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Home My WebLink About208-165• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspec/tion of the file. ^~~ ~` - ~ /~ Sri Well History File Identifier Organizing (done) RE AN C//o``lor Items: LyGreyscale Items: y^ Poor Quality Originals: ~,.6,a~ ~umiimiiuii DIGI AL DATA Diskettes, No. 1 ^ Other, No/Type: o a„~~~~~a iiummuuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q /s/ Pro'ect Proofin II I II'I II I I III I (III J g BY: Maria Date: /s/ Scannin Pre aration ~_ x 30 = .~ + ~_ =TOTAL PAGES g p (Count does not include cover sheet) ~M BY: Maria Date:. ~/A /~~ /s/ ~ ~ 1~ Production Scanning Stage 1 BY: Stage 1 BY: Page Count from Scanned File: ~~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: ~/~ ~Q /s/ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /sui nsuuun i~ni 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 111111 III II'I III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 7/8/2010 Permit to Drill 2081650 Well Name/No. MILNE PT UNIT KR C-43L1 Operator BP EXPLORATION (ALASKA INC API No. 50-029-23200-60-00 MD 15501 TVD 7353 Completion Date 2/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ./'~~ Mud Log No Samples No Directional Survey DATA INFORMATIDN Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / .y rv~eairrmt nu~~~~r name acme meaia rvo start stop cn rzecervea comments pt LIS Verification 13090 15501 Open 3/23/2009 LIS Veri, GR, ROP RAD RAS, RPD, RPS ED C Lis 17758" Induction/Resistivity 13090 15501 Open 3/23/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS g Induction/Resistivity 25 Col 13463 15501 Open 3/23/2009 MD MPR, GR 5~lan-2009 ~ og Induction/Resistivity 5 Col 13463 15501 Open 3/23/2009 TVD MPR, GR 5-Jan-2009 Lo Gamma Ray 25 Col 13463 15501 Open 3/23/2009 MD GR 5-Jan-2009 D D Asc Directional Survey 13379 15501 Open 1/30/2009 I // ~Rpt Directional Survey 13379 15501 Open 1/30/2009 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y I~ Daily History Received? ~/ N Chips Received? YTFf-' Formation Tops ~ N Analysis Y'7~1 Received? •I ~I DATA SUBMITTAL COMPLIANCE REPORT 7/8/2010 Permit to Drill 2081650 Well Name/No. MILNE PT UNIT KR C-43L1 Operator BP EXPLORATION (ALASKI~ INC MD 15501 TVD 7353 Completion Date 2/10/2009 Completion Status 1-OIL Current Status 1-OIL Comments: Compliance Reviewed By: API No. 50-029-23200-60-00 UIC N Date: t ~_J Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, April 01, 2009 2:37 PM To: Maunder, Thomas E (DOA) Subject: RE: MPC-43L1 (208-165) and MPC-43L1-01 (208-166) Hi Tom, This was a particularly fun one... (Doyon 14 Originally Drilled 03/18/04 - 04/10/04) Nabors 3S Prep'd the well 12/10/08 - 12/24/08 Nordic #2 CTD Drilled 12/27/08 - 01 /14/09 Nabors 3S moved back on to run completion 02/03/09 - 02/10/09 Thanks! Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 01, 2009 2:33 PM To: Hubble, Terrie L Subject: MPC-43L1 (208-165) and MPC-43L1-01 (208-166) Terrie, I am belatedly reviewing the 407s for these new segments. The rig listed on the drilling operations reports is Doyon 14. These penetrations were coil drilled and according to the pre- post-rig work summary you supplied, Nordic 2 conducted the work. Please confirm this and I will make the correction by hand. Thanks in advance, Tom Maunder, PE AOGCC 4/1 /2009 L J MPC-43, Well History (Pre & Post CTD Sidetrack) Date Summary 10/12/08 T/I/0=200/300/0 Freeze Protect - Pump tbg w/5 bbls neat methanol & 15 bbls diesel. Freeze protect flow line w/4 bbls 60/40 methanol, 6 bbls diesel & 4 bbls 60/40 methanol. Shut laterals & bleed to 0 psi. IA/OA & master open. Wing, swab & ssv closed. Tag well & notify operator. Final WHP's=200/280/0 10/17/08 T/I/0=100/330/0. MIT OA to 2000 psi. Failed. Lost 400 psi in 15 minutes. Establish LLRT .9 bpm @ 1600 psi for 5 bbls. Monitor OA pressure. Bleed OA pressure down to 0 psi. FWHP = 100/330/0. 11/02/08 T/I/O=SSV/400/120, Temp=S1. PPPOT-T-T (PASS), pre CTD. PPPOT-T: Stung into test port (200 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1"). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi 11/20/08 MADE 15 MIN GRADIENT STOP @ 12,148' SLM (12,145' MD). MADE 3 HR SBHP STOP @ 12,607' SLM (12,648' MD). PULLED 1" DGLV FROM ST#1 @ 12,482' MD. LEFT POCKET EMPTY PULLED 1" DPSOV FROM ST#2 @ 139' MD. SET 1"DGLV IN ST#2 @ 139' MD. WELL SUPPORT ~T BPV. WELL LEFT S/I. PAD OP NOTIFIED. JOB COMPLETED. ~We ... Nordic #2 _ Ftxg~ ~iup +t~%~dri0 2 Mulfit~teral;ry~~~s (12l `~, 01/14/09 T/I/0= 0/0/0 (Freeze Protect Post RWO). Pumped 15 bbls Diesel down tubing. FWHP = 0/0/0 Master, SSV, IA, OA, Wing ,and Swab closed. 01/15/09 SPOT UP EQUIPMENT R/U SURFACE EQUIPMENT TEST WIRE REPACK STUFFING BOX. 01/16/09 MADE FRIST @ 12,737' SLM FOR ONE HR TIME 06:10 TO 07:10. MADE SECOND STOP @ 13,300 SLM FOR 3 HRS TIME 07:20 TO 10:20. RAN 2.5" MAGNET DOWN TO 3500 SLM SEVERAL TIMES, AND 3.5" MAGNET TO 7500'. RECOVERED TOTAL OF 3 CUPS METAL SHAVINGS. LAY DOWN EQUIPMENT FOR HIGH WIND 40+ MPH. 01/17/09 RAN 3.50" MAGNET TO 12730' SLM MULTIPLE TIMES. RECOVERED TOTAL OF 2.5 r'i iPc RAN 3.80" MAGNET TO 12730' SLM SAT DOWN @ 2110 MD. RECOVERED 1/4 OF CUP. RUNNING 4.5 BRUSH W/ KJ, 3.5 MAGNET. 01/18/09 RAN 4.5 BRUSH, 3.5 MAGNET TO 12,705 SLM. WORK BRUSH FOR 15 MIN. RECOVERED TOTAL OF 1/2 CUP OF SHAVINGS IN 3 RUNS. RAN 4.5" BLB W/ 3.80" G. RING TO 12705' MD. WORK BRUSH. SET 3.813" X-LOCK, PX-PLUG BODY (3.805" OD), (4) 3/16" EQ PORTS. LIH = 26" SET @ 12705 MD. SET PRONG @ 12711 SLM. 01/19/09 T/I/0=150/0/0 (Assist Slickline. MIT- Tubing to 2000 psi.) PASSED. Pumped 3.7 bbls Diesel down tubing to bring pressure up to 2000 psi. Lost 60 psi in first 15 minutes. Lost 20 psi in second 15 minutes. Performed 2nd test with additional 0.1 bbls diesel to bring pressure from 1920 psi. to 2000 psi. Lost 0 psi in thirty minutes. FWHP = 150/0/0 Swab, SSV, and Wing closed. Master, IA, and OA open. 01/19/09 SET PX PLUG @ 12705 MD. PERFORMED MIT-T TO 2000 PSI -GOOD TEST. R/D. 01/20/09 T/I/O=0/0/0 (CMIT T x IA to 2000 psi.). Pumped .6 bbls Diesel down tubing to bring pressure up to 1400 psi. No change on IA. Bleed tubing down to 0 psi. Pumped 2.2 bbls into IA to bring pressure up to 2000 psi. Tubing pressure came up to 280 psi. Bleed pressure down to 0 psi on IA and tubing. FWHP = 0/0/0. Page 1 of 2 MPC-43, Well History (Pre & Post CTD Sidetrack) Page 2 of 2 w • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPC-43L1 &MPC-43L1-Ol Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2368042 -~° Sent by: Catrina Guid - _~, u. Date: 03/19/ I s ~r~~? .~ ~ --~~~ Received by: ~- ~ Date: ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~,/~ r~~5 ~ Baker Hughes INTEQ 7260 Homer Drive ~~S ~~~ 1 ~~ B ~~ Anchorage, Alaska 99518 Direct: (907) 267-6612 [(~ITEQ FAX: (907) 267-6623 • ~ // ~® BAKER .. HY!sNES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY IXYLURA'1'IUN (ALASKA) INC CUUN fY NUK'IH SLUYE BURUUGH WELL NAME MPC-43LI-01 WELL NAME MPC-43LI STATE ALASKA FIELD MILNE POINT UNIT DATE 3/19/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2368042 Copies of Copies Digital Copies of Copies Digital Each Log 2 of Film Data Company BP EXPLORATION (ALASKAI INC Each Log i of Film Data Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 I Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address ~vs ~~~ Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston. Texas 77073 This Distribution List Completed Bv: i ~~ ~~ ~ t ~~ - Page i of I STATE OF ALASKA ~`~_~~~~ ALAS IL AND GAS CONSERVATION CO SION .3- ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAC? ~ ~ 7(~1~9 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ads: `°' ~~ ®Devel~l~i'~41a~® Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/10/2009 12. Permit to Drill Number 208-165 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~~ 12/3tg20 Q 13. API Number 50-029-23200-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/4/2009 ~ 14. Well Name and Number: MPC-43L1. 1344 FSL, 2290 FEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 548' FSL, 544' FEL, SEC. 33, T14N, R10E, UM 8. KB (ft above MSL): 51.1' Ground (ft MSL): 16.4' 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 1247' FSL, 2256' FEL, SEC. 33, T14N, R10E, UM 9. Plug Back Depth (MD+TVD) 15501' 7353' Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558168 y- 6029627 Zone- ASP4 10. Total Depth (MD+TVD) 15501' 7353' 16. Property Designation: ADL 047434 & 355017 TPI: x- 554541 y- 6039361 Zone- ASP4 - 6040048 Zone- ASP4 Total Depth: x- 552823 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y 18. Directional Survey ®Yes ^ No bmit el r ni n rin a inf rm i n r 2 AAC 25.05 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 AA .25.071): MWD DIR, GR, RES L,//N4aH/G.~ l~ -5~60'~~ ~/ff.S-S~TY.6 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 2-7/ " 6.16# L-80 13695' 155 1' 7 3 ' 7 3' 4-1/4" Uncemented SI Liner 23. Open to production or inject ion? ®Yes ^ No 24. Tuewc RECORD If Yes, list each i (MD+TVD of To 8 Bottom; Pe nterval open rforation Size and Number): S¢E DEPTH SET MD PACKER SET MD p ~ 2-7/8" Slotted Section Note: 2-7/8", 6.5#, L-80 12715' None MD TVD MD TVD Well Branch Well Branch 13707 - 15469' 7338' - 7353' MPC-43L1 MPC-43L1 25. ACID, FRACTURE, CEMENT SDUEEZE, ETC. Departs from Is not Directly DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED Well Branch Accessible 43L1 01 MPC 1650' Freeze Protected w/ 22 Bbls of Diesel - , - PTD # 208-166, at 13692' MD ' (7338 TVD) 26. PRODUCTION TEST Date First Production: Reported on MPC-43L1-01 Method of Operation (Flowing, Gas Lift, etc.): See MPC-43L7-01 10-407 (Dated 03-05-09, PTD # 208-166) for Production & Test Data Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. Casing 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 Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. i None ~'~' _~ ~-, FDrm 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE ~ ,`, ,~ ry ~~n~ }~ G ., 7 'JU /J~~ ~~~ ~~ 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS ' NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk C1 13459' 7192' None Kuparuk A 13574' 7296' Kuparuk A3 13580' 7300' Kuparuk A2 13610' 7319' Kuparuk A2 (Invert) 13685' 7338' Kuparuk A2 (Revert) 13840' 7332' Kuparuk A2 (Invert) 14200' 7344' Kuparuk A2 (Revert) 14610' 7339' Formation at Total Depth (Name): Kuparuk A2 14610' 7339' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. n3//t% Si d V W gne Terrie Hubble Title Drilling Technologist