ' F ~ - - St ?/1110 :3000 anDir 3 MD, 2761L86 TVD )t - - ~ I , _ ~~ r ~ ~ m 4a ~ U Smtx Oir 3.02'. l0U' : 3500AJ' MQ 3 125. 8'TV D , _ . , . . ._ .._- _., g , ' ' " _ ' - - ~ ~ ~ ~ ~ - ~ - - I-- - - ~, 31100 Start it 3.25?/100 : 3962.8 1 M , 33 78.5 FVD - ~ ~ - • S rtDir2.35"IUU .4 0941 'MD ,3472.5'T VD - - _.. } - i -_. _. FORMATION TOP DETAILS - ~ ~- -- I I ~ nd Dir :4137.59 M D, 3 3.3 TVD I t i - I ~ "1' C' I Z tart Dir 4"100' .415 7.55' D, 35U2.TTV D ~ ~ _ No. TVDPath MDPath Fomtation i I I op o o nc ~ _ ~ I ~ ' ' i 220 cult (PST~ 1 1902.50 1957.64 BPRF ~ ~(iO0 , End Dir : 450,. M , 369 7.78' TVD 2 273250 2963.70 U nu 4a g i I ~ 9 Sib" ~ _ _ Fault P50 3 3378.50 391_.81 ~ ~ M87S M87F (-U mu Ma) ~cdPilot'FI i _ _ _.. 4 3383.50 3921.94 To Coal Zonc P ~ I , I ' I _ B o MM~I ~ MPS-4 1 T2.. -~--M PS.4lT3.. I 5 3472.50 4094.15 TUZC i IRI Io Tot _ al Dc th: ~, 073.0_ M 5 D. 4072;5' V D I i I I 6 365L50 4429.49 M87S I _ ~ ~ 7 371850 4533.57 M87F U mu Ma) ~ ~ ~ Plan M P ~ I I - ~~ i-- i - 50 4583.86 M80'I'(-MBI) 8 3751 . ~ I ~~ - . 77 M80 ]RFl d I I Tup NB MP -41 Wp 6.U ~ oo 9 3810.50 4673. - 10 3888.50 4792.63 MROS ~ , -... - - --- - i -- - I T NC P 7„ i _ i ._ _ _ - - - II 3926.50 4850.54 Top NA . i I - -- ~ ~ - - 12 4007.50 4973.97 Top NB ~ 1 I 13 4040.50 5024?6 Top NC i I ~ I '. ', I I I 1 , _I , I ~. ~ I TARGET DETAILS I I i ' ~ Name TVD +N/-S +E;-W Northine Easling Shape ~ ~' ~ I I'~ ~ ' Zcd Pilot Tl 376150 -1788.00 1116.78 5998110.61 566625.60 Circle (Radius: 100) MPS-41 T2.. 3790.10 -2352.16 2266.02 5997556.60 567779.63 Point 2000 3000 4000 SOUII 6000 7000 MPS-41 T3.. 3855.00 -2444.47 3954.01 5997479.10 569468.20 Point Vertical Section at 145.04° [IIIUOIUin] COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amocu inmc (N:'E) Rcfcrcncc: Well Ccntrc: Pl.m MPS-41 - ZcJ, Truc N Depth Fm Depth To Sunny: Plan Tuol Plan: Plan MPS-0I Wp 6.0 (Plan MPS-41 - ZaJ/Plan MPS-0I ) ical (TVD) Rcfcrcncc: RKB 7250 72.50 Cnlculwion Method: Minimum Curvature ection )VS1 Rcfcrcncc: SIW - (QOUN,O.OOE) 34.71 800.22 PlanneJ: Plan MPS-41 Wp bA V3 CB-0YRO-SS Created By: Sperry Drilling Date: 9/23/21108 Erzor System: ISCWSA urcJ Dcpih Rcfcrcncc: RKB 7250 7350 %0012 5073.02 PlanncJ: Pl:m MPS-0I W 6.0 V3 MWD i IFR ~ MS Scan MdhoJ: 'frrv Cylinder Nurth Calcul:dion MethuJ: Minimum Curvamrc Ertnr Surfam: Elliptical i Casing WELL DETAILS blaming Methal: Rules Base) Name iN/-S IEi-W' Northing Fasting Latitude LungituJc Slot H /~ LLlBUR'TOfV 1F\ 1 i i Plan MPS-YI-Zed -%L%6 -%5255 5999%%8.5% 56549329 7U°24'3G.523N 149°28'W 159W NrA I. - - Start Dar 115'?/1011' : 4( 0' MD, 4110'TVD i i.; TARGET DETAILS S(idPPy ~r~~~~Ag BBIPV~096 Start Dir 2'?/100':800' D.799.49'TVD i TVD +N.-S +F /-W Northin Fastin Sha e N n g g p . a tc ' 5 OW Zcd Pilot Tl 3%L50 -1788.110 1116.78 5998110.61 566625.60 Circle (Radius: loll) _ - MPS-41 T2.. 3790.10 -2352.Ih 2266.02 5997556.60 5(7779.63 Point - ~ ~ ' --- MPS-41 T3.. 3%55,00 -2444.47 3954.111 5997479.10 56946810 Point _i _:-_ _ ! _ 1500 Eud Dir 843.72' MD, 1800' TVD I Stan Uir .75''/ lU0' : 1954.86' MD, 9Q0'TVp -37 . ~ 200 ~ - . t , . ._ i , _ - { _ i ..~.. ~ ' ' __ '. . . . - :. . MU, 24 nd Dir-: 2588.33 7.8 TVD - -_ _ ~ t - ~ I ._.._. . - __- -_. __ - ' ~ ~ ! ~ a ' ~ : -- -... ~ - 74 I ' ' ' .... _ _ - __ i Stan Dir3.0I ./H)U :29 StarlDir 3?'100' : 3W0 6.8_ MD 2727.1 TVD~ 2~60.86'TVD l' MD ~ ~ ~ . _ ~ - _ _ -J . t - - . ~ _ _ I _ - - _ ' FORMATION TOP DETAILS _ ~ ~ ~ l - - i ~ -- ~ - ' I i ~ _ ~ ~ _ i ~ ' ' No. TVDPath MDPath Format on - - - • - 1 I I 1902.50 1957.64 BPRF ~ i '. ~ 2732.SU 2963.70 Ugnu 4a _ ' ~ ~ 3 3378.50 3912.81 220 Fault(P50) ~ t~ t c - I a i ~ I ~ i ~~ . 1 I _ , . _ , U ~t u Ma) 7 3718.50 4513 57 M87F ( - I ~ - i _- 8 3751.50 4583.86 MBUT(-MBI) '~ ii I ~ ~ ~ 9 3810.50 4673.77 M80 IRllood - - - -- ~ ~ ~ ~ - ~ ~ --- .. ~ - 10 3888.50 4792.63 MSOS I I i _.. ~ ~ ) _ _ 3926.50 4850.54 To NA P ~ --- - : 25'?/IOU' :391 tan Uir 3 7 3378 5'TVD 1' MD ~ p l2 4007 ~U 4973.97 To NB ~: i I . _ . . , , 13 4040.50 502426 Top NC I I ~ I ~ Start Dir ?.35'!/1 4094.15' MD, 3472.5'T D : I I _. - - I __ I End Dir :4137. 9' MD, 3493.3' TVD I I ~ ~ i - - - CASING DETAILS ~. . - - 9 I ~ 8' ~ ~ StanUtr4:'il ~ O':4157.55'ML2.350_T VD ~ - ; I - ~ - No. TVD MD Nantc Sizc ~. ~ ~ 3500 - i I ~ - --- - -I ~ ~ I _. I ~' I ~ 95 ,,~ cont. I I I ~ I 3493.42 4137.84 9 5/8" ).G,.S I { 1 ' ~ I ~- - i ~ 2 ~, 407_ 49 ~U73.U1 7" 7.Wll ~ r : 4502' MD. 3697. 8' TVU i '~ j i ~-- ~ I ~ I ~ '~ SECTION DETAILS i I Z PiWtTI I i i i I Sec MD Inc An 'IVD iNi-S iE;-W DLcg TFace VSce Target I I ~ I ~ ' ~ I 34.71 0.W U.OU 34.71 0.00 0.00 OA0 U.Ul1 O.UII - - _ -_ - ~ - - - - ~. '' . ~ 2 900.01 0UO QW 400.01 lID0 0.00 0.00 4W 400 ~ T tal Dcplh : SO73 112' MD 72 5' TVD _ 3 %00.00 i0U 145.00 799.49 -14.29 IO.OU L25 145.W 17.44 ~ ~ . , . - ~~ - 4 I%43.72 2587 145.00 1800.00 -240.61 IG8A7 2.110 0.00 293.73 i 4(~0( Pla t MPS-41 Wp 6.0 ~ 5 1954.%b 25.%7 141.00 1900.011 -2%0.34 196.29 U.W 400 34223 - ' - - - ' '. 6 '_5%%.33 38.27 I6%54 Z437.%U S%8.20 315.47 2.75 >5.77 662.83 ~ __ - - __. ! - ~ __ - I . 7 X956.%2 38'_7 IG%54 2727 111 %I L%8 36U.R2 llAO O.OU %72.13 ~ i ~, % 3110401 18.90 166.72 2760.%( 838.19 366.59 3.01 298.32 89699 ~ ~ - I ~ _ ~ ~ I 9 31161.63 39.%3 16420 2808 50 %76.01 376.41 3.00 399-21 93361 ~ ~ ~ ~ ~ ~ I ~ I I ~~ 111 3501!01 47.79 149.03 31214% 1111.51 49%.71 3.OU 301.4% 12-'9.49 ~ ~ - II 3912.%I 5669 137.91 337850 -1411.71 693.69 3.02 311.93 1554.45 I? 4094.15 60.%% 133.11 3472.50 -1522.21 802.3(+ 3.25 314.07 1707.28 li 4137.54 61.90 133.11 3493.30 -154827 %30.20 2.35 360.W 1744.59 14 4157.55 61.90 133.11 3502.70 -1560.30 843.05 0.00 400 1761.82 li 450199 48.99 12234 3697.7% -1743.66 11158.45 ~ 4.W -161.11 2035.51 7 40 11 09 1479 1849 2319 25 89 16 4599.111 48.99 127.24 37( L50 -178%.OU 1116.78 11.00 O.UU 210528 LcJ Pilot TI 17 5073.02 4%99 127.24 4072511 -2W4.43 1401 A6 O.UU O.OU 2445.77 West(-)/East(+) [It] S err -Sun P Y BP Planning Report Company:. BP Amoco Date: 9/23/2008 Time: 13150:04 Page: 1 Field: 'Milne Point Co-ordinate(NE) Refereuce: Well: Plan MPS-41 -Zed, True North Site: M Pf S Pad Vertical (TVD) Reference: RKB 72.50 72:5 Well: Plan MPS-41 -.Zed Section (VS) R eference: Well (O.OON;O:OOE,145.04Azi) Wellpath: Plan MPS-41 Survey Calculation Method: Minimum Curvature Db; Oracle Plan: Plan MPS-41 Wp 6.0 Date Composed: 2/20/2008 Version: 32 Principal: Yes Tied-to: From Well Ref. Point Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 