Date MPC-43L1 208-185 Prepared ByName/Number. TenieHubble, 564-4628 Well Number P rmi N . / r Dulling Engineer: Greg Sarber, 564-4330 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND 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). IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 4~ Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE ~~i Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DeJ,Y.0Q11~j1Y ~~~~, ~ Rig Number: 14 Date From - To Hours Task ,Code ~I NPT Phase Description of Operations 12/25/2008 104:30 - 18:00 I 13.501 MOB N WAIT PRE 18:00 - 00:00 6.00 MOB N WAIT PRE 12/26/2008 00:00 - 19:00 19.00 MOB N WAIT PRE 19:00 - 19:45 0.75 MOB N WAIT PRE 19:45 - 20:00 0.25 MOB P PRE 20:00 - 00:00 4.00 MOB P PRE 12/27/2008 00:00 - 08:00 8.00 MOB N WAIT PRE 08:00 - 10:00 I 2.00 I MOB I P 10:00 - 18:00 8.001 RIGU P 18:00 - 18:30 0.50 RIGU P 18:30 - 19:40 1.17 RIGU P 19:40 - 20:00 0.33 RIGU P 20:00 - 00:00 4.00 RIGU P 12/28/2008 00:00 - 03:20 3.33 RIGU P 03:20 - 03:40 0.33 BOPSU~P 03:40 - 04:00 0.33 BOPSU P 04:00 - 14:00 I 10.001 BOPSUR P 14:00 - 15:50 1.831 RIGU I P 15:50 - 18:30 2.671 RIGU P 2$:30 - 22:20 0.83 BOPSUF~ P PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE W EXIT W EXIT W EXIT Move rig off of MPB-22 & move to the edge of the pad. Clean up around the well. Place heater in extended mouse hole to help thaw it out. Work on misc rig projects. Continue to work on misc rig projects. Loaded the 2 3/8 E coil and instated hard line. Continue to wait for MPC-43 prep work. Continue with misc projects and cleaning on rig. Prep rig for rig move. Warm up moving system. Move satelite camp to C pad. PJSM on rig move Move rig from MP-B pad to C-pad, trip distance of 5.5 miles. Rig is parked on side of C pad waiting on C-43 well prep work to be completed. Continue with misc. rig projects and cleaning. SLB is changing out injector dodge bearings. Spot T-mats & herculite liner. Jack up, spin tires & warm up moving system. PJSM regarding moving rig. Move rig from pad entrance & spot over well. Level rig. RU handy berm. ND tree cap. NU BOPE &MPD loo .Chain off BOP's. Bring on boiler water. Get stack measurements. Spot metal/food dumpsters. Spot office trailer. RU BOT coil track tools. RU cables to rig. SLB is C/O dodge bearings on the injector. Crew change, walk arounds, and PJSM. Finish berming up around cellar. Make snow pack around base of cellar. Lay out traction mats. NU choke line. PJSM on MU / NU of circulating loop. Reviewed hammer wrench policy. RU circulating loop Continue to NU MPD circulating loop. Fix leaking BOP Ram door seal. Shell test BOP's -Pass Start to RU to Pull BPV with MPU well support, Unable -Don't have appropriate cross overs to attach there lubricator to our lubricator. .Test BOPE &MPD equipment as per approved wellplan, 'AOGCC regs, and PTD #208-165. Recorded all data electronically and on AOGCC test form. Test witness waived by Jeff Jones, AOGCC. 2-3/8" x 3-1/2" VBR's failed -tear apart & rebuild. All passed to 250psi/3500psi. Blow down MPD loop. PJSM regarding pulling BPV. Hoist equipment to RF. Steam BPV lubricator & X-over. RU 20' extension, 7"x4" otis connection, BPV lubricator. Stab onto well. P.T. 500psi. Pull 4" 'H' style BPV. RD & LD lubricator & x-over. Hoist whipstock & setting tools to RF, MU & scribe same. Install three pip tags in WS. PU injector & MU stuffing box, hook up packoff hoses. Run stabbing winch cable & prep to ull coil acros Pull test grapple connection. Remove shipping bar. Pull coil across & stab into the injector. Fill coil Pressure test inner reel valve and packoff rnnteo: vzoizwa n:~o:ia wm MS BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 D~LLING INC. Rig Release: 4/10/2004 N Contractor Name: DOYO ,~ ~ Rig Name: ~~~'Y~r~l`I~r4 ~o~~c..~ Rig Number: 14 Date From - To Hours I Task Code NPT Phase Description of Operations 12/28/2008 22:20 - 22:30 0.17 RIGU P WEXIT PJSM for cutting coil 22:30 - 23:00 0.50 RIGU P WEXIT Cut coil, found Eline ~ 15 ft cut. 23:00 - 00:00 1.00 RIGU P WEXIT Make up SLB CTC, Pull test to 35K #'s, Pressure test to 3,500 psi. Unable to circulate coil is frozen.,' 12/29/2008 00:00 - 01:35 1.58 RIGU N SFAL WEXIT Cut 100 ft of frozen CT. Circulate, Install SLB CTC, and pull test to 35,000 #'s. Pressure test to 3,500 psi -Passed Install night cap and check well. No WHP 01:35 - 02:50 1.25 RIGU P WEXIT OC E line -greater than 2,000 M Ohms, and 45 Ohms MU BHI UOC and test -Pass. 02:50 - 03:00 0.17 RIGU P WEXIT PJSM on PU of Whipstock BHA, and filling the hole. 03:00 - 03:30 0.50 RIGU P WEXIT Line up to fill hole while pumping slack over bung hole. Upper swab was not open when checkin well earlier. en both swabs and had 77 si WHP. 03:30 - 05:50 2.33 KILL P WEXIT Bull head well, lead in with 5 bbls of McOH. Stab on injector and bull head ~ 5 bpm ~ 1330 psi WHP / 3050 psi CP. Max WHP was 1593 psi before turning the corner At 247 bbls flow check well -had flow and 10 psi WHP. Shut in and pump more. (~ 305 bbls Flow check. -well is breathing flow and pressure is falling off slowly. 05:50 - 07:30 1.67 KILL P WEXIT S/I well. Cir thru coil & thru kill line to prevent freeze up. C/O w/ day crew. PJSM regarding popping off. Pop off well & place injector over bung hole. Install night cap. Top off hole -full. Open well to closed choke, Opsi. Flow check - no flow. BD kill line. 07:30 - 08:00 0.50 WHIP P WEXIT PJSM regarding MU BHA. MU WS &BHI coil track tools. MU to coil. Stab onto well. Power up & test tools. Set counters. 08:00 - 12:00 4.00 WHIP P WEXIT Open EDC & circ min rate while RIH w/ WS ~ 60ft/min. Seeing every collar while RIH & 0.1 bpm losses. 12:00 - 12:40 0.67 WHIP P WEXIT Log down for tie-in from 13,140ft (-9ft corr. 12:40 - 12:45 0.08 WHIP P WEXIT Continue to RIH. 12:45 - 12:55 0.17 WHIP P WEXIT Log CCL for collar confirmation. PUH to set depth, 56k up wt. Lost 14bbls on trip in hole. 13:00 - 13:10 0.17 WHIP P WEXIT Close EDC & set TOWS high side at 13,460ft. Stack 2k -not ... moving. 13:10 - 17:00 3.83 WHIP P WEXIT POH. PJSM while POH regarding handling BHA. 17:00 - 19:05 2.08 WHIP P WEXIT Tag up. Flow check well - no flow. Pop off well. BD BHA w/ air & water. LD BHI coil track tools on catwalk & remove HOT. LD WS setting tool. MU window milling BHA. Whipstock setting tool looked norma goo . 19:05 - 21:55 2.83 STWHIP P WEXIT RIH with Window mill BHA. EDC closed and pump min rate. 21:55 - 22:05 0.17 STWHIP P WEXIT Log for GR tie in from 13,180 ft - 13,222 ft -8 ft correction. 22:05 - 00:00 1.92 STWHIP P WEXIT RIH, Tag ~ 13,463 ft -Dry. PU to 13,420 ft pumps on to 2.5 bpm ~ 2450 psi RIH Ta C~ 13 460 ft -Wet. CI~ ~ ~ Retag and get 250 psi increase in CP. Paint flag and start time_ millin o s er BOT hand, well plan, and BP RP. 12/30/2008 00:00 - 09:00 9.00 STWHIP P WEXIT Continue to time mill window per BOT hand, and BP's RP. Had some difficulties with coil stacking, but smooth pressure changes with 200-300 psi of motor work (no abrupt changes in rnmeu: vmicwa n.uo. io ran ~ ~ BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ~, Task Code NPT ~~ .Phase I Description of Operations 12/30/2008 00:00 - 09:00 9.00 STWHIP P WEXIT pressures). 09:00 - 10:05 1.08 STWHIP P WEXIT Drill into formation from 13,470 ft to 13,478 ft. 10:05 - 11:05 1.00 STWHIP P WEXIT Back ream window, Dry pass through window 11:05 - 14:30 3.42 STWHIP P WEXIT POOH 14:30 - 15:30 1.00 STWHIP P WEXIT LD window milling BHA. 15:30 - 16:15 0.75 STWHIP P WEXIT Swizzle stick the stack 16:15 - 20:40 4.42 DRILL N SFAL PROD1 Trouble shoot BHA HOT magnetics won't calibrate. Change 20:40 - 20:50 0.17 DRILL P 20:50 - 21:40 0:83 DRILL P 21:40 - 00:00 2.33 DRILL P 12/31/2008 00:00 - 00:35 0.58 DRILL P 00:35 - 00:55 0.33 DRILL P 00:55 - 01:05 I 0.171 DRILL I P 01:05 - 04:00 I 2.921 DRILL P 04:00 - 07:45 3.751 DRILL I P 07:45 - 09:30 ~ 1.751 DRILL ~ P out HOT's, new HOT is too clod to function correctly. Steam HOT to warm up hydraulics. Calibrate and test new HOT. PROD1 PJSM - on PU of build section BHA. PROD1 PU BHA #3 -build section BHA with 3.1 AKO, and Hycalog 3.75 X 4.25 bi center bit. Had to fight BHA through well head - tightfit. PROD1 RIH with BHA #3, EDC open. PROD1 Continue to RIH to 13,180 ft PROD1 Log for GR tie in from 13,130 ft - 13,180 ft RIH to 13,390 ft to park for depth correction and collar location -8.5 ft correction. PRODi Close the EDC and RIH Pass through window clean, tag bottom ~ 13,482.9 ft. PROD1 PROD1 PROD1 09:30 - 10:45 1.25 DRILL P PRODi 10:45 - 15:15 4.50 DRILL N SFAL PROD1 15:15 - 21:30 6.25 DRILL N SFAL PROD1 13,477 ft Drilling ~ 13,484 ft Op=2.46/2.48 bpm ~ 3185 psi Den=8.57/8.54 ppg (still displacing BIO out of liner) DH WOB=3210# CT WT=7180# ROP=6 FPH ECD=10.17 ppg DPRESX=564 psi NBI=7.57 deg. ~ 13,530.6 ft 0=2.51 /2.15 bpm Losses are healing by 13,535 ft. Drilled to 13,540 ft -Not getting sufficient DLS need 3 ea only getting 31 dea_ POOH for new AKO setting. Follow pressure schedule while POOH. 0=2.96/2.68 bpm ~ 62 ft/min (no losses). LD build BHA. Install extra lubricator and make presure deployment measurements. MU 3.75 deg AKO,mtr with Hycalog 4.25" bi-center. Stab coil. Test tools. Get on well. Run in hole. Loud "clunk" from reel. Check out same. Inspect reel. Found several drive. plate bolts sheared off. Call for mechanics and replacement bolts. (Change out day for mechanics) Dissassemble reel drive system components. Continue to repair drive systems Stab on well and test run in and out of hole. Nnntea: vztiizuua i i:uo: iu r+m BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date I From - To 'Hours Task Code NPT Phase Description of Operations 12/31/2008 15:15 - 21:30 6.25 DRILL N SFAL PROD1 21:30 - 00:00 2.50 DRILL P PROD1 RIH with build section BHA #4 with 3.8 AKO. EDC open and .40 bpm .1/1/2009 00:00 - 00:35 0.58 DRILL P PROD1 Continue to RIH with BHA #4 00:35 - 01:10 0.58 DRILL P PROD1 Log for GR tie in from 13,130 ft to 13,175 move to 13,390 ft to stop and make correction. -12 ft correction Close EDC, and log to tie in whipstock pip tags. pip tag ~ 13,471.5 ft 01:10 - 05:30 4.33 DRILL P PROD1 43K up WT & 3200 psi FS Drilling ~ 13,545 ft QP=2.46/2.46 bpm ~ 3340 psi Den=8.59/8.62 ppg ECD=10.71 ppg DH WOB=540 # CT WT=12900 # ROP=.6 fpm / 35 FPH DPRESX=577 psi NBI=25.77 deg and TF=355 deg. INCREASE WOB to 2620 #'s ROP = 74 FPH (short lived) Very slow ROP's ~ 13,561 ft Op=2.51 bpm ~ 3450 psi DH WOB=5300#'s ROP= 0 to 0.1 FPM Drilling improving again ~ 13,586 ft / ROP=50 FPH drilled to 13,609 ft 05:30 - 08:00 2.50 DRILL P PROD1 Continue to drill build section from 13 6 3500 psi fs at 2.48 bpm in/out. 100-200 psi mtr work. DHWOB: 2.5-5k#. IA/OA/PVT: 930 psi/138 psi/385 bbls. WHP/BHP/ECD: 55 psi/4084 psi/10.84 ppg. INC/AZM/TF: 90.07/318 deg/70L. Getting 43 deg avg dog IecL Land build in A2 sand at 13 730' d. 08:00 - 11:00 3.00 DRILL P PROD1 Wiper trip to above window. Open EDC. Circulate out of hole. Maintain BHP as per pressure schedule. Hold PJSM to review getting off well and laying down BHA. 11:00 - 14:00 3.00 DRILL P PROD1 Bleed off well. Flow check same. Pull and LD BHA. Bit 0-0-I. Very green. Hold PJSM to review using pressurized circulation loop. Label valves as per procedure. Circulate across well holdin 700 Install SLB UTIM coil monitor system. 14:00 - 17:00 3.00 DRILL P PROD1 Pressure deploy lateral BHA with res tool & 1.2 deg mtr with new Hycalog raptor 4.25" bit. 17:00 - 20:25 3.42 DRILL P PROD1 Run in hole. Follow BHP pressure schedule 20:25 - 20:45 0.33 DRILL P PROD1 Log for GR tie in. Park at 13,400 ftmake -14 ft correction. 20:45 - 21:00 0.25 DRILL P PROD1 Continue to RIH and wiper to bottom. Tag ~ 13732 ft 21:00 - 22:40 1.67 DRILL P PROD1 Drilling ahead ~ 13.740 ft Op=2.5/2.5 bpm C~? 3620 psi & WHP=51 psi Den=8.67/8.67 ppg ECD=10.78 DH W06=1160#'s CT WT=11,100 #'s DPRESX=761 psi NBI=91.14 deg drill to 13,828 ft - Diff stuck. Printed: vz~zuus n:u5aannn ~ ~ BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date '. From - To ~ Hours Task Code NPT Phase Description of Operations 1/1/2009 22:40 - 00:00 1.33 DRILL N STUC PROD1 CP=fell off while drilling. Pipe was stu en driller tried to PU. Able to circulate with full returns. HOT will orientate. DH WOB show's positive and negative WOB when pushing and pulling. 1/2/2009 100:00 - 01:15 1.251 DRILL N STUC PROD1 01:15 - 01:25 0.17 DRILL N STUC PRODi 01:25 - 02:30 1.08 DRILL N STUC PROD1 02:30 - 02:55 0.421 DRILL N STUC PROD1 02:55 - 04:25 I 1.501 DRILL N STUC PROD1 04:25 - 07:00 I 2.581 DRILL I P 07:00 - 07:45 0.751 DRILL P 07:45 - 10:00 I 2.251 DRILL ~ P PROD1 Tried several times to pull free while maintaining circulation for MPD practices, Working higher and higher on the over pulls till 80,000 #'s up weight. -Down on pump to min rate with and without WHP still not free with 80K UP WT -Continue to circulate BU, order crude, and consult with town engineer. -line up to circulate across the top and hold WHP with choke wait 20 min. Continue to work stuck pipe: After 20 min circulating across the top -push down -800 #'s CT WT -PU 80,000 #'s -Not seeing the same amount on wt change in DH WOB. Circulate 20 bbls to warm up coil. SD pumps and relax WHP to 0 wait 20 min. PJSM with crew and LRHOS on pumping crude. Continue to work pipe after relaxation period. -down 0 #'s CT WT -UP 80,000 #'s -got back the DH WOB indications (-10,000 #'s with 80K up). Circulate to warm coil, PT connections with LRHOS, Test crud6 - 0.6 psi vapor pressure ~ 100 deg. Load 20 bbls of dead, crude into coil. and circulate to the bit 4 bbls crude in open hole section. Wait5min.-dnto0#'s UP75K Wait 5 min -repeat Wait 5 min -Saw DH WOB changing without working pipe. - DN 0# CT WT UP 70,000# pulled FREE. Circulate out Crude while wiper to window to tie in ~ pip tag. +9 ft correction. RIH to 13,750 ft, MAD pass up to 13,500 ft for GEO while circulating out the crude. ~ 115 bbls out take returns to TT ~ 167 bbls bring it in. lost 52 bbls. Back on bottom drilling. FS=3318 psi w/ DPRESX=443 psi Drilling ~ 13,834 ft OP=2.53/2.54 bpm @3535 psi &DPRESX=801 psi den=8.69/8.70 ppg ECD=10.85 ppg DH W0B=1260#'s CT WT=12,000#'s ROP=1.5 fpm / 90 FPH Drill to 13,976 ft PROD1 Wiper trip above window. Blow down kill line Run in hole. PROD1 Drill ahead from 13,976'. 3380 psi fs at 2.52 bpm in/out. 100-200 psi mtr work. dhwob: 2-3k#. ROP: 100 fph +. IA/OA/PVT: 275 psi/118 psi/323 bbls Printed: 1/26/2009 11:05:18 AM BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours I Task Code NPT ~ Phase Description of Operations 1/2/2009 07:45 - 10:00 2.25 DRILL P PROD1 WHP/BHP/ECD: 51 psi/4189 psi/11.1 ppg inc/azm/tvd: 86.8 deg/274 deg/7290'. Drill to 14,125'. 10:00 - 10:45 0.75 DRILL P PROD1 Wiper trip to window. 3380 psi fs. 324 bbls pvt. Hole smooth. 10:45 - 13:00 2.25 DRILL P PROD1 Drill from 14,125' to 14,275'. 3450 psi fs at 2.52 bpm in/out. 13:00 - 14:00 1.00 DRILL P PRODi Wiper trip to above window. Log GR tie in. Add 5' correction. Run in hole. 14:00 - 15:30 1.50 DRILL P PROD1 Drill ahead from 14,275' to 14425'. 3550 psi fs at 2.52 bpm in/out. 15:30 - 16:30 1.00 DRILL P PROD1 Make wiper trip to 13,500. Hole smooth in both directions. Begin mud swap to new flo pro. 16:30 - 17:45 1.25 DRILL P PROD1 Drill ahead from 14,425'. 3350 psi fs at 2.48 bpm in/out. Continue mud swap. Drill to 14575 ft 17:45 - 19:35 1.83 DRILL P PROD1 Wiper to window, Hole has was smooth both ways. Tag ~ 14,574 ft 19:35 - 20:50 1.25 DRILL P PROD1 Drill ahead from 14,574 ft. FS = 3150 psi &DPRESX = 418 psi Drilling ~ 14.600 ft Op=2.54/2.54 bpm ~ 3590 psi &DPRESX=870 psi Den=8.65/8.75 ppg ECD=10.78 ppg DH WOB = 1,630#'s CT WT = 10,300 #'s ROP=2.4 fpm / 140 FPH Drilled to 14,725 ft 20:50 - 23:00 2.17 DRILL P PROD1 Wiper to window Tie in C~3 Whipstock RA marker. + 4 ft correction. Tag ~ 14,727 ft. 23:00 - 00:00 1.00 DRILL P PROD1 FS=3130 psi Drill ahead from 14,725 ft Op=2.54/2.54 bpm @ 3700 psi DH WOB=1900 #'s. ROP=2.4 fpm / 144 FPH Drill to 14,837 ft 1/3/2009 00:00 - 00:40 0.67 DRILL P PRODi Continue drilling from 14,837 ft midnight depth to 14,875 ft. 00:40 - 02:45 2.08 DRILL P PROD1 Wiper trip to window. -clean Tag ~ 14,872 ft 02:45 - 04:20 1.58 DRILL P PROD1 FS = 3030 psi l~ 2.4 bpm Drilling ~ 14,889 ft Op=2.4/2.4 bpm (~ 3270 psi DH WOB =1322 #'s CT WT=11,600 #'s ROP=1.ifpm / 64 FPH Difficult to get started "ratty" conditions, several stalls. Drill to 14,936 ft 04:20 - 04:30 0.17 DRILL P PROD1 Wiper to 14,800 ft. 04:30 - 05:05 0.58 DRILL P PROD1 FS = 3230 psi / 420 psi ~ 2.52 bpm Tag & stall out several more times. 05:05 - 08:30 3.42 DRILL P PROD1 Wiper to 9,000' into cased hole. 3420 psi fs at 2.57 bpm in/out. pvt: 320 bbls. Noticed some cow patties over the shaker during trip. rnntea: uzazuva iivo:ia rwi BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ' Task Code NPT ', Phase ~', Description of Operations __ -- _ - 1/3/2009 08:30 - 08:45 0.25 DRILL P PROD1 Log GR tie in. Add 6' correction. 08:45 - 09:45 1.00 DRILL P PROD1 Continue to run in hole. 09:45 - 12:15 2.50 DRILL P PROD1 Drill ahead from 14,936'. 2:15 - 13:30 13:30 - 15:00 15:00 - 16:30 16:30 - 17:30 .25 1.50 1.50 1.00 RILL DRILL DRILL DRILL P P P P ROD1 PROD1 PRODi PROD1 3450 psi fs at 2.50 bpm in/out. 150-300 psi mtr work. dhwob: 1.5-2.Ok#. BOP: 50-80 fph IA/OA/PVT: 508 psi/270 psi/327 bbls. WHP/BHP/ECD: 59 psi/4198 psi/11.09 ppg. Inc/Azm/TVD: 87.7 deg/294 deg/7292'. Drill to 15,075'. Wiper trip to window. 3237 psi fs at 2.47 bpm in/out. pvt: 323 bbls. Hole smooth. Drill ahead to 15,162'. Trouble sliding. Make early wiper trip to window. 3350 psi fs at 2.53 bpm in/out. pvt: 313 bbls. Drill ahead from 15,161. Very touchy near btm. Stalling easilly. Not sure if due to mtr or formation. 17:30 - 22:25 4.92 DRILL P PROD1 Wiper from bottom, Pull through window open EDC Qp=3.26 bpm ~ 3500 psi Perform surface jog - a little extra cuttings across the shaker. PJSM - on pressure undeployment and inspecting coil while POOH 22:25 - 23:30 1.08 DRILL P PROD1 Pop of injector, while maintaining WHP with circulating loop. Run coil down into rat hole for visual inspection. Found several flats ots in coil within first 30 ft. 23:30 - 23:45 0.25 DRILL P PRODi PJSM on cutting coil with hand cutter and reheading coil. 23:45 - 00:00 0.25 DRILL P PRODi Cut 30 ft of coil. 1/4/2009 00:00 - 02:15 2.25 DRILL P PROD1 Continue to cut coil -Cut 29.5 ft off. Behead coil pull test, pressure test, and OC E-line Stand back injector. 02:15 - 03:45 1.50 DRILL P PROD1 PU lubricator and Pressure undeploy BHA #5. LD BHA. 03:45 - 04:00 0.25 BOPSU P PRODi Function test BOPE per AOGCC reps, Permit to drill, and well plan while BHI makes up and programs BHA. 04:00 - 04:30 0.50 DRILL P PROD1 MU new lateral BHA with new motor, HOT, and Bit. 04:30 - 04:45 0.25 DRILL P PROD1 PJSM on PU and Pressure deployment of BHA #6. 04:45 - 07:15 2.50 DRILL P PROD1 Pressure deploy BHA #6. Test tools. Crew change and PJSM. 07:15 - 10:30 3.25 DRILL P PROD1 Run in hole. Follow pressure schedule. 10:30 - 10:45 0.25 DRILL P PROD1 Log GR tie in from 13,150'. Subtract 14' correction. 10:45 - 12:00 1.25 DRILL P PROD1 Continue wiper trip to btm. 12:00 - 15:00 3.00 DRILL P PROD1 Drill ahead from 15161'. 3300 psi fs at 2.51 bpm in/out. 200-300 psi mtr work. 1-2k# dhwob. IA/OA/PVT: 370 psi/107 psi/304 bbls. WHP/BHP/ECD: 70 psi/4305 psi/11.36 ppg. Inc/AzmlTvd: 91.3 deg/273 deg/7296'. Tag btm and had two stalls, then begin drilling at 50-60 fph. Note a large volume of cuttings over shaker, well before btms up. Drill to 15,310'. 15:00 - 16:45 1.75 DRILL P PRODi Make wiper trip to 13,500'. rnncea: vzorzu~a i ~:~a: is nm BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To 'Hours Task Code NPT Phase Description of Operations ~ _ ~_ 1/4/2009 _ 15:00 - 16:45 1.75 DRILL P PROD1 3560 psi fs at 2.52 bpm in/out. Hole very smooth in both directions. 16:45 - 19:45 3.00 DRILL P PROD1 Drill ahead from 15310'. 3410 psi fs at 2.49 bpm in/out. Drilling ~ 15394 ft OP=2.45/2.45 ~ 3650 psi &DPRESX = 660 psi Den=8.88/8.93 ppg ECD = 11.48 ppg DH WOB=2,380 #'s CT WT=8,100 #'s ROP=1.5 fpm / 88 FPH Drill to 15,470 ft 19:45 - 22:35 2.83 DRILL P PROD1 Wiper to window. Tie in at RA with + 9 ft correction. Wiper to bottom ~ 30 fpm to help clean out with reduced O in build section of. Q=1.26 ~ 2290 psi in lateral Op=2.51/2.66 bpm C~3 3450 psi. Den=8.90/8.93 ppg. Pumped a 17 bbl high vis pill out of the bit at bottom. TAG ~ 15,475.5 ft 22:35 - 23:15 0.67 DRILL P PROD1 Drill ahead from 15,475 ft. Drilling C~3 15,479 ft Op=2.53/2.53 bpm ~ 3740 psi &DPRESX = 677 psi den=8.92/8.93 ppg ECD=11.59 ppg DH WOB=1190 #'s CT WT=9400 #'s ROP=1.2 fpm / 74 FPH TD called ~ 15 500 ft -.BHA wiper to finish getting Hi Vis pill out the bit. 23:15 - 00:00 0.75 DRILL P PROD1 Wiper to window 1/5/2009 00:00 - 03:30 3.50 DRILL P PROD1 Wiper trip to window. Tie in at Whipstock RA tag with +2.5 ft correction. Tag bottom ~ 15,501 ft. Wiper to window using new 8.6 ppg FlowPro. Paint flag ~ 13,547 tt EOP. 03:30 - 07:15 3.75 DRILL P PROD1 Pull through window, Open EDC, POOH. Follow pressure schedule. Qp=3.34/2.94 bpm ~ 3720 psi ~ 70 FPM At surface. Slowly bleed off whp. 07:15 - 08:00 0.75 DRILL P PROD1 Open hole BHA on to catwalk. Bit in excellent condition: 1-1-I. 08:00 - 11:45 3.75 CASE P RUNPRD PU liner running equipment. Complete rig up to run liner. MU liner ass 59 'ts 2-7/8" slotted/ erfed STL & billet) on BHI tools with BTT GS spear and knuckle joint. Get on well. 11:45 - 14:45 3.00 CASE P RUNPRD Run in hole. Follow pressure schedule. Wt check at window: 50k# up, 12k# do wt. 14:45 - 15:30 0.75 CASE P RUNPRD Continue in to open hole. Window smooth. Set down at 14418'. PU (65k#) and run at it a few times. Continue in hole. Ty btm at 15.503'. Come on line at 2.5 bpm at 4200 psi. 42k# up wt. Liner is released. Estimated TOL is 13,695'. 