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 Well: Plan MPS-41 -Zed Slot Name: Well Position: +N/-S -81.86 ft Northing: 5999888.58 ft Latitude: 70 24 36.523 N +E/-W -852.55 ft Easting : 565493.29 ft Longitude: 149 28 0.159 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 4137.84 3493.42 9.625 12.250 9 5/8" 5073.01 4072.49 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft ,deg deg. 1957.64 1902.50 BPRF 0.00 0.00 2963.70 2732.50 Ugnu 4a 0.00 0.00 3912.81 3378.50 220 Fault (P50 ) 0.00 0.00 3921.94 3383.50 Top Coal Zone 0.00 0.00 4094.15 3472.50 TUZC 0.00 0.00 4429.49 3651.50 M87S 0.00 0.00 4533.57 3718.50 M87F (-Ugnu Ma) 0.00 0.00 4583.86 3751.50 M80T(-M61) 0.00 0.00 4673.77 3810.50 M80 1 Rflood 0.00 0.00 _ 4792.63 3888.50 M80S 0.00 0.00 4850.54 3926.50 Top NA 0.00 0.00 4973.97 4007.50 Top NB 0.00 0.00 5024.26 4040.50 Top NC 0.00 0.00 Targets .Map Map. " <-- Latitude --? <- Longitude ->: Name Description TVD.. +N/-S +E/-W Northing Easting Deg Miu Sec Deg Min Sec Dip..: Dir. ft ft ft ft ft Zed Pilot T1 3761:50 -1788.00 1116.78 5998110.61 566625. 60 70 24 18.938 N 149 27 27.434 W -Circle (Radius: 100) -Plan hit target MPS-41 T2.. 3790.10 -2352.16 2266.02 5997556.60 567779. 63 70 24 13.387 N 149 26 53.763 W -Plan out by 1247.99 at 3790.10 -1807.90 1142.96 5998090.94 566651. 95 70 24 18.742 N 149 27 26.667 W MPS-41 T3.. 3855.00 -2444.47 3954.01 5997479.10 569468. 20 70 24 12.472 N 149 26 4.304 W -Plan out by 2814.47 at 3855.00 -1853.07 1202.37 5998046.30 566711. 75 70 24 18.298 N 149 27 24.926 W S err -Sun P Y BP Planning Report Company:. BP Amoco Date:. 9/23/2008 Time: 13:50:04 Page: : 2 Field: Milne Point Co-ordinate(NE) Reference: WeIL PIamMPS-41 -Zed, True North Site: M Pt S Pad Vertical (TVD}:Reference: RKB 72.50 72.5 Well: Plan MPS-41 -:Zed Section (VS) Reference: Well (Q.OON,O;OOE,1 45.04Azi) Wellpath: Plan MPS-41 Survey Calculation: Method: Minimum Curvature Db: Oracie Plan Section Information MD Incl..: Azim TVI) +N/-S +E/-W DLS Build Turn TF0 Target ft deg deg ft' ft ' ft ' deg/1t70ft deg/100ft deg/100ft deg 34.71 0.00 0.00 34.71 0.00 0.00 0.00 0.00 0.00 0.00 400.01 0.00 0.00 400.01 0.00 0.00 0.00 0.00 0.00 0.00 800.00 5.00 145.00 799.49 -14.29 10.00 1.25 1.25 0.00 145.00 1843.72 25.87 145.00 1800.00 -240.61 168.47 2.00 2.00 0.00 0.00 1954.86 25.87 145.00 1900.00 -280.34 196.29 0.00 0.00 0.00 0.00 2588.33 38.27 168.54 2437.80 -588.20 315.47 2.75 1.96 3.72 55.77 2956.82 38.27 168.54 2727.10 -811.88 360.82 0.00 0.00 0.00 0.00 3000.01 38.90 166.72 2760.86 -838.19 366.59 3.01 1.46 -4.21 298.32 3061.63 39.83 164.20 2808.50 -876.01 376.41 3.00 1.51 -4.09 299.21 3500.01 47.79 149.03 3125.48 -1151.51 498.71 3.00 1.82 -3.46 301.48 3912.81 56.69 137.95 3378.50 -1411.71 693.69 3.02 2.16 -2.68 311.93 4094.15 60.88 133.11 3472.50 -1522.21 802.36 3.25 2.31 -2.67 314.07 4137.59 61.90 133.11 3493.30 -1548.27 830.20 2.35 2.35 0.00 360.00 4157.55 61.90 133.11 3502.70 -1560.30 843.05 0.00 0.00 0.00 0.00 4501.99 48.99 127.24 3697.78 -1743.66 1058.45 4.00 -3.75 -1.70 -161.11 4599.10 48.99 127.24 3761.50 -1788.00 1116.78 0.00 0.00 0.00 0.00 Zed Pilot T1 5073.02 48.99 127.24 4072.50 -2004.43 1401.46 0.00 0.00 0.00 0.00 Survey MD Incl Azim TVD Sys TVD VS N/S E/W bLS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ff ft 34.71 0.00 0.00 34.71 -37.79 0.00 0.00 0.00 0.00 5999888.58 565493.29 CB-GYRO 100.00 0.00 0.00 100.00 27.50 0.00 0.00 0.00 0.00 5999888.58 565493.29 CB-GYRO 200.00 0.00 0.00 200.00 127.50 0.00 0.00 0.00 0.00 5999888.58 565493.29 CB-GYRO 300.00 0.00 0.00 300.00 227.50 0.00 0.00 0.00 0.00 5999888.58 565493.29 CB-GYRO 400.00 0.00 0.00 400.00 327.50 0.00 0.00 0.00 0.00 5999888.58 565493.29 Start Dir 1. 500.00 1.25 145.00 499.99 427.49 1.09 -0.89 0.63 1.25 5999887.69 565493.92 CB-GYRO 600.00 2.50 145.00 599.94 527.44 4.36 -3.57 2.50 1.25 5999885.03 565495.82 CB-GYRO 700.00 3.75 145.00 699.79 627.29 9.81 -8.04 5.63 1.25 5999880.59 565498.99 CB-GYRO 800.00 5.00 145.00 799.49 726.99 17.44 -14.29 10.00 1.25 5999874.38 565503.42 Start Dir 2. 900.00 7.00 145.00 898.94 826.44 27.89 -22.85 16.00 2.00 5999865.87 565509.49 MWD+IFR 1000.00 9.00 145.00 997.96 925.46 41.81 -34.25 23.98 2.00 5999854.55 565517.57 MWD+IFR 1100.00 11.00 145.00 1096.44 1023.94 59.17 -48.47 33.94 2.00 5999840.41 565527.65 MWD+IFR 1200.00 13.00 145.00 1194.25 1121.75 79.96 -65.50 45.87 2.00 5999823.49 565539.72 MWD+IFR 1300.00 15.00 145.00 1291.27 1218.77 104.16 -85.32 59.74 2.00 5999803.80 565553.77 MWD+IFR 1400.00 17.00 145.00 1387.39 1314.89 131.72 -107.90 75.55 2.00 5999781.36 565569.78 MWD+IFR 1500.00 19.00 145.00 1482.49 1409.99 162.62 -133.21 93.27 2.00 5999756.21 565587.72 MWD+IFR 1600.00 21.00 145.00 1576.46 1503.96 196.82 -161.22 112.89 2.00 5999728.37 565607.58 MWD+IFR 1700.00 23.00 145.00 1669.17 1596.67 234.28 -191.91 134.38 2.00 5999697.88 565629.33 MWD+IFR 1800.00 25.00 145.00 1760.52 1688.02 274.95 -225.22 157.70 2.00 5999664.77 565652.95 MWD+IFR 1843.72 25.87 145.00 1800.00 1727.50 293.73 -240.61 168.47 2.00 5999649.48 565663.85 End Dir : 1 1900.00 25.87 145.00 1850.64 1778.14 318.29 -260.73 182.56 0.00 5999629.49 565678.11 MWD+IFR 1954.86 25.87 145.00 1900.00 1827.50 342.23 -280.34 196.29 0.00 5999610.00 565692.02 Start Dir 2. 1957.64 25.92 145.14 1902.50 1830.00 343.44 -281.33 196.99 2.75 5999609.01 565692.72 BPRF 2000.00 26.59 147.29 1940.49 1867.99 362.17 -296.91 207.40 2.75 5999593.53 565703.27 MWD+IFR 2100.00 28.30 151.97 2029.25 1956.75 408.07 -336.67 230.64 2.75 5999553.98 565726.85 MWD+IFR 2200.00 30.15 156.14 2116.53 2044.03 456.25 -380.56 251.94 2.75 5999510.28 565748.54 MWD+IFR 2300.00 32.11 159.85 2202.13 2129.63 506.60 -428.49 271.26 2.75 5999462.53 565768.27 MWD+IFR 2400.00 34.18 163.17 2285.86 2213.36 559.00 -480.33 288.55 2.75 5999410.84 565786.01 MWD+IFR 2500.00 36.32 166.15 2367.53 2295.03 613.33 -535.98 303.77 2.75 5999355.33 565801.72 MWD+IFR 2588.33 38.27 168.54 2437.80 2365.30 662.83 -588.20 315.47 2.75 5999303.22 565813.88 End Dir 2600.00 38.27 168.54 2446.96 2374.46 669.45 -595.28 316.91 0.00 5999296.16 565815.37 MWD+IFR 2700.00 38.27 168.54 2525.47 2452.97 726.25 -655.99 329.21 0.00 5999235.57 565828.21 MWD+IFR 2800.00 38.27 168.54 2603.98 2531.48 783.05 -716.69 341.52 0.00 5999174.98 565841.05 .MWD+IFR 2900.00 38.27 168.54 2682.49 2609.99 839.85 -777.39 353.82 0.00 5999114.40 565853.88 MWD+IFR 2956.82 38.27 168.54 2727.10 2654.60 872.13 -811.88 360.82 0.00 5999079.97 565861.18 Start Dir 3. Went S err -Sun P Y BP Planning Report Company:... BP Amoco Date: 9/23/2008 Time: 13:50:04 Pagc: 3 Field: Milne Point Co-ordinate(NE}Reference: WeIL Plan MPS-41 - Zed', True No rth Site: M Pt S Pad Vertical (TVD) Reference: RKB 72.50 72.5 Well: Plan MPS-41 -Zed Section (VS}Reference: Well (O.ODN,O.OOE,145.04Azi) Wellpath: Plah MPS-41 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Inch Azim TVD ; Sys TVD VS N/S E/W I)LS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 2963.70 38.37 168.25 2732.50 2660.00 876.04 -816.06 361.68 3.01 5999075.80 565862.07 Ugnu 4a 3000.01 38.90 166.72 2760.86 2688.36 896.99 -838.19 366.59 3.01 5999053.72 565867.18 Start Dir 3. 