15:30 - 16:00 0.50 CASE P RUNPRD Log GR tie in from 14,910'. Subtract 12' correction. Liner top is on depth. 16:00 - 19:15 3.25 CASE P RUNPRD Pull out of hole. PJSM while POOH Pdntetl: U26/2009 11:U6:1S AM 1 BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To ~ Hours Task ~i Code NPT Phase Description of Operations - - -- - - -- __ 1/5/2009 19:15 - 19:35 0.33 CASE P RUNPRD Continue PJSM on pressure deployment procedure and review PDP with crew. This is the first time for this crew to PD since Kuparuk. 19:35 - 22:30 2.92 CASE P RUNPRD Pressure undeploy BHA. 22:30 - 22:50 0.33 CASE P RUNPRD Stand back Injector, and deployment lubricator to prep rig floor for maint. 22:50 - 23:10 0.33 CASE P RUNPRD PJSM -Nordic for cut and slip of drill line. P,1SM -SLB for servicing injector /chain inspection. 23:10 - 00:00 0.83 CASE P RUNPRD Nordic -Cut and slip drill line. SLB -Service injector /chain inspection. 1/6/2009 00:00 - 01:05 1.08 CASE P RUNPRD Continue with SLB & Nordic rig service. 01:05 - 04:30 3.42 DRILL P PROD2 Pressure deploy build section BHA. Inspect coil by running coil into rat hole. -light wear only. Continue deployment. 04:30 - 07:45 3.25 DRILL P PROD2 RIH following pressure schedule with BHA#8. 07:45 - 08:00 0.25 DRILL P PROD2 Log GR tie in.. Subtract 8' correction. 08:00 - 08:45 0.75 DRILL P PROD2 un in hole. Ta billet to at 13 693' d Trough up at TF 10L. 08:45 - 13:45 5.00 DRILL P PROD2 Time drill ahead on billet from 13,692'. 3400 psi fs at 2.49 bpm in/out. 100-200 psi mtr work. dhwob: 1-2k#. IA/OA/PVT: 138 psi/4 psi/209 bbls. whp/bhp/ecd: 51 psi/4245 psU11.22 ppg at 7287' tvd. 13:45 - 17:50 4.08 DRILL P PROD2 Drill ahead 13,725 ft ~` `~ ~ 3440 psi at 2.47 bpm "'~ ~ ~ ~ dhwob: 3K rop=26 FOH Drill to 13,847 ft 17:50 - 18:25 0.58 DRILL P PROD2 Wiper to window. 18:25 - 21:30 3.08 DRILL P PROD2 Drill ahead from 13,847 ft Drilling ~ 13917 ft Op=2.48/2.48 bpm ~ 3640 psi &DPRESX=611 psi Den=8.92/8.92 ppg ECD=11.4 ppg DH WOB=2910 #'s CT WT=6250 #'s ROP=1.0 fpm / 60 FPH BHA wiper C~ 13,948 ft Drill to 14,000 ft 21:30 - 22:15 0.75 DRILL P PROD2 Wiper to window RIH was clean. Tag ~ 13,999 ft 22:15 - 00:00 1.75 DRILL P PROD2 Drill ahead from 13,999 ft. Drilling X14,010 ft Op=2.55/2.55 bpm ~ 3830 psi &DPRESX = 621 psi Den = 8.95/9.05 ppg &ECD = 11.56 ppg DH WOB = 2,220 #'s CT WT = 7,000 #'s ROP = .9 fpm / 56 FPH 14,063 stacking -BHA wiper 64K up wt. Hole getting sticky drilling to 14,100 ft 1/7/2009 00:00 - 00:25 0.42 DRILL P PROD2 Continue to drill ahead from 14,075 ft Drill to 14,100 ft 00:25 - 01:05 0.67 DRILL P PROD2 W iper to window -Clean. 01:05 - 04:40 3.58 DRILL P PROD2 Pull through window and open EDC, POOH following pressure schedule. 0=3.29/2.94 bpm Perform jog near surface. Hold PJSM on pressure undeployment procedures while POOH rnmea: vzwzuua i i:~o: is Hm BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task. Code NPT ' Phase ~', Description of Operations 1/7/2009 04:40 - 07:30 2.83 DRILL P PROD2 Pressure undeploy BHA #8 w/ 750 psi whp Crew change/safety mtg LD BHA. Bit was 1-1-I 07:30 - 10:20 2.83 DRILL P PROD2 Adjust motor, change bit Safety mtg Pressure deploy BHA #9 Check CT for flat spots, inspect packoff 10:20 - 13:15 2.92 DRILL P PROD2 RIH w/ BHA #9 (1.2 deg motor, used HYC BC bit, res) circ thru it 0.40 130 13:15 - 13:30 0.25 DRILL P PROD2 Log tie-in down from 13150', corr -6.5' 13:30 - 14:05 0.58 DRILL P PROD2 RIH thru window, clean. Circ 1.0/1900 to billet. Pass billet at min rate. Wiper to TD 2.45/3200 w/ a few minor wt loss w/ MW spots 14:05 - 16:05 2.00 DRILL P PROD2 Drill from 14103' 2.42/3400/908 w/ 200-400 psi dill, 0.80-1.5k wob w/ 11.2 ECD at 88 deg at 100'/hr while swap to fresh mud. Drill to 14250' 16:05 - 17:10 1.08 DRILL P PROD2 Wiper to window. Sticky off bottom. OP's thru 13850-950' shale area. Rest of hole was clean to window. Wiper in hole at 1.0 bpm to just past billet was clean. Wiper at 2.5/3200 to TD except reduced rate to 1.0 bpm to get thru shale. Mud swap completed 17:10 - 19:15 2.08 DRILL P PROD2 Drill from 14244' 2.53/3230/80L w/ 100-300 psi dill, 0.85-1/6k wob w/ 10.78 ECD at 90 deg (7276' TVD) 19:15 - 20:05 0.83 DRILL P PROD2 Come off bottom sto drillin er GEO. Make small wiper trip while waiting for GEO evaluate direction 20:05 - 20:25 20:25 - 22:10 22:10 - 00:00 0.33 DRILL P 1.75 DRILL P 1.83 DRILL P PROD2 Drill from 14,376 to 14,400 ki h n PROD2 Wiper to window -clean with reduced through the shale and low spots. PROD2 Drill ahead from 14,400 ft Drilling ~ 14445 ft Op=2.50/2.49 bpm ~ 3370 psi &DPRESX=659 Den=8.67/8.76 ppg ECD=10.86 ppg DH W06=830#'s CT WT=10,400#'s ROP=1.1 fpm / 66 FPH NBI=87.86 deg BHA wiper ~ 14,479 ft - 68K UP WT. Drill to 14,505 ft PROD2 Continue to drill ahead from 14,505 ft to 14,550 ft Op=2.5 bpm @3400 psi ROP= 1.2 fpm / 73 FPH PROD2 Wiper to window ~ 2.5 bpm. Slow to 15 fpm from 13,950 ft to 13,850 for shale and 13,650 to 13850 ft for clean out of belly. Pump min rate and pull through window. Open EDC and pump 3.5 bpm ~ 3100 psi. Wiper to 10,000 ft. PROD2 Log for GR tie in from 13,130 ft to 13,200 ft. RIH to 13,380 ft and make +16 ft correction. Close EDC. PROD2 Continue wiper to bottom. PROD2 FS=3150 ps ~ 2.50 bpm &DPRESX=405 psi 1/8/2009 100:00 - 00:40 0.67 ~ DRILL ~ P 00:40 - 03:25 I 2.751 DRILL I P 03:25 - 03:55 0.501 DRILL P 03:55 - 04:45 0.83 DRILL P 04:45 - 06:20 1.58 DRILL P Printed: 1/26/2009 11:05:18 AM BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task '~, Code I NPT i 1/8/2009 04:45 - 06:20 1.58 DRILL P 06:20 - 07:45 1.42 DRILL P 07:45 - 10:15 2.50 DRILL P 10:15 - 11:25 1.17 DRILL P 11:25 - 11:35 0.17 DRILL P 11:35 - 12:15 0.67 DRILL P 12:15 - 14:00 1.75 DRILL P 14:00 - 16:00 2.00 DRILL P 16:00 - 17:10 1.17 DRILL P 17:10 - 18:40 1.50 DRILL P 18:40 - 19:05 0.42 DRILL P 19:05 - 20:15 1.17 DRILL P 20:15 - 22:10 1.92 DRILL P 22:10 - 00:00 1.83 DRILL N SFAL 1/9/2009 00:00 - 00:50 0.83 DRILL N SFAL 00:50 - 04:05 3.25 DRILL P Spud Date: 3/19/2004 Start: 12/25/2008 End: 1 /14/2009 Rig Release: 4/10/2004 Rig Number: 14 Phase Description of Operations PROD2 Tag ~ 14,559 ft and drill ahead. Drilling ~ 14,570 ft OP = 2.52/2.50 bpm ~ 3420 psi &DPRESX = 679 psi Den = 8.76/8.80 ppg &ECD=10.93 ppg DH WOB = 1390 #'s CT WT=11,400 #'s ROP = 1.6 fpm / 95 FPH NBI = 91 deg Drill to 14700' PROD2 Wiper to window was clean both directions while using slower pulling speeds and reduced pump rates over known shales PROD2 Drill from 14700' 2.43/3300/908 w/ 100-300 psi diff, 1.0-3.Ok wob w/ 10.88 ECD at 100'/hr at 90 deg. Scrape the top of sand at 14700-720'. Drill to 14 5 ' PROD2 Wiper to window PROD2 Wiper back in hole at red rate and set down at 13585'. Had to ream 2.1 /2800 to 13610' PROD2 Continue wiper in hole 1.06/2000 past billet, clean. W iper to TD, clean PROD2 Drill from 14850' 2.44/3320/90-120L w/ 100-300 psi diff, 1.5-3.Ok wob w/ 11.0 ECD at 90 deg at 7281' TVD at 100'/hr. Drill ood sand until 14910' PROD2 Drill from 14910' at a slower enetration rate of 75'/hr an to see GR incr to 120 a i units. Drill from 14980' 2.44/3300/130L at 10'/hr w/ 3.5-5.5k wob w/ 100-300 psi diff w/ sticky pickups. Drill to 15000' PROD2 Wiper to window was clean. Pull thru window, open EDC PROD2 Wiper to 10000' circ thru EDC 2.96/3200 PROD2 Log for GR tie in from 13,100 ft to 13,200 ft RIH to 13,380 ft and make +16 ft correction. Close the EDC while holding WHP with pumps down. PROD2 Continue wiper to bottom. - No reaming needed /Clean. PROD2 Having problems with stacking trying to get started tagged ~ 14,492 ft and slowly worked down to 15,002 ft with multiple stalls. Drilling getting better ~ 15,008 ft. Drilling ~ 15,065 ft Op=2.47/2.46 blm ~ 3550 psi &DPRESX=687 psi Den=8.89/8.92 ECD=11.32 ppg DH WOB=1,870 CT WT=7,000# Drilled to 15,068 ft. PROD2 Wiper to window while repairs are made to pump #1 -swab washed out. Mud pump #1- PT and returned to service X00:00 ~ 13,850 ft. PROD2 Continue wiper to bottom -Clean. PROD2 Tag bottom ~ 15,067 ft Again trouble getting started drilling. RIH to fast and motor stalls, RIH to slow and coil stacks out. Drilling ~ 15,082 ft Op=2.5/2.5 bpm ~ 3650 psi &DPRESX=675 psi Den=8.93/8.96 ppg ECD=11.35 ppg DH WOB = 1320 #'s CT WT=8000 #'s ROP= 1.1 fpm / 67 FPH NBI=87.5 deg Drilled to 15,220 ft Printed: 1/26/2009 11:05:18 AM • BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task ', Code NPT Phase Description of Operations 1/9/2009 04:05 - 05:40 1.58 DRILL P PROD2 Wiper to window, using 2.67 bpm ~ 3570 psi while POOH and slowing down to 15 fpm through shales and in belly (13,700 - 13650 ft). Wiper OOH was clean. Wiper in Tagged ~ 13,565 ft - DD was having problems with keeping tool face due to coil/tool string torque rolling the stops over. Tried several time with different pump rates highest being 1.3 bpm. Pull up through window and jet up while waiting on advise. 05:40 - 09:30 3.83 DRILL N DPRB PROD2 POOH for BHA circ thru open EDC 3.3/3500 09:30 - 12:30 3.00 DRILL N DPRB PROD2 Pressure undeploy w/ 700 psi LD BHA and remove res tool while SWS RU CT Inspect on horsehead 12:30 - 14:30 2.00 DRILL N DPRB PROD2 WO BHI to get replacement torque gauge from N1 WO SWS to fin RU Inspect BHI MU adjust motor w/ N1 torque gauge 14:30 - 15:30 1.00 DRILL N DPRB PROD2 SWS has CT Inspect RU, but can't get it to communicate. Rig it down, reinstall UTIM Safety mfg re: pressure deploy 15:30 - 16:10 0.67 DRILL N DPRB PROD2 MU BHA into lubricator. Attempt t_o_RIH w/ 2.4 deg motor and can't et in hole Safety mfg re: open hole deploy 16:10 - 17:45 1.58 DRILL N DPRB PROD2 Breakdown BHA in mousehole. Bleed off whp. Open hole deploy BHA RIH w/ CT checking wear on CT 17:45 - 21:10 3.42 DRILL N DPRB PROD2 RIH with BHA #10 following pressure schedule. 