3000.00 38.90 166.72 2760.85 2688.35 896.99 -838.18 366.59 0.00 5999053.72 565867.18 MWD+IFR 3061.63 39.83 164.20 2808.50 2736.00 933.61 -876.01 376.41 3.00 5999015.99 565877.33 MWD+IFR 3100.00 40.44 162.69 2837.84 2765.34 957.08 -899.72 383.46 3.00 5998992.35 565884.58 MWD+IFR 3200.00 42.12 158.92 2913.00 2840.50 1020.56 -961.98 405.17 3.00 5998930.28 565906.84 MWD+IFR 3300.00 43.91 155.40 2986.12 2913.62 1087.24 -1024.82 431.67 3.00 5998867.68 565933.89 MWD+IFR 3400.00 45.81 152.11 3057.01 2984.51 1156.94 -1088.05 462.88 3.00 5998804.73 565965.65 MWD+IFR 3500.01 47.79 149.03 3125.48 3052.98 1229.49 -1151.51 498.72 3.00 5998741.59 566002.04 Start Dir 3. 3500.00 47.79 149.03 3125.48 3052.98 1229.48 -1151.51 498.71 0.00 5998741.60 566002.03 MWD+IFR 3600.00 49.85 146.09 3191.33 3118.83 1304.65 -1214.99 539.10 3.02 5998678.48 566042.97 MWD+IFR 3700.00 51.97 143.33 3254.38 3181.88 1382.25 -1278.31 583.95 3.02 5998615.56 566088.37 MWD+IFR 3800.00 54.16 140.72 3314.48 3241.98 1462.05 -1341.29 633.15 3.02 5998553.02 566138.11 MWD+IFR 3900.00 56.40 138.26 3371.44 3298.94 1543.84 -1403.75 686.55 3.02 5998491.03 566192.06 MWD+IFR 3912.81 56.69 137.95 3378.50 3306.00 1554.45 -1411.71 693.69 3.02 5998483.14 566199.26 220 Fault 3921.94 56.90 137.70 3383.50 3311.00 1562.03 -1417.37 698.82 3.25 5998477.53 566204.44 Top Coal Z 4000.00 58.68 135.57 3425.11 3352.61 1627.36 -1465.37 744.17 3.25 5998429.93 566250.21 MWD+IFR 4094.15 60.88 133.11 3472.50 3400.00 1707.28 -1522.21 802.36 3.25 5998373.61 566308.89 TUZC 4100.00 61.02 133.11 3475.34 3402.84 1712.28 -1525.70 806.09 2.35 5998370.15 566312.65 MWD+IFR 4137.59 61.90 133.11 3493.30 3420.80 1744.59 -1548.27 830.20 2.35 5998347.80 566336.95 End Dir : 1 4137.84 61.90 133.11 3493.42 3420.92 1744.81 -1548.42 830.36 0.00 5998347.65 566337.12 9 5/8" 4157.55 61.90 133.11 3502.70 3430.20 1761.82 -1560.30 843.05 0.00 5998335.88 566349.91 Start Dir 4. 4200.00 60.29 132.48 3523.22 3450.72 1798.13 -1585.55 870.32 4.00 5998310.88 566377.40 MWD+IFR 4300.00 56.53 130.90 3575.59 3503.09 1881.00 -1642.20 933.90 4.00 5998254.78 566441.47 MWD+IFR 4400.00 52.78 129.18 3633.44 3560.94 1959.78 -1694.69 996.32 4.00 5998202.85 566504.33 MWD+IFR 4429.49 51.68 128.64 3651.50 3579.00 1982.17 -1709.33 1014.45 4.00 5998188.37 566522.60 M87S 4500.00 49.06 127.28 3696.47 3623.97 2034.08 -1742.74 1057.26 4.00 5998155.34 566565.68 MWD+IFR 4501.99 48.99 127.24 3697.78 3625.28 2035.51 -1743.66 1058.45 4.00 5998154.44 566566.89 End Dir 4533.57 48.99 127.24 3718.50 3646.00 2058.20 -1758.08 1077.42 0.00 5998140.19 566585.98 M87F (--Ug 4583.86 48.99 127.24 3751.50 3679.00 2094.33 -1781.04 1107.63 0.00 5998117.49 566616.39 M80T (-M 4600.00 48.99 127.24 3762.09 3689.59 2105.93 -1788.41 1117.32 0.00 5998110.20 566626.15 MWD+IFR 4642.68 48.99 127.24 3790.10 3717.60 2136.59 -1807.90 1142.96 0.00 5998090.94 566651.95 MPS-41 T .. 4673.77 48.99 127.24 3810.50 3738.00 2158.93 -1822.10 1161.64 0.00 5998076.91 566670.75 M80_1 Rflo 4700.00 48.99 127.24 3827.71 3755.21 2177.77 -1834.08 1177.39 0.00 5998065.07 566686.61 MWD+IFR 4741.58 48.99 127.24 3855.00 3782.50 2207.65 -1853.07 1202.37 0.00 5998046.30 566711.75 MPS-41 T .. 4792.63 48.99 127.24 3888.50 3816.00 2244.32 -1876.38 1233.03 0.00 5998023.26 566742.61 M80S 4800.00 48.99 127.24 3893.34 3820.84 2249.62 -1879.75 1237.46 0.00 5998019.94 566747.07 MWD+IFR 4850.54 48.99 127.24 3926.50 3854.00 2285.93 -1902.82 1267.82 0.00 5997997.13 566777.62 Top NA 4900.00 48.99 127.24 3958.96 3886.46 2321.47 -1925.41 1297.53 0.00 5997974.80 566807.53 MWD+IFR 4973.97 48.99 127.24 4007.50 3935.00 2374.61 -1959.19 1341.96 0.00 5997941.42 566852.25 Top NB 5000.00 48.99 127.24 4024.58 3952.08 2393.31 -1971.08 1357.60 0.00 5997929.67 566867.99 MWD+IFR 5024.26 48.99 127.24 4040.50 3968.00 2410.74 -1982.16 1372.17 0.00 5997918.72 566882.66 Top NC 5073.01 48.99 127.24 4072.49 3999.99 2445.77 -2004.42 1401.45 0.00 5997896.72 566912.13 7" 5073.02 48.99 127.24 4072.50 4000.00 2445.77 -2004.43 1401.46 0.00 5997896.71 566912.14 MWD+IFR Went D 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 0) e 1S 1S t7 0 1S 1S 1S 1S 12 i Ma) 1S 1S 1S 1S 4S Nano Plan MI'SJI ~ -N-S ~l:/-W /N -%I.XG -%S?SS W'tiLL ur.'rnas Northing 1'mwrp 5444xxX ~X Jf .]43,24 LaliluJe LungiluJe Sl~rt -11°?1'16."3N 144'av'UU.I i`IK Ni,\ ANTI-COLLISION SETTINGS InmgrSrlalion Mcthud:MD Imrnal: 25.011 Dcl)Ih Rlnoc Pronl: 34.71 TU 1073.02 Maxunwn Rungc~ 703.%3 Rcfcrcncc Plnn: Plan MPS-91 Nrp GA C'unu',wv un,vls ISP Amuc51 L I I M I ,J. M' (unalure [ s': .ISI wSn S.an M1l.thoJ- -I raS'L)I'nJer N~:ntl I~:rn;r lurta~c: I:Ihpliul t'a.ln,• ti'am4lg M1Ie111.rJ. KuIc. ISOXJ sua\•LV rKOCl5nn1 Ueptll Fnl Ueprh Iu Srurer:PWa foul it- I 6UILa' I I IL PI hll SJI ti r 5.U V 3 ('151 Y KII-SS %INI~ sm3Je Il~nnuLllan MPS-11 inp6~ly? M1Iwo IPK-nts ~~11 / lti I LLI' \ I I I UI 1:\IL% C l 60 From Colour To MU PI"nMrs-1' 35 250 eig. 150 ~yl 2SO SOO Kct: Ua[um: ftlCli 7'_50 7'_ illft tiG~, .. bSxnan (higm lhipn SwnmC o 2 O •\rlpJc ~N/-S 'k%-t4' Fruln I~'U J ~ SO 7 (OOO ~~ 1 ~ IVOO )2~0 IJS,IFJ' II1X1 MINI i!]I 125 ~~ )2so )soo 1500 1750 1750 2000 2000 2250 "' K 2250 2500 LL°rND lOO 2SOO 27SO - MI's-US In11'1-I ISI. M1iajor KixX ~ M111'5-1151n11'ti-USL I1. 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'~ •. ~,!-f ' 1'141\ ~MI~ l3 t.nlnl M17.IIrKI.L IIaII MI lJI .. , S' , ~ -6 y II,I M1IPS J1 NpM1.ll ~ N . I : ~;o , ~`' ~ \ J I aV , 75 A ~' b, ~ ~~ ' 2~~ 1 20 ~ ~ ~J ~ ~f 100 Pre Plans Re moved . See AC Scan for Plans Parents Profile @ No Errors 125 - 5.. MU Ine :\~i I V'U -N~-ti -h:'-l\ IIL., 11a~4 \'Sea I arg.r 21 50 ~ Ji.71 (1.1X1 Il lNl 31.71 II IXI (1.1X1 111X1 I1W II IXI 11X1111 I1.IN1 UINI lIMIUI U.IX1 U.INI 11.W U.W U,IXI 1 50 O IXI.U11 XI J 1117 Y IJS,INI 7Y)1Y IlS INI Ixla M1 I1 9 1111X1 Iii 1!5 (NI I JJ ' 111 fit 161117 'UII fl ql 4i :1 N,S ~paA _[~31XCI70I1) _ S i41xfi ? li , . IJS,INI I'HXI IXI _ ?XII t4 I`)6.?9 OW 111X1 tJ ~: x L ~5J `• 4 iM1 A' 3X 4 I6N.54 5J7.ltU IM151 7710 5% ?fl 115A7 .75 5577 66 %I -XII N% 360 %2 OUII UW n7 It 1 VO k~~ 1 OO - INNI.UI 3A 411 1(ri.72 70U hb . -x3N 14 36(.59 3.01 ?9Ni %4f,Yv 1 O 4 JIIL I.Gi 34.83 IG4.