21:10 - 21:35 0.42 DRILL N DPRB PROD2 Log for GR tie in ~ 13,100 ft. with - 10 ft correction RIH and park ~ 13,400 ft to make correction. 21:35 - 22:30 0.92 DRILL N DPRB PROD2 SLB is servicing Reel drive plate through bolts. 22:30 - 23:40 1.17 DRILL N DPRB PROD2 Close the EDC, pass through window, and wiper down. 0=0.5 bpm ~ 1729 psi ~ 18 fpm TF=10 L Tag ~ 13,571 ft Q=0.5 bpm ~ 28 fpm TF=10 LT Tag C~ 13,572 ft with 7000 #'s DH WOB 0=0.5 bpm ~ 14 fpm TF=10 RT Tag ~ 13571 ft 0=0.25 bpm ~ 1560 psi @ 15 fpm TF=10 LT Tag ~ 13,572 ft TF = 10 LT ROP=41 fpm Tag ~ 13,572 ft gave a most of the weight back, pushed to 13,578 ft but stacked a ain. Consult with Greg Sarber: Continue to try with: ROP: Tool Face: All at 0.4 bpm. 50 fpm 10 L 18 fpm 10 L 20 fpm 30 L 40 fpm 10 L 10 fpm 25 R 25 fpm 50 L Still unable to et throu h. 23:40 - 00:00 0.33 DRILL N DPRB PROD2 POOH following pressure schedule to change out current 2.4 AKO for 3.8 AKO BHA. 1/10/2009 00:00 - 03:05 3.08 DRILL N DPRB PROD2 Continue to POOH following pressure schedule ~ 2.55 bpm. Printed: vzsizoos n:u5attarm ! • BP EXPLORATfON Page 13 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours , Task Code N'PT ' Phase ', Description of Operations i --- -- 1/10/2009 03:05 - 03:15 0.171 DRILL N DPRB PROD2 PJSM while POOH on LD of BHA and CT Inspect of last 100 ft 03:15 - 05:00 1.751 DRILL ~ N ~ DPRB ~ PROD2 05:00 - 08:10 ~ 3.17 ~ DRILL ~ N ~ DPRB ~ PROD2 08:10 - 08:30 0.33 DRILL N DPRB PROD2 08:30 - 09:30 1.00 DRILL N DPRB PROD2 09:30 - 10:40 1.171 DRILL ~ N ~ DPRB ~ PROD2 10:40 - 14:15 3.581 DRILL N DPRB PROD2 14:15 - 15:00 0.75 DRILL P PROD2 15:00 - 17:40 2.67 CASE P RUNPRD of coil. Slowly bleed down WHP to 0 and flow check well. Inspect last 100 ft of coil showing some wear but pass SLB min specs. Pull BHA #10 - LD 2.4 AKO motor and bit. MU BHA #11 -with 3.8 AKO and used 3.75" X 4.5" bit. Stab on Slowly bring up WHP to 750 psi for pressure schedule. RIH following pressure schedule Log tie-in down from 13150', corr -10'. Close EDC RIH circ thru bit 0.5/1300 and went thru window, clean. Set down at 13572' a couple times. Had to wash by at 1.0/2000 and saw wt loss/MW at 13574'. Set down at 13586' a few times. Had to wash by at 1.5/2600 to 13620' and then BHI 'Stops' were on the wrong side. PUH and orient around. Continue RIH at 2.1/2850 5'/min. Start 40 bbl hi-vis pill. Wash by billet 1.0/1800 to 13709' w/ expected wt loss in smaller OD hole. Wash back up hole and by billet at 1.5/2200 w/minor OP. Swap to fresh mud 2.5/3400 Slow recip 13630-680' while disp wellbore to fresh mud 2.5/3400. Slow wiper up hole to just below window was clean. Pull thru window Open EDC. POOH circ thru EDC 2.85/3000 w/ open choke while finish displacing wellbore to fresh mud LD drilling BHA Safety mtg re: run liner MU Unique Indexing Guide shoe on a 4 deg bent 2-7/8 STL pup + one solid and 51 slotted jts of 2-7/8" 6.16# L-80 STL liner _ 17:40 - 18:55 1.25 CASE P RUNPRD MU BTT Deployment Sleeve w/ torque sleeve and GS CTLRT assy MU BHI MWD assy w/ orientor 18:55 - 22:20 3.42 CASE P RUNPRD Slowly bring WHP up for pressure deployment. RIH with liner following pressure schedule. Tag ed ~ 14,350 ft (EDC shorted out after working through this shale section got a reading of 16,000 # DH WOB), Continue in hole after approval from town. Tagged a ain 15,014 ft, and tagged bottom @ 15,215 ft three times. Space 22:20 - 23:30 1.17 CASE P RUNPRD roug t WHP down to O psi. come up on pumps to release liner, unable to pump off of GS conection pumping 1.9 bpm. Working UP and down trvina to sumo off• 23:30 - 00:00 0.50 CASE N STUC RUNPRD Stuck -Mechanically unable to PU or Down. PU to 90,000#'s up weight, and 19,000 Down. 1/11/2009 00:00 - 02:30 2.50 CASE N STUC RUNPRD Continue to try and free liner and/or pump off of liner. Pressured up WHP incrementally to 950 psi -losing returns. Circulate High vis sweeps down coil 10bbls HV - 15 FP - 10 HV.... for 3 pills. Continue to work pipe and GS connection from 1.25 bpm to 2.4 bpm with and without WHP. (~ 52 % coil life ~ 13,586 ft. (which is on the reel right now) 02:30 - 11:10 8.67 CASE N STUC RUNPRD Call for 2% KCL Double slick. rnnteo: vzoizuua n:v°a° Hm BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date ~ From - To ,I Hours Task Code NPT Phase Description of Operations - - 1/11/2009 02:30 - 11:10 8.67 CASE N STUC RUNPRD Circulating ~ 0.5 bpm with WHP=300 psi losses started ~ 03:00 ~ 0.5/0.4 bpm ~ Reduced WHP to 200 psi & .33/.30 bpm WHP = 7 psi C~ .33/.31 bpm PVT=156 bbls ~ 03:15 Tried pulling free a few more times while waiting for KCL PVT=153 bbls ~ 05:45 Begin plans for worst case 11:10 - 12:30 1.33 CASE P RUNPRD Displace CT and wellbore above TOL to double slick 2% KCL at 2.72/4200 initial, 3.33/4130 final w/ open choke Nordic crew change 12:30 - 12:40 0.17 CASE P RUNPRD While circ 3.21/4120, stack max wt and liner still wouldn't move down hole. On first attempt while PUH, the GS remised from the liner at 49k normal u wt leavin the TOL at est 13482' (based on BOL at 15123') 12:40 - 16:00 3.33 CASE P RUNPRD POH circ 1.80/1600 16:00 - 16:30 0.50 CASE P RUNPRD LD BHI MWD assy LD BTT CTLRT assy w/ GS. All tools were recovered intact in 'as-run' condition 16:30 - 22:00 5.50 BOPSU P LOWERI Test BOPE as er approved well plan, AOGCC Regs, and Permit to drill # 208-166. Record all data electronically and on AOGCC test form. 250 psi / 3,500 psi. Test was witnesed by Bob Nobel, AOGCC. All PASSED. 22:00 - 22:10 0.17 FISH P LOW ER1 PJSM - on pumping slack managment and testing outermost inner reel valve. 22:10 - 22:50 0.67 FISH P LOWERI Take off UOC & LOC inspect for damage. - Eline was pulled out of head and out of anchor sub. After it ripped out it got pumped down through the flow sub. Tested eline -Passed. 22:50 - 23:15 0.42 BOPSU P LOWERI Pressure tested "outer most" inner reel valve and pack off 250 psi / 3500psi: PASS 23:15 - 23:45 0.50 FISH P LOWERI Pump for slack management. 23:45 - 00:00 0.25 FISH P LOWERI PJSM -Cutting coil 1/12/2009 00:00 - 01:55 1.92 FISH P LOWERI Cut coil -Cut 503 ft of coil, found wire ~ 222 ft. Leaves 2.7% slack per SLB calculator. 01:55 - 02:15 0.33 FISH P LOW ER1 Re head with SLB coil connector. Pressure test to 4,000 psi and pull test 35K 3's. 02:15 - 03:40 1.42 FISH P LOWERI MU BHI UOC & LOC. OC E line -pass. Pressure test - 3,500 psi 03:40 - 03:55 0.25 FISH P LOW ERi PJSM - MU & PU BHA 03:55 - 05:15 1.33 FISH P LOWERI MU Whi stock retrie I BHA. BHI DD scribed "" High Side with hook pointed up "" This will require a Low side tool face to engage the whipstock "' PU BHA, stab on injector. 05:15 - 08:20 3.08 FISH P LOWERI RIH with fishing BHA. 08:20 - 08:40 0.33 FISH P LOWERI Log tie-in down from 13150', Corr -2' PVT 140 (lost 3 bbls RIH) 08:40 - 09:10 0.50 FISH P LOW ERi RIH w/ LS TF circ KCI thru tool 0.25/40 13440' 49.Ok, 13.2k ~ 14'/min Lost wt at 13464.0' PUH w/ 5k over. Go back down and can't go in hole, good. PUH w/ 10k over on both surface and downhole indicators and held for -1 min when abruptly lost all wt back to neutral. No fluid losses. PU w/ extra 1.5k, but saw rnmea: uz°izuva i i:vo: i° r+m BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To ~ Hours Task Code NPT Phase I, Description of Operations 1/12/2009 08:40 - 09:10 0.50 FISH P LOW ER1 no overpull by the window, however string wt remains about 1 k over previous wt chk 09:10 - 12:30 3.33 FISH P LOW ERi POH circ thru hook 0.90/250 PVT 65 12:30 - 13:15 0.75 FISH P LOWERI St WD assy. Had no recovery. Inspect fishing tool and had no marks MU same assy 13:15 - 16:25 3.17 FISH P LOWERI RIH circ thru tool 0.50/280 16:25 - 16:45 0.33 FISH P LOWERI Log tie-in down from 13130', corr -2.5' PVT 132 (lost 2 bbls RIH) 16:45 - 17:40 0.92 FISH P LOWERI RIH w/ HS TF 1.63/1430 15.5k to 13475' Wash tray 3500 w/ HS TF w/ two 10'/min passes over 13450-475' Orient to LS -3' below the notch. PUH 50.1 k 0.5/120 and start pulling heavier at 13460.0'. Pull 5k over and open jars. RBIH and stack 7.9k and close jars. PUH and open jars. Straight pull to 90k (13442.0') and see -22.5k on BHI WOB. Go back to neutral and pull to max 90k at 60'/min. See -23.4k wob. RBIH and cock jars. Pull to 73k and let jars hit w/ -17.3k wob. Lost wt back to 46k. PUH w/ 5k over. Park to let element relax. See 0.1 b m losses PVT 134 17:40 - 21:25 3.75 FISH P LOWERI POH slow 0.52/0.44/120 w/ 2k over 21:25 - 22:00 0.58 FISH P LOW ERi LD Fishing BHA -Fish on the bank! hipstock showed good wear at bottom of whipstock face. Packer was missing middle rubber sealing element. 22:00 - 22:30 0.50 FISH P LOWERI Blow down tools, RD BHI tools, send out fishing tools and whipstock. 22:30 - 22:55 0.42 WHSUR P POST PU Nozzle for freeze protect. 22:55 - 23:40 0.75 WHSUR P POST RIH with nozzle 23:40 - 00:00 0.33 WHSUR P POST ~ 2500 ft waiting on LRHOS. Truck's have been tied up working for production for spill clean up support. 1/13/2009 00:00 - 00:15 0.25 WHSUR P POST PJSM with LRHOS for PT and Pumping diesel. 00:15 - 00:50 0.58 WHSUR P POST Continue to circulate waiting for LRHOS to warm up diesel. 00:50 - 01:15 0.42 WHSUR P POST Spot in LRHOS, Pressure test lines to 4,000 psi. 01:15 - 02:05 0.83 WHSUR P POST Load coil with 35 bbls of diesel, and circulate out. With diesel at the nozzle POOH 1 for 1 to surface. 02:05 - 02:50 0.75 WHSUR N SFAL POST Coil tubin acted while POOH durin freeze rotect o s. We had pumped 22 bbls of diesel out of bit before failure. iesel was released and held inside of seconda containm Notifications made: Ken Miller, CTD Superintendent ~ 02:10 Chuck Sevcik, Day CO-Man fry 02:20 Herb Williams, HSE Advisor ~ 02:32 SLB driller notified: Liam Weir, CTD Cell leader Regroup and make a plan forward. 02:50 - 03:20 0.50 WHSUR N SFAL POST PJSM on regaining control of coil tubing, Complete SLB Hazard Analysis an Risk Control record. 03:20 - 04:40 1.33 WHSUR N SFAL POST Secure coil ~ horse head and near break with tugger line. Cut Eline. Pull coil back to reel secure and cut. 04:40 - 05:00 0.33 WHSUR N SFAL POST PJSM -Securing well, Using BOP's to hold/secure coil tubing in well head. Striping injector and cutting coil. Also covered well control contingency plans. 