^_U _%ON.A1 -x'16.111 37441 3.1X1 ?99._1 4i3p1 III LIIII UI 17.]4 1J41U 3125.1% -1151.51 44%.71 3.110 1111.1% 1'_'_4.14 ravellin II 3412.%I Sfi.64 I? Jn4lJS 6nN% I~ JI3754 61 `NI g Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] ;l vy ;„W 13795 337%.511 111.11 31P_511 IJ?-11 3493 111 ;';;; 6$;;x -Il11.71 64i.fiv i.5q 111.9] ISS13< _I5v2~1 X51?16 .3.?5 111117 17117. a_X -I CyX,27 Pill.2U 2.35 1MI.lNI 1731.Sv ;;,,-~„ ,,r. ,;; -I,;," ';^'; I[ 1_1).111 ]X.44 I?7?4 i761SU -I"+%N.IxI 1116.-' N I -. x /a-J 1'il,n II 17 5117J.U2 4X.44 127.24 lU7'_.511 -_a(Nx1.33 VIII J6 MINI o.IXI '115. i'i S err -Sun P Y Anticollision Report Companyt BP Amoco Date: 9/23!2008 Time: 13:46:08 Page: 1 sField: Milne Point Reference Site: M Pt S Pad Co-ordinate(NE) Reference: Well: Plan MPS-41 -Zed, True North Reference Well: Plan MPS-41 -Zed Vertical (TVD) Reference; RKB 72.50 72.5 Reference Wellpath: Plan MPS-41 1)b: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.71 to 5073.02 ft Scan Method: Trav Cylinder North Maximum Radius: 703.83 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/17/2008 Validated: No Version: 3 Planned From To Survey Toolcode Tool N ame ft ft 34.71 800.00 Planned: Plan MPS-41 Wp 6.0 V32 CB-GYRO-SS Camera based gyro single shots 800.00 5073.02 Planned: Plan MPS-41 Wp 6.0 V32 MWD+IFR +MS MWD +IFR + Multi Station Casing Points MD TVD `Diameter Hole Size Name ft ft in in 4137.84 3493.42 9.625 12.250 9 5/8" 5073.01 4072.49 7.000 8.500 7" Summary <---------- Offset Wellpath -- ------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area.. Deviation Warning ft ft ft ft ft M Pt S Pad MPS-05 MPS-05 V2 4840.95 7925.00 343.46 79.48 263.98 Pass: Major Risk M Pt S Pad MPS-05 MPS-05L1 V2 4819.38 7900.00 284.16 77.21 206.95 Pass: Major Risk M Pt S Pad MPS-06 MPS-06 V11 2446.14 2525.00 83.72 38.03 45.68 Pass: Major Risk M Pt S Pad MPS-08 MPS-08 V10 2128.47 2175.00 45.27 34.03 11.24 Pass: Major Risk M Pt S Pad MPS-08 MPS-08PB1 V9 2128.47 2175.00 45.27 34.03 11.24 Pass: Major Risk M Pt S Pad MPS-11 MPS-11 V5 355.89 350.00 454.87 7.65 447.23 Pass: Major Risk M Pt S Pad MPS-13 MPS-13 V7 2080.72 2100.00 56.02 33.47 22.55 Pass: Major Risk M Pt S Pad MPS-14 MPS-14 V6 1537.19 1600.00 80.22 26.30 53.92 Pass: Major Risk M Pt S Pad MPS-17 MPS-17 V8 1488.79 1475.00 343.65 21.82 321.83 Pass: Major Risk M Pt S Pad MPS-17 MPS-17L1 V2 1488.79 1475.00 343.65 21.72 321.93 Pass: Major Risk M Pt S Pad MPS-20 MPS-20 V7 1145.48 1150.00 295.53 19.01 276.53 Pass: Major Risk M Pt S Pad MPS-21 MPS-21 V19 796.96 800.00 295.68 14.33 281.35 Pass: Major Risk M Pt S Pad MPS-22 MPS-22 V8 1392.48 1425.00 140.62 22.46 118.17 Pass: Major Risk M Pt S Pad MPS-23 MPS-23 V12 1238.61 1225.00 256.99 18.77 238.22 Pass: Major Risk M Pt S Pad MPS-23 MPS-23L1 V2 1238.61 1225.00 256.99 18.75 238.25 Pass: Major Risk M Pt S Pad MPS-24 MPS-24 V3 1187.68 1200.00 220.42 19.35 201.07 Pass: Major Risk M Pt S Pad MPS-24 MPS-24PB1 V11 1187.68 1200.00 220.42 19.63 200.79 Pass: Major Risk M Pt S Pad MPS-24 MPS-24PB2 V5 1187.68 1200.00 220.42 19.58 200.83 Pass: Major Risk M Pt S Pad MPS-25 MPS-25 V3 879.03 875.00 239.87 14.69 225.17 Pass: Major Risk M Pt S Pad MPS-25 MPS-25L1 V10 879.03 875.00 239.87 14.59 225.28 Pass: Major Risk M Pt S Pad MPS-26 MPS-26 V6 1413.71 1425.00 61.27 24.07 37.21 Pass: Major Risk M Pt S Pad MPS-27 MPS-27 V9 1065.07 1075.00 185.57 16.79 168.77 Pass: Major Risk M Pt S Pad MPS-27 MPS-27L1 V7 1065.07 1075.00 185.57 16.69 168.88 Pass: Major Risk M Pt S Pad MPS-27 MPS-27P61 V2 1065.07 1075.00 185.57 16.79 168.77 Pass: Major Risk M Pt S Pad MPS-28 MPS-28 V5 1061.77 1075.00 161.37 17.45 143.92 Pass: Major Risk M Pt S Pad MPS-28 MPS-28P61 V6 1061.77 1075.00 161.37 17.45 143.92 Pass: Major Risk M Pt S Pad MPS-28 MPS-28PB2 V5 1061.77 1075.00 161.37 17.45 143.92 Pass: Major Risk M Pt S Pad MPS-29 MPS-29 V8 752.86 750.00 173.56 13.57 159.99 Pass: Major Risk M Pt S Pad MPS-29 MPS-29L1 V6 752.86 750.00 173.56 13.44 160.12 Pass: Major Risk M Pt S Pad MPS-30 MPS-30 V11 1113.71 1125.00 134.43 18.55 115.88 Pass: Major Risk M Pt S Pad MPS-31 MPS-31 V8 1236.02 1250.00 41.09 20.05 21.04 Pass: Major Risk M Pt S Pad MPS-32 MPS-32 V5 724.04 725.00 133.51 14.96 118.55 Pass: Major Risk M Pt S Pad MPS-33 MPS-33 V11 1073.49 1075.00 98.34 17.11 81.22 Pass: Major Risk M Pt S Pad MPS-33 MPS-33A V7 1067.71 1075.00 98.28 17.03 81.25 Pass: Major Risk M Pt S Pad MPS-34 MPS-34 V9 743.04 750.00 85.41 13.71 71.70 Pass: Major Risk M Pt S Pad MPS-34 MPS-34L1 V1 743.04 750.00 85.41 13.66 71.75 Pass: Major Risk M Pt S Pad MPS-34 MPS-34L2 V9 743.04 750.00 85.41 13.55 71.86 Pass: Major Risk M Pt S Pad MPS-35 MPS-35 V17 743.57 750.00 62.16 14.45 47.71 Pass: Major Risk M Pt S Pad MPS-35 MPS-35P61 V16 743.57 750.00 62.16 14.61 47.55 Pass: Major Risk M Pt S Pad MPS-35 MPS-35P62 V16 743.57 750.00 62.16 14.45 47.71 Pass: Major Risk M Pt S Pad MPS-37 MPS-37 V7 400.53 400.00 60.17 9.69 50.48 Pass: Major Risk M Pt S Pad Plan Anges Plan Anges VO Plan: PI 424.76 425.00 59.92 9.55 50.37 Pass: Major Risk M Pt S Pad Plan Fem Plan Fem V2 Plan: Fer 399.04 400.00 120.93 9.08 111.85 Pass: Major Risk S err -Sun P Y Anticollision Report Company:. BP Amoco Date: 9/23/2008 Time: :13:46:08 Page: 2 Field: Milne Point Reference Site; M Pt S Pad Co-ordinate(NE) Reference: Well: Plart MPS-41 -Zed, True North Reference WeIL• Plan MPS-41 -Zed Vertical ('TVD) Reference: RKB'72.50 72.5 Reference Wellpath: - Plan MPS-41 Db: Oracle Summary ----- - Offset Wellpath -- ---> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath' MD MD Distance Area Deviation R'arning ft ft ft ft ft , M Pt S Pad Plan Mary Jean Plan Mary Jean VO Plan 399.19 400.00 90.05 8.19 81.85 Pass: Major Risk M Pt S Pad Plan MPS-39 / Trigon Plan MPS-39 VO Plan: M 300.04 300.00 31.12 7.55 23.57 Pass: Major Risk M Pt S Pad Plan MPS-41 -Zed Plan MPS~1A V4 Plan: 3500.01 3500.01 0.00 0.80 -0.80 FAIL: NOERRORS M Pt S Pad Plan New Ext. Sodcey Plan New Ext Sockeye 1 400.22 400.00 258.94 9.33 249.61 Pass: Major Risk M Pt S Pad Plan Xenon MPS-43 Xenon V1 Plan: Xenon W 349.73 350.00 30.76 8.48 