05:00 - 08:15 3.25 WHSUR N SFAL POST Set 2-3/8" combi rams (btm) on CT and P-P test w/ 10k. RILDS. Printetl: 1/26/2009 11:05:18 AM • • BP EXPLORATION Page 16 of 17 ~ Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours ' Task Code. NPT ', Phase ~ Description of Operations 1/13/2009 05:00 - 08:15 3.25 WHSUR N SFAL POST MPU RU scaffold on ops cab side of floor Develop plan forward. Decide to leave 3' lub above floor Penetrate CT -8' above the floor and allow the CT stub in the 08:15 - 08:30 0.25 WHSUR N POST Safety mtg re: remove CT stub from injector 08:30 - 09:15 0.75 WHSUR N POST Cut off CT -8' from floor w/ hand tubing cutter and lift injector w/ blocks. -20' of E-line is at top of stub Move scaffold out of way Run CT down from injector and hand cut in -5' lengths and get -35' Both ends of part look to be a factory weld. CCAT verifies weld 09:15 - 09:30 0.25 WHSUR N POST Safety mtg re: pull CT off reel to floor 09:30 - 12:00 2.50 WHSUR N POST Thread wire rope w/ grapple thru injector and pull to reelhouse. Install internal grapple and PT. Pull CT to floor and thru injector. Dress reel end of CT and insert spoolable dimple connector 12:00 - 12:20 0.33 WHSUR N POST Safety mtg re: finish CT splice 12:20 - 14:00 1.67 W HSUR N POST PU injector to put connector above stub Reset scaffold in front of 7" lub Cut a-line at top of stub. Dress stub to receive spoolable connector Align CT stub. Lower blocks, then stab w/ injector. Dimple up P-P test 10k each way. Set back scaffold Lower injector over CT and MU to lubricator. Open annular, pressure up w/ C-pump. Pull a bind and open combi rams to 40 psi whp showing on gauge 14:00 - 14:30 0.50 WHSUR P POST POH w/ well SI and not pumping, but with CT oven to drain to w II r . WHP bled off rapidly as CT was pulled from the wellbore. Secure tree 14:30 - 15:00 0.50 WHSUR P POST Displace CT w/ 2% KCI and take 10.0 bbls of diesel and 10 bbls of KCI to tiger tank (wellbore should have 25 bbls of diesel FP or -1650') 15:00 - 16:30 1.50 WHSUR P POST Remove checks from nozzle assy. Blow CT back w/air and recover 5.3 bbls MPU crew RD scaffold and load out 16:30 - 17:00 0.50 WHSUR P POST RU hydraulic cutter. Cut off 110' of CT, but with cool temps and waiting too long, the a-line froze to the inside of the CT MIRU N2 17:00 - 18:00 1.00 WHSUR P POST Safety mtg re: go to plan B Remove hyd cutter. Put injector over bunghole and fill w/ KCI until eline thawed and started moving. Pull out eline until all was recovered 18:00 - 20:20 2.33 WHSUR P POST Spot, RU & cool down N2 unit. Pump inhibitor & methanol into the reel. Blow down reel. Let reel depressurize. 20:20 - 21:30 1.17 WHSUR P POST PJSM regarding cutting coil. Pop off well. RU coil cutter. Cut 835ft of coil & pause. 21:30 - 23:10 1.67 WHSUR P POST PJSM regarding setting BPV. Open master - 4psi & diesel returns. RU GPB BPV lubricator. P.T. w/diesel to 500psi. Set 4" 'H' BP 23:10 - 00:00 0.83 WHSUR P POST MT pipe shed of coil. MT pits. Continue to cut coil. .1/14/2009 00:00 - 01:30 1.50 WHSUR P POST Continue to cut 1600ft of coil. MT pipe shed. Prep coil for unstabbing. Unstab coil & secure on reel w/ shipping bar. Place Printed: 1/26/2009 11:05:18 AM • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1./14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig. Name: DOYON 14 Rig Number: 14 Date From - To Hours ~ Task Code NPT .Phase ' Description of Operations 1/14/2009 00:00 - 01:30 1.50 WHSUR P POST injector over to side of RF & secure injector on RF. 01:30 - 11:00 9.50 BOPSU P POST ND Koomey lines. ND choke & kill lines. RD MPD loop hoses. RD MPD lubricator & stuffing box & prep for long term storage. Continue to MT & clean pits. ND BOP stack &MPD loop. RU tree cap & P.T. w/diesel to 5000psi -pass. ~tig released at iiam. Printed: 1/26/2009 11:05:18 AM rrsr by ~ BP Alaska ~ BN ~~s Baker Hughes INTEQ Survey Report INTEQ ~ Company: BP Amoco Date: 1/15/2009 Time: 08:51:30 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad, Vertical (TVD) Reference;` MPC-43:51.1 Well: MPC-43 Section (VS) Reference: Well (O.OON,O.OOE,333:30Azi) ~ Wellpath: MPC-43L1 Survey Calculation Method: . Minimum Curvature Db: Oracle Field. Milne Point ~ North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 _ _- - - -- ~~te: M Pt C Pad 1 I TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6027347.71 ft Latitude: 70 29 7.200 N From: Map Easting: 558058.04 ft Longitude: 149 31 31.821 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg _.._ - - Well: MPC-43 Slot Name: Well Position: +N/-S 2278.22 ft Northing: 6029626.64 ft Latitude: 70 29 29.606 N +E/-W 127.36 ft Easting : 558167.60 ft Longitude: 149 31 28.074 W ~ Position Uncertainty: 0.00 ft ~ Wellpath: MPC-43L1 Drilled From: MPC-43 j 500292320060 Tie-on Depth: 13379.14 ft Current Datum: MPC-43: Height 51.10 ft Above System Datum: Mean Sea Level Magnetic Data: 10/17/2008 Declination: 22.66 deg Field Strength: 57663 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.70 0.00 0.00 333.30 _ - Survey Program for Definitive Wellpath Date: 10/17/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft _. 81.00 632.00 MPC-43 GYRO (81.00-632.00) (0) CB-GYRO-SS Ca mera based gyro single shots 653.60 13379.14 MPC-43 (653.60-13744.68) (0) MWD+IFR+MS MWD +IFR + Multi Station 13463.00 15501.00 MWD (13463.00-15501.00) MWD MWD -Standard Annotation MD TVD ft ft __ ---- -- 13379.14 7113.23 TIP ~ 13463.00 7195.78 KOP ~ ~ 15501.00 7353.15 TD I Survey: MWD ~ Start Date: 12/31 /2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path b ~ BP Alaska i B ~GN • ~~ P Baker Hughes INTEQ Survey Report 1NTEQ ~ Company: BP Amoco ~ Date: 1/15/2009 Time: 08:51:30 Page: 2 Field: Mil ne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad Vertical (TVD) Reference: MPG-43: 51.1 Well: MPC-43 i Wellpath: MPC-43L1 Section (VS) Reference: Survey Calculation Method: Well (O.OON,O:OOE,333.30Azi) Minimum;Curvature Db: Oracle Survey -- MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 13379.14 11.35 342.66 7113.23 7062.13 9686.75 -3511. 42 6039284.69 554580.85 10231.54 0.00 MWD j 13463.00 8.90 341.71 7195.78 ~ 7144.68 9700.78 -3515. 92 6039298.69 554576.24 10246.10 2.93 MWD 13480.31 10.82 339.00 7212.83 7161.73 9703.57 -3516. 92 6039301.47 554575.22 10249.04 11.41 MWD 13495.25 15.55 336.00 7227.37 7176.27 9706.71 -3518. 24 6039304.60 554573.87 10252.44 31.98 MWD ~ 13507.65 19.28 333.00 7239.20 7188.10 9710.06 -3519. 85 6039307.93 554572.24 10256.15 30.93 MWD 13535.29 26.90 332.00 7264.61 7213.51 9719.66 -3524. 86 6039317.49 554567.15 10266.98 27.60 MWD ~i 13567.28 40.63 331.73 7291.14 7240.04 9735.29 -3533. 23 6039333.06 554558.66 10284.71 42.92 MWD 13602.72 55.75 325.47 7314.71 7263.61 9757.67 -3547. 09 6039355.32 554544.63 10310.92 44.61 MWD 13625.90 65.46 322.74 7326.08 7274.98 9773.99 -3558. 93 6039371.55 554532.66 10330.83 43.12 MWD 13663.51 81.39 318.74 7336.78 7285.68 9801.77 -3581. 70 6039399.15 554509.68 10365.88 43.56 MWD 13690.11 92.15 316.97 7338.27 7287.17 9821.43 -3599. 50 6039418.67 554491.73 10391.44 40.99 MWD 13710.49 92.89 311.09 7337.38 7286.28 9835.58 -3614. 13 6039432.70 554476.99 10410.65 29.05 MWD 13730.07 91.53 303.05 7336.62 7285.52 9847.36 -3629. 73 6039444.36 554461.30 10428.18 41.61 MWD 13760.90 93.29 299.20 7335.32 7284.22 9863.28 -3656. 09 6039460.07 554434.82 10454.25 13.72 MWD ~ ', i 13790.75 93.20 297.06 7333.63 7282.53 9877.33 -3682. 37 6039473.91 554408.43 10478.61 7.16 MWD 13820.97 91.07 294.85 7332.51 7281.41 9890.55 -3709. 52 6039486.91 554381.18 10502.62 10.15 MWD 13850.48 89.20 292.80 7332.44 7281.34 9902.46 -3736. 51 6039498.62 554354.10 10525.40 9.40 MWD 13880.74 88.62 290.54 7333.01 7281.91 9913.64 -3764. 63 6039509.57 554325.90 10548.01 7.71 MWD 13914.82 87.39 287.84 7334.20 7283.10 9924.83 -3796. 79 6039520.51 554293.65 10572.46 8.70 MWD 13943.21 87.24 285.27 7335.53 7284.43 9932.91 -3823. 97 6039528.38 554266.41 10591.90 9.06 MWD 13972.33 87.79 282.74 7336.79 7285.69 9939.95 -3852. 20 6039535.20 554238.13 10610.87 8.88 MWD 14006.37 87.61 279.95 7338.16 7287.06 9946.64 -3885. 54 6039541.62 554204.74 10631.83 8.21 MWD ~ 14035.52 87.09 277.28 7339.51 7288.41 9951.00 -3914. 33 6039545.76 554175.92 10648.66 9.32 MWD 14067.38 86.84 274.35 7341.19 7290.09 9954.22 -3945. 98 6039548.74 554144.25 10665.76 9.22 MWD 14096.42 87.70 273.77 7342.58 7291.48 9956.28 -3974. 91 6039550.56 554115.31 10680.60 3.57 MWD 14125.69 89.02 277.29 7343.42 7292.32 9959.10 -4004. 03 6039553.15 554086.17 10696.20 12.84 MWD 14162.57 89.17 282.54 7344.00 7292.90 9965.44 -4040. 34 6039559.22 554049.82 10718.19 14.24 MWD 14197.79 90.15 286.94 7344.21 7293.11 9974.40 -4074. 39 6039567.91 554015.70 10741.50 12.80 MWD 14223.82 90.21 290.47 7344.13 7293.03 9982.75 -4099. 04 6039576.06 553990.99 10760.03 13.56 MWD 14261.50 89.48 295.51 7344.23 7293.13 9997.46 -4133. 72 6039590.50 553956.20 10788.76 13.52 MWD i 14293.87 90.61 299.63 7344.20 7293.10 10012.44 -4162. 41 6039605.25 553927.40 10815.03 13.20 MWD 14325.87 92.49 299.84 7343.34 7292.24 10028.31 -4190 .18 6039620.90 553899.50 10841.68 5.91 MWD 14354.31 91.63 297.94 7342.31 7291.21 10042.04 -4215 .07 6039634.43 553874.51 10865.13 7.33 MWD 14395.02 91.87 294.44 7341.07 7289.97 10059.99 -4251 .57 6039652.10 553837.87 10897.58 8.61 MWD 14430.84 91.04 292.11 7340.16 7289.06 10074.14 -4284 .47 6039665.99 553804.87 10925.00 6.90 MWD I~ 14460.59 90.12 289.89 7339.86 7288.76 10084.80 -4312 .24 6039676.43 553777.02 10947.00 8.08 MWD 14493.27 90.31 286.25 7339.74 7288.64 10094.93 -4343 .30 6039686.32 553745.88 10970.01 11.15 MWD 14521.53 89.82 284.05 7339.71 7288.61 10102.32 -4370 .57 6039693.49 553718.55 10988.87 7.98 MWD 14553.74 91.04 287.24 7339.46 7288.36 10111.00 -4401 .59 6039701.93 553687.48 11010.56 10.60 MWD 14581.60 90.40 290.08 7339.11 7288.01 10119.92 -4427 .98 6039710.64 553661.02 11030.38 10.45 MWD 14610.48 90.09 293.52 7338.99 7287.89 10130.64 -4454 .79 6039721.15 553634.13 11052.01 11.96 MV11D 14640.97 88.87 296.99 7339.27 7288.17 10143.65 -4482 .36 6039733.94 553606.46 11076.02 12.06 MWD 14678.59 88.77 301.76 7340.04 7288.94 10162.09 -4515 .12 6039752.12 553573.56 11107.22 12.68 MWD 14700.55 88.68 304.58 7340.53 7289.43 10174.10 -4533 .50 6039763.99 553555.09 11126.21 12.84 MWD 14726.16 88.68 307.50 7341.12 7290.02 10189.16 -4554 .20 6039778.89 553534.27 11148.96 11.40 MWD 14749.66 88.71 306.16 7341.66 7290.56 10203.25 -4573 .00 6039792.82 553515.36 11169.99 5.70 MWD 14780.10 89.17 303.35 7342.22 7291.12 10220.59 -4598 .01 6039809.97 553490.23 11196.73 9.35 MWD 14809.79 90.06 302.02 7342.42 7291.32 10236.63 -4622 .99 6039825.81 553465.12 11222.28 5.39 MWD 14840.49 89.36 298.46 7342.57 7291.47 10252.08 -4649 .51 6039841.05 553438.48 11248.01 11.82 MWD 14870.19 89.26 295.93 7342.93 7291.83 10265.66 -4675 .92 6039854.42 553411.97 11272.00 8.52 MWD 14900.60 88.71 293.71 7343.47 7292.37 10278.42 -4703 .52 6039866.96 553384.27 11295.80 7.52 MWD 14929.00 88.65 291.33 7344.12 7293.02 10289.29 -4729 .74 6039877.63 553357.97 11317.30 8.38 MWD 14960.38 87.30 288.62 7345.23 7294.13 10300.00 -4759 .21 6039888.11 553328.42 11340.11 9.64 MWD -~.