22.27 Pass: Major Risk Site: M Pt S Pad Well: MPS-05 Rule Assigned: Major Ris k Wetlpath: MPS-05 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVI) Ref Offset TFO+AZI TFO-HS Gasing/IlSflistance Area Deviation Warning ft ft ft ft ft ft, deg deg in ft ft ft 55.70 55.70 50.00 50.00 0.05 0.01 75.49 75.49 7.625 544.21 1.22 542.98 Pass 80.70 80.70 75.00 75.00 0.11 0.03 75.48 75.48 7.625 544.23 1.69 542.54 Pass 105.70 105.70 100.00 100.00 0.17 0.04 75.47 75.47 7.625 544.26 2.17 542.09 Pass 130.70 130.70 125.00 125.00 0.26 0.07 75.46 75.46 7.625 544.31 2.77 541.54 Pass 155.70 155.70 150.00 150.00 0.34 0.10 75.45 75.45 7.625 544.37 3.36 541.01 Pass 180.70 180.70 175.00 175.00 0.43 0.13 75.43 75.43 7.625 544.45 3.96 540.49 Pass 205.70 205.70 200.00 200.00 0.51 0.14 75.41 75.41 7.625 544.55 4.49 540.06 Pass 230.70 230.70 225.00 225.00 0.57 0.15 75.39 75.39 7.625 544.68 4.94 539.74 Pass 255.69 255.69 250.00 249.99 0.62 0.17 75.35 75.35 7.625 544.83 5.40 539.44 Pass 280.69 280.69 275.00 274.99 0.67 0.18 75.31 75.31 7.625 545.00 5.85 539.14 Pass 305.68 305.68 300.00 299.98 0.73 0.20 75.26 75.26 7.625 545.17 6.32 538.85 Pass 330.68 330.68 325.00 324.98 0.78 0.23 75.20 75.20 7.625 545.39 6.78 538.61 Pass 355.66 355.66 350.00 349.96 0.82 0.25 75.12 75.12 7.625 545.68 7.26 538.42 Pass 380.65 380.65 375.00 374.95 0.87 0.28 75.04 75.04 7.625 546.02 7.73 538.29 Pass 405.87 405.87 400.00 399.93 0.91 0.31 74.94 289.94 7.625 546.44 8.17 538.27 Pass 431.89 431.89 425.00 424.90 0.91 0.34 74.83 289.83 7.625 546.96 8.53 538.43 Pass 457.90 457.90 450.00 449.87 0.92 0.36 74.69 289.69 7.625 547.57 8.88 538.69 Pass 483.88 483.88 475.00 474.83 0.92 0.39 74.53 289.53 7.625 548.27 9.24 539.03 Pass 509.84 509.83 500.00 499.77 0.93 0.42 74.33 289.33 7.625 549.12 9.60 539.51 Pass 535.75 535.73 525.00 524.69 0.94 0.45 74.11 289.11 7.625 550.16 9.99 540.17 Pass 561.61 561.58 550.00 549.60 0.96 0.48 73.86 288.86 7.625 551.39 10.37 541.02 Pass 587.42 587.37 575.00 574.47 0.97 0.51 73.58 288.58 7.625 552.85 10.76 542.09 Pass 613.14 613.07 600.00 599.29 0.99 0.54 73.26 288.26 7.625 554.67 11.16 543.51 Pass 638.77 638.66 625.00 624.04 1.01 0.58 72.90 287.90 7.625 556.87 11.56 545.31 Pass 664.27 664.13 650.00 648.73 1.03 0.61 72.51 287.51 7.625 559.46 11.97 547.49 Pass 689.65 689.46 675.00 673.33 1.05 0.64 72.08 287.08 7.625 562.47 12.38 550.09 Pass 714.88 714.63 700.00 697.83 1.08 0.68 71.61 286.61 7.625 565.93 12.80 553.13 Pass 739.94 739.63 725.00 722.21 1.10 0.71 71.11 286.11 7.625 569.85 13.23 556.62 Pass 764.83 764.45 750.00 746.48 1.13 0.75 70.58 285.58 7.625 574.24 13.66 560.58 Pass 789.56 789.09 775.00 770.64 1.16 0.78 70.04 285.04 7.625 579.06 14.09 564.98 Pass 814.42 813.85 800.00 794.69 1.17 0.82 69.48 284.48 7.625 584.33 14.49 569.83 Pass 839.29 838.61 825.00 818.61 1.18 0.85 68.90 283.90 7.625 590.01 14.88 575.14 Pass 863.96 863.14 850.00 842.43 1.20 0.89 68.31 283.31 7.625 596.07 15.25 580.82 Pass 888.46 887.48 875.00 866.18 1.21 0.92 67.70 282.70 7.625 602.29 15.63 586.66 Pass 912.80 911.64 900.00 889.87 1.21 0.96 67.07 282.07 7.625 608.67 16.01 592.66 Pass 936.96 935.60 925.00 913.49 1.22 0.99 66.42 281.42 7.625 615.21 16.35 598.86 Pass 960.90 959.31 950.00 937.03 1.22 1.03 65.75 280.75 7.625 621.98 16.71 605.27 Pass .984.54 982.69 975.00 960.41 1.23 1.08 65.05 280.05 7.625 629.08 17.06 612.02 Pass 1007.87 1005.73 1000.00 983.64 1.23 1.12 64.31 279.31 7.625 636.52 17.41 619.11 Pass 1030.86 1028.42 1025.00 1006.70 1.24 1.17 63.56 278.56 7.625 644.33 17.77 626.56 Pass 1053.52 1050.75 1050.00 1029.59 1.25 1.22 62.78 277.78 7.625 652.51 18.13 634.38 Pass 1075.86 1072.72 1075.00 1052.32 1.26 1.28 62.00 277.00 7.625 661.11 18.49 642.62 Pass EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 of•4~1 .. ~ =3r°~.1 ...., ..,_. ;'iais (~~ccs~~t~2rs ~~~=:;h Sta#e Cabins ~I~te~r~l ~1 ~ __.~ Alaska DNR Case ~um~mary File Type ADL File Number: 380110^ ~ PrintableCa..se File_Summ..ary See Township, Range, Section and Acreage? ~+ Yes No New Search ~ LAS !Menu I Case Abstract I Case Detail I Land Abstract -. , 1-~rlc: aUL 3{01 lfl ''~' Search for Status Pla~_;.It~clates ~ ul I Oi 1 ~i~0(Iti Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 9661 2 Case Tv~e: rz~ OIL & GAS LEASE COMP DNR Unit. 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 3 5 ISSUED Status Date: O 1 /29/ ] 993 Total ACr~S': 2437.000 Date Initiated: 08/25/1992 Office of Primary Res~onsibiliry: DOG DIV OIL AND GAS Last Ti•crnsactior~ Date: 03/18/2005 Case SubtZ~he: ~ NORTH SLOPE Last Transaction: PAXN 1 i'ARTICiPATTNG AREA EXPANDED Meridian: l~ T<~„i~~~{r~~?: UI~N Range: 011E .Srriiot~: O> SectionAc~°t~s: 640 ~ca~:.,~ Plats Mrri~laczn: U 7~nrn5~lri/~: (1J~N Range: O1lE S'c~c~ll~ur: f)(, ti"r~~lrr,~r l~~r~~~~: ~„ M~~rrrliun: l~ l~~ticn~hr/~.~ OI'N l~cnl~rr~ UI1L S'~~clrun: U Sectionllcrc~~: BYO ~tl~~ricliun_~ U l nli~i.~~hi~>: Ol 'N Range: O1 l E 5~~1(Ot1_ 08 Section Aerrc: ~i~0 Legal Description 08-2~-1992 **SALE NOTICE LEGAL DESCRIPTION** TRACT ~ ~-110 T. MN., R. 11 E., UM1~1T MF_RIDIAN, ALASKA SECTION ~, UNSURVEYED, ALL, «0 ACRES; SEC'MON 6, UNSURVEYED, ALL. ~ ?'ACRES'; SECT ION ?, UNSURVEYED. A/ L, X80 ACIZES,~ SFC'MON S, UN.SUR~'EY"CD, .4LL, 6~0 f]CRES. http://www. dnr. state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=3 8011... 10/ 15/2008 C i TRANSMITTAL LETTER CHECKLIST WELL NAME /t/fj~~S - .Sl/ PTD# ~o~/s9 Deveiopment~ _ Service Exploratory _ Sh'atigraphic Test __.__Non-Conventional Weil FIELD: _ ~~GiYE ~i~YT ~ ~h' POOL: L~GNL/ • U h~c 1 c Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits API number well in permit No. .API No. 50- are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE in accordance with 20 AAC 25.005(f), all records, lead and logs acquired for the pilot Note must be clearly differentiated in both well name ( PI.1) and AP[ number (50- - _.