~ by ~ BP Alaska ~ s~ N~ Baker Hu hes INTEQ Surve Re ort g Y P INTEQ ~ - _.-. _ _ Company: BP Amoco I Date:. 1/15/2009 Time: 08:51:30 Fage: 3 ~ Field: Mi lne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad Verti cal (TVD) Reference: MPC-43: 51:1 WeIL MPC-43 Section (VS) Reference: Well (O.OON,O.OOE,333.30Azi) ~Wellpatb: MPC-4311 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ~ ft deg deg ft ft ft ft ft ft ft deg/100ft 14991.31 88.56 285.62 7346.35 7295.25 10309 .10 -4788.75 6039896.97 553298.81 11361.51 10.51 MWD 15021.51 89.69 282.79 7346.81 7295.71 10316 .51 -4818.02 6039904.15 553269.49 11381.28 10.09 MWD i 15049.23 90.37 280.99 7346.80 7295..70 10322 .22 -4845.14 6039909.65 553242.32 11398.57 6.94 MWD ~, 15084.78 89.85 276.82 7346.73 7295.63 10327 .72 -4880.26 6039914.88 553207.17 11419.27 11.82 MWD 15113.98 89.63 273.12 7346.86 7295.76 10330 .25 -4909.34 6039917.18 553178.07 11434.60 12.69 MWD ~ 15148.59 90.98 271.98 7346.68 7295.58 10331 .79 -4943.92 6039918.45 553143.49 11451.51 5.11 MWD 15180.47 ~~ 89.02 275.22 7346.68 7295.58 10333 .79 -4975.73 6039920.20 553111.67 11467.59 11.88 MWD 15207.89 86.99 278.82 7347.63 7296.53 10337 .14 -5002.92 6039923.34 553084.45 11482.80 15.07 MWD 15241.78 85.85 283.04 7349.75 7298.65 10343 .55 -5036.12 6039929.49 553051.20 11503.45 12.87 MWD 15272.04 85.98 287.78 7351.91 7300.81 10351 .57 -5065.21 6039937.28 553022.05 11523.69 15.63 MWD 15303.67 87.60 290.85 7353.68 7302.58 10362 .02 -5095.01 6039947.49 552992.18 11546.41 10.96 MWD 15330.67 89.72 292.65 7354.31 7303.21 10372 .02 -5120.08 6039957.29 552967.03 11566.61 10.30 MWD 15361.99 90.95 295.69 7354.13 7303.03 10384 .84 -5148.65 6039969.89 552938.37 11590.90 10.47 MWD 15390.49 91.10 299.74 7353.62 7302.52 10398 .09 -5173.87 6039982.94 552913.05 11614.07 14.22 MWD 15421.92 90.46 304.31 7353.19 7302.09 10414 .75 -5200.51 6039999.39 552886.28 11640.92 14.68 MWD 15455.98 89.91 308.51 7353.08 7301.98 10434 .96 -5227.91 6040019.38 552858.72 11671.29 12.44 MWD j 15501.00 89.91 308.51 7353.15 7302.05 10462 .99 -5263.14 6040047.14 552823.28 11712.17 0.00 MW Tree: 2-9/16" - 5M FM~ Wellhead: 11" x 11" 5M Gen 5, w 2-7/8" FMC Tbg. Hgr., 2-7/8" EUE Top & Btm, 2.5" CIW BPV Profile MPU C-~43 La -~1 ~ Orig. DF Elev. = 51.10' (Doyon 14) I Orig.GL Elev. = 16.40' (Doyon 14) 20" 91.1 #ppf, H-40 BTC 112' 10 3/4", 45.5 ppf, L-80 Btrc. ~ 9,363` Camco 2-7/8"x 1` KBMM 139` I Camco 2-7/8"x 1' KBMM 12,483` 2-7/8" 6.5#, L-80, EUE Srd 2.441" =Drift ID Cap = .0058 7-5/8" 29.7 ppf, L-80, Btc-mod ( drift ID = 6.875", cap. = 0.0459 bpf ) 4.5" 12.6 #/ft , IBT ,mod. ( drift id = 3.958" ,cap = .0152 bpf ) Baker Tie back slv. 12,735` Baker 7-5/8"x 5-1/2" "ZXP" liner pkr. 12,746' 7-5/8", 29.7# L-80 btc shoe 12,883' ~ Perforation Summary Ref IOg: Tied Jewelry log into MWD 4107/04 Size SPF Interval (TVD) 3-3/8" 12 13,566' - 13,576' 7,297' - 7,307' 3-318" 12 13,580' - 13,600' 7,311' - 7,331' 2-7/8" 6 13,619' - 13,628' 7,350' - 7,359' PF-3412 HMX Charges / 12spf 3.3/8" / .69" hole 2 HES RTTS slip segments DATE I REV.BY I COMMENTS XN Nipple (2.813 packing ID) 12 625' , (2.75 no-go ID) WeIILift Discharge Gauge Unit 12,638` Centrilift Tandem ESP 12 644' , 68-G31 SXD MVP 66-P31 SXD Gas Separator GRSFTx AR 12,673` Tandem Seal Assembly 12,678' Centrilift KMH Motor 12 692` , 228 HP, 2305 v / 60 amp WeIILift MGU Sensor 12,711 ` ~ CTD Window - 13460 - 13480 / 2-7/8" L-80 Slotted Liner 13482 - 15123 ~``~..._........J _~ ?~ Q 2-7/8" SIoUPerf Liner 13696 - 15501 o 0 • 4.5" Landing collar (PBTD) 13,727' 4.5" 12.6#, L-80 float shoe 13,815' 05/25/05 MDO Converted to ESP Nabors 4-es 01/14/09 Nordic 2 CTD Laterals 2/10/09 REH Re-complete w/ ESP -Nabors 3S MILNE POINT UNIT WELL C-43L1 ~r L9-01 API NO: 50-029-23200-00 ~ ~ ~~ ~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: January 30, 2009 Please find enclosed directional survey data for the following wells: MPB-22APB1 MPB-22A MPC-43L1 ~~ ~ - ~ ~s` MPC-43L1-Ol Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~~~ ,State of Alaska AOGCC DATE: '~ ~ ~ ~ ~ ~ 1 Cc: State of Alaska, AOGCC ~d~_ ~c~ ~ L__ J ,~NBa " a J~ ~ ~ ` airy" 6~4 \ ~ ~ )' ~' 9 ~ 4 o- s 0. ) a ,-..3 { ~ 1 qqg@g f s"' ~ 7 ) 9 ~ i f ) { : { f L.b ~ [ c , t ( p (l.'t ~ ~y^_ ~ ~ fJf` Itl_.k r~/ ALASSA OIL A1QD GA5 CO1~T5ERQATIOrT COIrIIKISSIOI~T ohn McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPC-43L1 BP Exploration Alaska Inc. Permit No: 208-165 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 700 ANCHORAGE, ALASKA 99507-3539 PHONE (907) 279-7433 FAX (907) 276-7542 Surface Location: 1344' FSL, 2290' FEL, SEC. 10, T13N, R10E, UM Bottomhole Location: 1311' FSL, 2300' FEL, SEC. 33, T14N, R10E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well MPU C-43, Permit No 204-039, API 50-029-23200-00. Production should continue to be reported as a function of the original API number stated above. 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). ce ely, Daniel T. Seamount, Jr. 5 Chair DATED this _ day of November, 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 COMMON ` '~ ~. ~ ~ ~ 20~& PERMIT TO DRILL 15 20 AAC 25.005 el~r~~ ni ~. r^~~ ~~,~,~ ; ° ~,~;=~~'r,r~ 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. Specify if wel ' I' d for: ^ Coalbed M~~~~' C~~as Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 ~ 11. Well Name and Number: MPC-43L1 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 15585' • TVD 7290'ss • 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 047434 & 355017 • Sands ' FEL, SEC. 10, T13N, R10E, UM 1344' FSL, 2290 Top of Productive Horizon: UM R10E T14N 509' FEL SEC 33 498' FSL 8. Land Use Permit: 13. Approximate Spud Date: December 1, 2008 , , , . , , Total Depth: 1311' FSL, 2300' FEL, SEC. 33, T14N, R10E, UM 9. Acres in Property: 3440 14. Distance to Nearest Property: 5,590' 4b. Location of Well (State Base Plane Coordinates): Surface: x-558168 y-6029627 • Zone-ASP4 10. KB Elevation (Height above GL): 51.1' • feet 15. Distance to Nearest well Within Pool: 1,090' 16. Deviated Wells: Kickoff Depth: 13460 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2139 - Surface: 1439 • 1 in Pr m: . i i n T- S b - B i f n c r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/ " -7/ " TL 1 7 1 7 m I d i r 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 13817' Total Depth TVD (ft): Plugs (measured): 7547' None Effective Depth MD (ft): 13700' Effective Depth TVD (ft): 7431' Junk (measured): 13701' asin Length Size Cement Volume MD TVD Conductor /Structural Surface 1- /4" 1 I I 7' Intermediate 1 7- / " x 1 3' Liner 1 4-1 x I 'G' 1 7 '- 1 1 '- 7 ' Perforation Depth MD (ft): 13566' - 13628' Perforation Depth TVD (ft): 7298' - 7359' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing i true a d correct. Contact Gres Sarber, 564-4330 Printed Name John 1Nul ~ Title Engineerin Team Leader p Prepared ey Name/Number Si nature Phone 564-4711 Date /~ ~ /~ 4 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill N - 2v~~~loJr API Number: SO-029-23200-60-00 Permit Approval See cover letter for o i n Conditions of Approval: ,-,/ If box is checked, well may not be used to explore for, test, or produce coalbed me~~tha//ne, gas hydrates, or gas contained shales: L~~~// Samples Req'd: ^ Yes. l~dNo Mud Log Req'd: ^ Yes L~No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: APPROVED BY THE COMMISSION ~~ Date COMMISSIONER "'" Submit In Duplicate Form 10-40 Revis 12/2005 ~ a ~ .~ p s,,,i ~ ~ ~~ /o, 23, o$ ~ c.~,:~ "" by BPXA Milne Point C-43L1, C-43L1-01 CTD Sidetracks October 21, 2008 To: Tom Maunder Petroleum Engineer Alaska Oil & Gas. Conservation Commission From: Greg Sarber CTD Engineer Date: October 21, 2008 Re: MPC-43L1, MPC-43L1-01 Permits to Drill Permit to Drill approval is requested for 2 sidetrack laterals added to well MPC-43. History -Milne Point C-43 is currently ashut-in Kuparuk "A" sand producer. The well was drilled March 2004, and given a frac stimulation in May 2004 with 213.5K# Carbolite. The well was initially completed with a jet pump. It was converted to an ESP completion in 2005. The ESP recently failed in Oct. 2008. The parent well perforations were still making a small volume of productive oil at ~50% WC prior to the ESP failing. ,.- Reason for PTD Request -Your approval is requested to add two coil tubing drilled sidetrack laterals from the MPC-43 producer. This well is ideally suited to test an unswept section of the Kuparuk A2 and A3 sands to the =-'" Northwest of the parent well bottom hole location. The scope of this project includes pulling the existing ESP completion and running a 4-1/2" tubing work string, drilling two lateral legs completed with slotted liners landed outside the window; pulling the CST whipstock to regain access to the perforations in the parent wellbore, and then pulling the work string and running a new ESP completion. Pulling and running the ESP completions will be performed by a dedicated workover rig. The coil sidetrack will be drilled by Nordic rig 2, and this PTD application covers only the work to be completed by Nordic 2 during the sidetrack operations. Technique -This well will be a Milne Point Kuparuk "A" sand well. BP does have some experience drilling Kuparuk sands with coiled tubing in the KRU using Nordic 2. Conoco Phillips uses a form of Managed Pressure Drilling where they use a less than kill weight fluid to drill with. This is done because of the large range in bottom hole pressures found in the KRU, how close BHP's are to frac pressure, and the need to maintain a constant bottom hole pressure to maintain shale stability. That complete system was considered for this well. The full MPD system used in the KRU was rejected due to the low bottom hole pressure on well MPC-43. A form of this technique will however be used. This is due to a desire to maintain a constant BHP to maintain shale stability. A dedicated drilling superchoke will be installed on the rig, and used to trap pressure on the wellhead when the rig pumps are shut down. This will maintain a constant bottom hole pressure on the wellbore at all times. However, there is 1 major difference between this technique, and the standard MPD well drilled in the KRU. Because this well has a bottom hole pressure of about ~6~Ib equivalent, at no time will the reservoir be under balanced. The drilling fluid used will be 8.6 ppg Flo-pro solids free mud. The rig pits will be full at all times with a greater than kill weight fluid. There is no need to have a separate tankage of kill weight fluid on location as is found on KRU MPD wells. The way this technique will be practiced is that the well will be loaded with drilling mud (KW F). The first drilling BHA will be run in the hole. Once the BHA is on bottom drilling the bottom hole pressure including ECD will be recorded. At times when pumps need to be shut down, the drilling super choke will be used to trap and maintain a constant bottom hole pressure equal to the pumps on BHP. At no time will the reservoir be in an under balanced condition. No formation fluids will enter the wellbore at any time. This discussion is provided should the question be raised about reason for the extra superchoke that will be located on the rig for this well. Timing -This well was just added to the drilling schedule for Nordic rig 2. The estimated start time for Nordic 2 to begin a CTD sidetrack on this well is December 1, 2008. 