~ from records, data and [ogs acquired for well SPACING The permit is approved subject to felt compliance with 20 AAC EXCEPTION 25.055. Approve[ to perforate and roduce /infect is contfngept upon issuance of a conservation order approving a spacing exception . assumes the liability of any puotest to the spacing exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the 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 throu tar et canes. Noa-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed !or foams of welp until after tComnanv Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Com, nanY Name) must contact the Commission to obtain advance approve! of such water well testin g ro Rev: 1/112008 WELL PERMIT CHECKLIST' Field & Pool MILNE POINT, UGNU UNDEFINE OIL - 525160 Weli Name: MILNE PT UNITUGNU S-41 Program DEV Well bore seg ^ PTD#:2D81590 Company BP EXPLORATION (ALASKA) INC Initial ClassiType DEV I PEND GeoArea 890 Unit 11328 OnlOff Shore 2n Annular Disposal Administration 1 Pe[mitft;eatkached---- - -- --- - -- - - ------ - NA ------ - - ---------------- - - --- ------ --- -- 2 Lease number appropriate--- ---- - -- - --- -- Yes - --- --- - -- _ - - ------- -- - -- --- --- 3 Uniquewellrtameandnumbe[ --- - - -- -- - -- --- - Yes- ----- - - --- ---------- 4 Welilocatedin-a-defined-pool. ---- - -- - ----------- Yes_ -- -- -- -- - -- -- --- -- - --- - - 5 Well locatedpropard[slancefromdriliingu~it_boundary----------------------- Yes_ -------.---------------------------------------------------------------- 6 Well locatedp[operdiskancef[omQtherY~eils__-_______________________ Yes_ _-__.______-__-___--__--___-_ 7 Sufficient acreage available indliilingunit-------------------------------- Yes- -----256t)acres.__--__--__________________--__---.________.. __--- 8 If deviated, is wellbQre platincluded - - - - - - - - - - - - - - - Yes ----------------------- - - - - - - - - - - - - - - - - - - - 9 Ope[atot only affected party- - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - 10 Ope[atotbas_appropriakebondinforce-------------------------------- Yes- ------BlanketBond#61$4193.----------------------------------------.----------- ~ 11 Pe[mitc~anbeissuedwitboukconsflrYatignarder---------------------------- Yes- -----.-.--.--------------------------------------.----------------------- Appr Date 12 PetmitcaDbeissuedwkhoukadmin~tr_akive_approYal------------------------- Yes. ------------------------------------.---------------------.-------------- ACS 1011512008 13 Canper[nitbQappr4vedbefOrelS-day_v~ait------------------------------- Yes- ----.-.--------------------------------------._------------------------- 14 Weil located within area and strata authorized by-Injection Order#(putl9#in-comments)_(For _NA__ _______________-_______-______-__--_______-__--__.____-_.___---___-__ 15 Allwegswithin1l4_miie_a[ea.ofreviewjdentified(Fo[serviceweUDnly)______________ NA-- -_-__--__-__________________-__--__- 16 Pre-producedinjec~oeduration_ofpreproductionlessthan3months-(Forservicewellonly)-- NA_ __________________._______________-_______-__-____.____-______-- 17 tdonconven,gas_cgnforms to AS31,05:03Q(t.1.A),U,2.A•p) - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conducto[str-ing_Rrovided- -- - ------ - -- -- -- - --- Yes- - -- - -- --- ---- --------- -- ----- --------------- 19 SurfacecesingproteetsallknowrtUSDWs____.___----.__-_--_---__ NA__ ------Allaquifersexempted, 40CFR_147.tQ2(b)(3).__-__--_________________________ ___ 20 CMT-voiadequaketQCi[culake_onconducto[&surfcsg----------------------- Yes- --_-------------------------------------------------------------------- 21 CMT-vol adequate to tie•in longskrirrg ko surf csg - - - - - - - - - - - - - - N0- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT-wilJcover all known_ptoductivebQrizons_______________-.-----____-- Yes. .-----------------------------------------.------------------.--_ --- 23 Casing designs adequate fo[C,TB&_Re[maf[osi-------------------------- Yes- -------------------------------------------------------------.------- 24 Adequate-tankage-or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ . _ Rig equipped with steel pits, No reserve pit planned._ Ali waste_ to ;>;pproved disposal well(s), _ - _ _ - _ _ _ _ _ _ _ _ 25 If_a_re-drill,has_a10r403forabandonmentheen aRP-roved.------------------- ~A-- ------------------------------------------------------------------------ 26 Adequate welibore seperationp[op9sed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed, Traveling cylinder path calculated, Gyros possible in surface_hole: _ - _ _ _ _ - _ - _ 27 If dive[ter-required, does ii meet regulations___-__-___--________________ Yes. ..__------_-----------_---_-------_--__-_--------------------------- Appr Date 28 Dulling fluid program schemaiic_$ equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ _ _ _ Maximum expected fomtation pressure 8,5-EMW_ MV11 planned up to 9.4-ppg._ - - - - - - - - - - _ - - - _ - - _ - - - TEM 10115!2008 29 BOPI=s,-do theymeeiregulati9n ------- - ---- ------- Yes -- -- -- -- -- -- -- - - --- - --- -------- 30 9OPt_.press rating appropriate; test to_(put psig incomments)- _ _ _ - - _ _ _ _ . _ . Yes _ _ _ _ _ _ _ MA$P calculated at 130$psi, 3500_psi-BOP testplanned- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke_manlfoldcompiieswlAPLRP-53 (May 84) - -- - ------ Y~ -- ------------------ -- -- - --- - - --- ----- 32 Workwilioccurwikhoutoperatiortshutdown__---____-__--________---- Yes- ----------------------------------------------------------------.--_-- 33 Is presence °f H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ - _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ - - No_ . _ _ _ _ H2$ is not-repoCted in Ugnu. _Rig equipped wikh sensors_andalarms, - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical_conditionoiwflllsWithinAORyarified(FO[serviceweilonN)------------- NA-- --------------------_--------------------.---------------------------_ Geology 35 Pe[mitean be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ - _ _ Formation is_known to have H2S_present_ Max l,eyel teco[ded is 2ppm.- - _ _ - - _ _ _ _ _ _ - _ _ - _ _ _ _ _ _ _ _ - _ 36 Dafa_presentedonpoteniialpverpressurezones__--_.-__---__----_______ _hlA- -------------------------------------------.----------------------- Appr Date 137 Seismic analysis of shallow gas zones_-__---------------------------- NA_ -______--_------------.--- -------____-- ------------- - ------------- ACS 1011512008 38 Seabed-conditionsunley_(if of(-shore)___________________--__--___._-_ _h!A__ __ 39 Contactnamelphoneforweekly_progressreports[eXploratoryonly]________--____ Yes _____PaulHanson-564.4195-------------------------------_.-_-_____--___.____ Geologic Commissioner: Date: Engineering Date Public Date mmission r: Commissioner Co r~ f l.J%~ ~` J2v1 c~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special ef~ori has been made to chronologically organize this category of information. R Y MPS-41.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 29 16:56:39 2009 Reel Header Service name .............LISTPE Date . ...................09/01/29 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................09/01/29 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS scientific Technical services scientific Technical services MPS-41 500292340100 BP Exploration (Alaska), Inc. Sperry Sun 29-JAN-09 MWD RUN 1 MWD RUN 3 Mw-000615003 MW-000615003 J. GRANADOS A. MUNRO G. BURLEY G. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 12 12N l0E 3224 518 .00 71.53 37.79 Page 1 ~v~ /S°i 1~5`3fl 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MPS-41.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 106.0 8.500 9.625 4140.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGERMUELLER TUBE DETECTORS, PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYANMICS SENSOR (DDS), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). DATA FROM 1041' MD, 1038' TVD TO 1481' MD, 1463' TVD WAS ACQUIRED MEASURED AFTER DRILLING (MAD) PASS. ALL DATA PRESENTED MERGED WITH MWD DATA FROM RUN 1. INTERMITTENT GAPS IN DENSITY DATA OCCUR OVER RUN 1 INTERVAL. 4. DRILLED OUT OF 9 5/8" CASING SHOE WITHOUT MWD TOOLS TO 4265' MD, 3545' TVD. NO RATE OF PENETRATION DATA PRESENTED. 5. MWD RUN 2 - NO FOOTAGE DRILLED. 6. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGERMUELLER TUBE DETECTORS, PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYANMICS SENSOR (DDS), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), MAGNETIC RESONANCE (MRIL-WD), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MRIL-WD T2 DATA ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED FOLLOWING DRILLING. ALL DATA PRESENTED MERGED WITH MWD DATA FROM RUN 3. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN ON 19 NOVEMBER 2008. THESE DIGITAL DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 12 JANUARY 2009, PER ERIC HULM (BP). LOG HEADER AND ANNOTATION DATA RETAIN ORIGINAL DEPTH REFERENCES. 8. MWD RUNS 1-3 REPRESENT WELL MPS-41 WITH API#: 50-029-23401-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5081'MD, 4075'TVD. Page 2 i ~ MPS-41.tapx SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). CTFA = AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = AVERAGE OF NEAR DETECTOR'S COUNT RATE. T1PT = TOTAL MRIL POROSITY T1 LOGGING MODE (TIPTOT). T1PX = IRREDUCIBLE MRIL POROSITY FROM T1 LOGGING MODE (TIPIRRMX). T1PM = MICRO (CLAY-BOUND) MRIL POROSITY FROM T1 LOGGING (TIPMIC). T1LM = LOG MEAN OF T1 RELAXATION TIME(T1LM). T1KC = T1 PERMEABILITY FROM COATES ALGORITHM(TIKCOAT). T2PT = TOTAL MRIL POROSITY T2 LOGGING MODE (T2PTOT). T2PX = IRREDUCIBLE MRIL POROSITY FROM T2 LOGGING MODE (T2PIRRMX). T2PM = MICRO (CLAY-BOUND) MRIL POROSITY FROM T2 LOGGING (T2PMIC). T2LM = LOG MEAN OF T2 RELAXATION TIME(T2LM). T2KC = T2 PERMEABILITY FROM COATES ALGORITHM(T2KCOAT). MRIL-WD IRREDUCIBLE POROSITY CUTOFF: 60 MS T1 MODE / 33MS T2 MODE MRIL-WD MICO POROSITY CUTOFF 6 MS T1 MODE / 3MS T2 MODE SPECTRAL BVI COEFFICIENT: 0.031 T1 MODE / 0.062 T2 MODE COATES ~~C" COEFFICIENT = 10 T2 TE SPACINGS: TA - 4.8 MS TB - 1.2 MS @ TW = 8000 MS PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE : 8. 5 ~~ MUD WEIGHT: 9.2 - 9.4 PPG MUD SALINITY: 350-14,000 PPM CHLORIDES FORMATION WATER SALINITY: 21,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... Page 3 MPS-41.tapx version Number. ........1.0.0 Date of Generati on.......09/01/29 Maximum Physical Record..65535 File Type. ... .........LO Previous File Na me.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted an d clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FCNT 213.0 4992.0 NPHI 213.0 4992.0 NCNT 213.0 4992.0 DRHO 229.5 5006.0 RHOB 229.5 5006.0 PEF 229.5 5006.0 RPS 255.0 5043.0 RPM 255.0 5043.0 RPD 255.0 5043.0 FET 255.0 5043.0 GR 263.0 5029.0 ROP 318.5 5081.0 CALA 4131.5 4995.5 T2PT 4142.0 4171.5 T2PM 4142.0 4171.5 T2KC 4142.0 4171.5 T2LM 4142.0 4171.5 T2PI 4142.0 4171.5 T1PM 4172.0 4969.5 T1LM 4172.0 4969.5 T1KC 4172.0 4969.5 T1PI 4172.0 4969.5 T1PT 4172.0 4969.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3871.0 3867.5 3905.5 3901.0 3925.0 3920.5 3929.0 3925.5 3935.0 3930.0 3940.0 3937.0 3946.5 3943.5 3964.5 3958.0 3967.0 3963.0 3978.5 3974.0 3984.0 3982.0 3995.5 3990.5 4022.5 4016.0 4053.0 4047.5 4140.5 4139.5 4182.0 4182.0 4230.5 4230.0 4434.0 4432.5 4665.0 4662.0 Page 4 4845.0 4959.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MwD 3 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 FCNT MWD CP30 4 1 68 8 3 NCNT MWD CP30 4 1 68 12 4 RHOB MWD G/CC 4 1 68 16 5 DRHO MWD G/CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 T1KC MWD MD 4 1 68 52 14 T1LM MWD MS 4 1 68 56 15 T1PI MWD PU 4 1 68 60 16 T1PM MWD PU 4 1 68 64 17 T1PT MWD PU 4 1 68 68 18 T2KC MWD MD 4 1 68 72 19 T2LM MwD MS 4 1 68 76 20 T2Pi MWD Pu 4 1 68 80 21 T2PM MWD PU 4 1 68 84 22 T2PT MWD Pu 4 1 68 88 23 NPHI MWD PU 4 1 68 92 24 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 213 5081 2647 9737 213 5081 CALA MWD IN 8.37 10.66 8.97783 1729 4131.5 4995.5 FCNT MWD CP30 514.1 4064.45 880.08 9380 213 4992 NCNT MWD CP30 128714 253550 152578 9390 213 4992 RHOB MwD G/cc 0.519 2.748 2.05298 9219 229.5 5006 DRHO MWD G/CC -4.257 0.49 0.0457057 9219 229.5 5006 RPD MWD OHMM 0.16 2000 190.085 9490 255 5043 RPM MWD OHMM 0.18 2000 235.683 9490 255 5043 Page 5 MPS-41.tapx 4843.0 4956.5 MERGE TOP MERGE BASE 315.0 4147.5 4265.0 5081.0 ~' ~ MPS-41.tapx RPS MWD OHMM 0.24 2000 218.682 9490 255 5043 FET MWD HR 0.08 95.79 6.60728 9490 255 5043 GR MwD API 15.41 124.1 68.6596 9533 263 5029 PEF MwD B/E -9.53 26.23 2.16478 9232 229.5 5006 ROP MWD FPH 0.25 1003.59 162.541 9293 318.5 5081 T1KC MWD MD 0 275.59 7.49418 1596 4172 4969.5 T1LM MWD MS 4.98 104.8 18.4642 1596 4172 4969.5 T1PI MwD Pu 5.84 30.61 22.1538 1596 4172 4969.5 T1PM MwD PU 0.62 15.03 7.90229 1596 4172 4969.5 T1PT MWD Pu 6.49 36.34 27.433 1596 4172 4969.5 T2KC MWD MD 0.05 1.06 0.330333 60 4142 4171.5 T2LM MwD MS 3.81 5.55 4.83133 60 4142 4171.5 T2PI MWD PU 22.27 32.64 26.6595 60 4142 4171.5 T2PM MwD PU 10.1 12.98 11.3665 60 4142 4171.5 T2PT MWD PU 24.89 33.47 28.393 60 4142 4171.5 NPHI MWD Pu 13.22 106.84 46.1766 9390 213 4992 First Reading For Entire File..........213 Last Reading For Entire File...........5081 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/29 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.......09/01/29 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 TNPS 209.5 4041.0 CTNA 209.5 4041.0 CTFA 209.5 4041.0 SNP2 226.0 4051.0 SC02 226.0 4051.0 SBD2 226.0 4051.0 SEMP 251.5 4084.0 SEDP 251.5 4084.0 SESP 251.5 4084.0 Page 6 ~ ~ MPS-41.tapx SEXP 251.5 4084.0 SFXE 251.5 4084.0 SGRC 259.5 4091.5 SROP 315.0 4147.5 LOG HEADER DATA DATE LOGGED: 11-NOV-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4147.0 TOP LOG INTERVAL (FT): 315.0 BOTTOM LOG INTERVAL (FT): 4147.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 58.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 134745 EWR4 EWR Phase-4 230192 CTN Comp Thermal Neutron 158417 ALD Azimuthal Litho Dens 11005089 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 106.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 148.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 350 FLUID LO55 (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 6.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.218 81.5 MUD FILTRATE AT MT: 4.500 70.0 MUD CAKE AT MT: 2.800 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 .lIN Page 7 MPS-41.tapx Max frames per record .............undef ined Absent value ... ...................-999 Depth units. . . .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Co de offset Channel DEPT FT 4 1 68 0 1 FONT MWDO10 CP30 4 1 68 4 2 NCNT MWDO10 CP30 4 1 68 8 3 RHOB MWDO10 G/CC 4 1 68 12 4 DRHO MWDO10 G/CC 4 1 68 16 5 RPD MwD010 OHMM 4 1 68 20 6 RPM MwD010 OHMM 4 1 68 24 7 RPS MWDO10 OHMM 4 1 68 28 8 RPX MwD010 OHMM 4 1 68 32 9 FET MWDO10 HR 4 1 68 36 10 GR MWDO10 API 4 1 68 40 11 PEF MWDO10 B/E 4 1 68 44 12 RoP MwD010 FPH 4 1 68 48 13 NPHI MwD010 Pu 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 209.5 4147.5 2178.5 7877 209.5 4147.5 FCNT MWDO10 CP30 514.1 2426.88 850.5 7664 209.5 4041 NCNT MWDO10 CP30 128714 213272 148347 7664 209.5 4041 RHOB MWD010 G/CC 1.126 2.748 2.02452 6548 226 4051 DRHO MWDO10 G/CC -0.322 0.49 0.0687831 6548 226 4051 RPD MWDO10 OHMM 0.16 2000 229.925 7102 251.5 4084 RPM MwD010 OHMM 0.18 2000 298.185 7102 251.5 4084 RPS MWDO10 OHMM 0.24 2000 276.68 7102 251.5 4084 RPX MWDO10 OHMM 0.33 1728.67 34.6065 6523 251.5 4084 FET MWDO10 HR 0.08 58.14 3.30522 7102 251.5 4084 GR MWDO10 API 15.41 121.96 68.3168 7104 259.5 4091.5 PEF MWDO10 B/E -9.53 26.23 2.12762 6582 226 4051 ROP MWDO10 FPH 0.25 1003.59 181.44 7666 315 4147.5 NPHI MWDO10 PU 18.23 106.84 47.347 7098 209.5 4041 First Reading For Entire File..........209.5 Last Reading For Entire File...........4147.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/29 Maximum Physical Record..65535 File Type ................L0 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.......09/01/29 Page 8 ~ • MPS-41.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 4100.0 5026.5 SEDP 4130.0 5040.5 SBD2 4130.0 5003.5 CTNA 4130.0 4989.5 SCO2 4130.0 5003.5 ACAL 4130.0 4993.0 CTFA 4130.0 4989.5 SEMP 4130.0 5040.5 TNPS 4130.0 4989.5 SESP 4130.0 5040.5 SNP2 4130.0 5003.5 SEXP 4130.0 5040.5 SFXE 4130.0 5040.5 T2PI 4141.0 4171.5 T2PM 4141.0 4171.5 T2KC 4141.0 4171.5 T2LM 4141.0 4171.5 T2PT 4141.0 4171.5 T1PI 4172.0 4967.0 T1MP 4172.0 4967.0 T1LM 4172.0 4967.0 T1KC 4172.0 4967.0 T1PT 4172.0 4967.0 ROP 4265.0 5081.0 $ LOG HEADER DATA DATE LOGGED: 15-NOV-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5081.0 TOP LOG INTERVAL (FT): 4265.0 BOTTOM LOG INTERVAL (FT): 5081.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.4 MAXIMUM ANGLE: 57.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 242561 EWR4 EWR Phase-4 228272 CTN Comp Thermal Neutron 244601 ALD Azimuthal Litho Dens 224808 BOREHOLE AND CASING DATA Page 9 MPS-41.tapx OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4140.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 65.0 MUD PH: $.2 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .250 51.0 MUD AT MAX CIRCULATING TERMPERATURE: .139 97.0 MUD FILTRATE AT MT: .310 51.0 MUD CAKE AT MT: .340 51.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code offset channel DEPT FT 4 1 CALA MWD030 IN 4 1 FCNT MWD030 CP30 4 1 NCNT MWD030 CP30 4 1 RHOB MWD030 G/CC 4 1 DRHO MWD030 G/CC 4 1 RPD MWD030 OHMM 4 1 RPM MWD030 OHMM 4 1 RPS MWD030 OHMM 4 1 RPX MWD030 OHMM 4 1 FET MWD030 HR 4 1 GR MWD030 API 4 1 PEF MWD030 B/E 4 1 ROP MWD030 FPH 4 1 T1KC MWD030 MD 4 1 T1LM MWD030 MS 4 1 T1PI MWD030 PU 4 1 T1MP MWD030 PU 4 1 T1PT MWD030 PU 4 1 T2KC MWD030 MD 4 1 T2LM MWD030 MS 4 1 T2PI MWD030 PU 4 1 T2PM MWD030 PU 4 1 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Page 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 56 15 60 16 64 17 68 18 72 19 76 20 80 21 84 22 88 23 10 MPS-41.tapx T2PT MWD030 PU 4 1 68 92 24 NPHI MWD030 PU 4 1 68 96 25 First Last Name Service Unit Min Mdx Mean Nsam Reading Reading DEPT FT 4100 5081 4590.5 1963 4100 5081 CALA MWD030 IN 8.37 10.66 8.97797 1727 4130 4993 FCNT MWD030 CP30 715.61 4064.45 1010.61 1710 .4130 4989.5 NCNT MWD030 CP30 149061 253550 171308 1720 4130 4989.5 RHOB MWD030 G/CC 0.682 2.663 2.14856 1748 4130 5003.5 DRHO MWD030 G/CC -4.257 0.142 -0.0426991 1748 4130 5003.5 RPD MWD030 OHMM 1.9 2000 75.364 1822 4130 5040.5 RPM MWD030 OHMM 0.76 2000 49.2102 1822 4130 5040.5 RPS MWD030 OHMM 0.49 2000 51.0895 1822 4130 5040.5 RPX MWD030 OHMM 0.31 1640.53 34.0563 1822 4130 5040.5 FET MwD030 HR 0.34 95.79 6.01873 1822 4130 5040.5 GR MwD030 API 25.73 115.44 69.0614 1854 4100 5026.5 PEF MwD030 B/E 1.59 12.91 2.30003 1748 4130 5003.5 ROP MWD030 FPH 0.25 184.45 73.2859 1633 4265 5081 T1KC MwD030 MD 0 275.59 7.51978 1591 4172 4967 T1LM MWD030 MS 4.98 104.8 18.4826 1591 4172 4967 T1PI MwD030 PU 5.84 30.61 22.1572 1591 4172 4967 T1MP MwD030 PU 0.62 15.03 7.90999 1591 4172 4967 T1PT MWD030 PU 6.49 36.34 27.4484 1591 4172 4967 T2KC MWD030 MD 0.05 1.06 0.330161 62 4141 4171.5 T2LM MWD030 MS 3.81 5.55 4.81564 62 4141 4171.5 T2PI MWD030 PU 22.27 32.64 26.6305 62 4141 4171.5 T2PM MWD030 PU 10.1 12.98 11.3935 62 4141 4171.5 T2PT MWD030 PU 24.89 33.47 28.3639 62 4141 4171.5 NPHI MWD030 PU 13.22 58.61 39.985 1720 4130 4989.5 First Reading For Entire File..........4100 Last Reading For Entire File...........5081 File Trailer Service name... .......STSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/01/29 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE scientific Technical Services Page 11 Date . ...................09/01/29 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EoF Physical EOF End Of LIS File MPS-41.tapx writing Library. Page 12 • scientific Technical services