1~ 1. 2. 3. 4. 5. 6. 7. 8. 9. 1 11 1 1 1 1 1 1 CTD Sidetrack Summarv Pre-CTD Rig Work performed by Workover Rig: (Began on November 10, 2008) MIT OA Prep pad. Circ out freeze protect from the IA, Load and kill well. MIRU Workover rig. Test BOPE ND 2-9/16" tree, NU BOPS. Test same Pull 2-7/8" L-80 tubing with ESP completion. Run 4-1/2" L-80 tubing completion (See Schematic). ~ Set TWC svh~ C~~ ~~ c~ECt~~. 0. RDMO workover rig. 2. RU slickline. Pull ball and rod and RHC sleeve. 3. Run dummy whipstock to 13,500'. 4. Eline will set retrievable 4-1/2" monobore whipstock with top at 13,457'. 5. Install a BPV 6. Remove temporary scaffolding, level pad if needed. 7. Drill mousehole extension. ND BOPE, NU 4-1/16" 5M psi tree. Test same. . Install temporary scaffolding around well. ~~ V\ l ~~ Rig Sidetrack Operations: (Scheduled to begin on December 1, 2008 using Nordic rig 2) 1. MIRU Nordic Rig 2 T~~ S 2. NU 7-1/16" CT Drilling ROPE and test. 3. Pull BPV. ~.~+~~ 4. Mill 3.80" window at 13,457'. 5. Drill build/turn/lateral section of L1 with 3.75" x 4.125" bicenter bit, and drill L1 lateral to 15,585'. 7. Sidetrack from the L1 lateral off of the deployment sleeve/whipstock at 13,620' with a 3.75" bit. 8. Drill build/turn/lateral section of L1-01 with 3.75" x 4.125" bicenter bit, and drill L1-01 lateral to 15,500'. 9. Run a 2-7/8" L-80 slotted liner string with an L-80 deployment sleeve with top outside window at 13,480'. 10. Recover Baker monobore whipstock at 13,457'. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 2. Post-CTD Rig Work: 1. MIRU workover rig. 2. ND 4-1/16" tree. NU BOPE and test. 3. Pull 4-1/2" work string. 4. Run 2-7/8" ESP completion. 5. ND BOPE, NU 2-9/16" tree. 6. RDMO well with workover rig. 7. Re-install wellhouse and FL's. 8. Pull BPV. 9. POP Well Svc.~~ ~~ +~~~~~ l ~~m~ ~~~~ Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75" x 4.125" (bi-center bits used) Casing Program: Uncemented Slotted liner • 2-7/8", L-80 6.16# STL~3,620' and - 15,585' and for MPC-43L1 la~l • 2-7/8", L-80 6.16# STL 13,480' and - 15,.550' and for MPC-43L1-01 lateral Existing casing/tubing Information 10-3/4", L-80 45.4#, Burst 5210, Collapse 2480 psi 7-5/8", L-80 29.7#, Burst 6890, Collapse 4790 psi 4-1/2", L-80 12.6#, Burst 8430, Collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle on the L1 lateral is 94.23 deg @ 14,594'. The maximum planned hole angle of the Li-01 lateral is 95.21 deg @ 14,498'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line 5,590'.. • Distance to nearest well within pool -1,090' from MPL-16. Logging • MW D directional, Gamma Ray and Resistivity will be run over all of the open hole section on both laterals. Hazards • The maximum H2S concentration on the parent MPC-43A well is 5 ppm recorded on 10/10/2008. f • The maximum H2S concentration on the pad is on well MPC-03 at 9.5 ppm on 10/10-2008. • Hole stability is a potential problem. Previous experience drilling in KRU indicates that the shales in the Kuparuk interval can be degraded. To counter this, a constant bottom hole pressure will be used to drill the well. This will be done by using a dedicated drilling choke to trap pressure on the formation when pumps are down. • Fluid loss is not expected to be a problem on this well. Traditionally this has not been a problem in the KRU CTD drilling projects. • The TD's are not challenging from a weight on bit standpoint. No special measures will be needed to reach TD on these laterals. Reservoir Pressure • The reservoir pressure on MPC-43A was last recorded at 2,139 psi at 7,000' TVDSS in July 2008. (5.87 ~ ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 1,439 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewmanrf"errie Hubble Tree. ~s116" - 5[41 FMC 11 A p 1 ! Lr ,A ~ C?riq. i~ Elev. = 51.i~' ~noyn~, ~4~ We#,aad~ ~1 • x 11` 5M FMC 1~~ r V ""~F Gen 5, w 2-7lB"FMC Tb {5rig.S~ Elev. = 18~40r {Doyen 94~ g. ~~, UPTBG Top 8 etm, ;~i, 2.5' C!W BPV Profle 20' 97.9# ppf, Ff~tO 8TC ' 12' 70 3~'A", 45.5 PpF. L~0 Btrc. KQP ~ 300' Max. hale angle = ~ deg. Hole arx~ie thru`peris ='~ deg. 2-7t9" 6,5 ppf, L-80 8rd $ue tbg, drat id = 2.347' cap = .JG592 bpf } 7~/~' 25.7 ppf, L,BO, ~oinod ( drill ID = 5.875",cap. = 0.04513 bpf ) d.5" 12.6 iylfl , I8T ,mod. d drift id = 3"9a8' ,cap = Q.G12S bpf } 2-~~~s t° t~3~z 13J' I t:ernaso 2-7ta`~t 1• KaMC~ #~FZ 12,+482,. xN Nippr+e {2813pgt3cuu}it)3 12,635' {2.75 rw-ga l D~ Centt~'ift 909lGC 170D t:5P, 64$` 12 19VGC 8200 , sari 513, GPflATAR ia1 669' 12 Gas Separator c~s~Tx,~ •~ . Tandem Seal Assembly 674`. 12 rlex~rre n ~1ettlN Y7141A51. G.e , Centt~rPIKMH Mohr 687' 12 152 HP, 2325 v ! 44 smp . Pumpmaie Sensorwlf~s 12,7x1' i3aker Tie track sr~ 12, f 3 S' 8alcer T~'x 5-1t2' `2~CP" ~rne~* pta. ? 2,746' ?-5~'B', 29.7# L-90 btc sire Perfioratlan Summary Reflo{F TiedJarraYybglnb1111A1brd47AW sm. s~ »,.~~ tTwi ~~~ ~~ 19,`~6rt3'.19,07~; ; " ~sa'.7,~~ 3.:,~~" 13 13.590r . 13,93C•' 7,31i' .7,3x1 2.7tfi` 6 19,15' . ?3,F~~' 7,350. ? X53' PF3t f3 t Mx Ghaagee:! 12spf 3,3.8• ~ ,35' babe o~ ~u ev 04109J04 MDO 04125,U4 M @O 05+'25105 MDO Fiats faina ~' x 3.5' roller stem lost during R1Y'14 en 8."15'DS, Tcrp ~ 13741', 4.5' landingcciar{P9TD~ 13,727` 4.5 ~ 12.dill, L-8D float shoe 13.$1 S' oc~inlErrrs Dr#ed and conaliieted Doyon 14 Add fret pens Ganverted b ESP iYabors4~s MLME PANT UMlT W ELL C•13 AP'I f~0: 50-029~32Q0-00 ~: 2-9116"-SM FMC MPU C-43L1 & L1 Wellhead: 11" x 11" SM FMC Gen 5, w 2-718" FMC Tbg. Hgr., Proposed CTD Latorals UPTBG Top 8 Btm 1 2.5" CIW BPV Profile Orig. DF Etev. = 51.10' iDoyon 14) Orig.GL Elev. = 16.40' (Doyon 14) 20" 91.1# ppf, H-40 BTC 112' -2,000', 4-112" HES X Nipple, 3.813' ID 10 3!4", 45.5 ppf, L-80 Btrc. ~ 9, 363' ID 7-518" 29.7 ppf, L-80, Btc-mad ( drift ID = 6.875", cap. = 0.0459 bpf ) 4.5' 12.6 #/ft , I BT ,mod. (drift id = 3.958" ,cap = 0.0125 bpf ) 4-1'2" 12.6;e, L-60 IBT4Vork SVing Installed pre CTD Rig arrival Baker Tie back slv. 12,735' Baker 7-5/8"x 5-112" "ZXP" liner pkr. 12,746' 7-518", 29.7# L-80 btc shoe 12,883' 13~ 45T I-ia_s/1^ who- re~revea , Perforation Summary Rei log: Tied Jeweky log Into M,hNND 4107/04 s¢e SPF Interval (TVD) 33/8" 12 13,506' - 13.576' 7,297' • 7,30- 3-318° 12 13.580' - 13,600' 7,311' - 7,331 2-7/B" 6 13,619' - 13,628 7,350' - 7,355 PF-3412 HMX Charges 112spf 3 318' ! .69' hole -~ t 2,650', 4-1/2" HES X Nipple, 3.813' ID 12,550', 7-518" x 4-1/2" B KR S-3 Packer 12,650', 4-1/2" HES X Nipple, 3.813' ID ruler H 13480-13550 I ----~ "'~-__ ~-_Iv_~Z_:_a3_L_~_a1___I ~~- --- MPC-43L1----~ 2-718" L-80 Spotted liner 13600-15585 n 0 4.5" Landing collar (PBTD) 13,727` 4.5" 12.6#, L-80 float shoe 13,815' DATE REV 8Y COMMENTS MILNE POINT UNIT 04!09104 MDO Drilled and completed Doyon 14 WELL C~3L1 8 L1-01 04/26/04 MDO Add frac perts API NO: 50-029-23200-00 OS/25105 MDO Converted to ESP Nabors 4-es 10/15/08 MSE Prooosed CTD Laterals b ~ BP Alaska P Baker Hu hes INTE Plannin Re ort g Q g P 1NTEQ Gompatay: BP Amoco Date: 10/20/2008 Time: 09:54:42 Page: 1 '.Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad VerticaF(TVD) Ieference: MPC-43: 51.1 Well: MPC=43 Section (VS) Reference: Well (O.OON,O.OOE,325. OOAzi) ~ellpathf Plan 3, MPC-43L1 Survey Calculation Method: Minimum Curvature Db; Sybase - _ --- j Field: Milne Point - - North Slope UNITED STATES Map System:US State Plane Coordinate Geo Datum: NAD27 (Clarke 1866) System 1927 Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Sys Datum: Mean Sea Level _ _ Geomagnetic Model: bggm2007 - _ _ _ ---- jSite: M Pt C Pad -- - TR-13-10 ' UNITED STATES :North S Site Position: lope Northing: 6027347 .71 ft Latitude: 70 29 7.200 N From: Map Easting: 558058 .04 ft Longitude: 149 31 31.821 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: MPC-43 Slot Name: Well Position: +N/-S 2278.22 ft Northing: 6029626 .64 ft Latitude: 70 29 29.606 N +E/-W 127.36 ft Easting : 558167 .60 ft Longitude: 149 31 28.074 W Position Uncertainty: 0.00 ft - -. _ - -- Wellpath: Plan 3, MPC-43L1 Drilled From: MPC-43 500292320060 Tie-on Depth: 13379.14 ft Current Datum: MPC-43: Height 51 .10 ft Above System Datum: Mean Sea Level Magnetic Data: 10/17/2008 Declination: 22.66 deg Field Strength: 57663 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.70 0.00 0.00 325.00 Plan. Plan #3 Date Composed: 10/17/2008 copy Mary's plan 3 Version. 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD #N/-S +FJ-W Northing Easgng Deg Min Sec Deg Min Sec Dip. Dir.. ft ft ft fC ft MPC-43L1 Polygon 51.10 10866.77 -5373.28 6040450.00 552710.00 70 31 16.458 N 149 34 6.428 W -Polygonl 51.10 10866.77 -5373.28 6040450.00 552710.00 70 31 16,458 N 149 34 6.428 W j -Polygon 2 51.10 10538.51 -5600.87 6040120.00 552485.00 70 31 13.228 N 149 34 13.128 W -Polygon 3 51.10 9444.98 -3889.21 6039040.00 554205.00 70 31 2.485 N 149 33 22.670 W -Polygon 4 51.10 9769.25 -3151.58 6039370.00 554940.00 70 31 5.677 N 149 33 0.939 W ~ MPC-43 Fault 51.10 11329.81 -5754.70 6040910.00 552325.00 70 31 21.010 N 149 34 17.680 W -Polygonl 51.10 11329.81 -5754.70 6040910.00 552325.00 70 31 21.010 N 149 34 17.680 W -Polygon 2 51.10 10545.31 -2635.45 6040150.00 555450.00 70 31 13.312 N 149 32 45.739 W MPC-43L1 Target4 7341.10 10372.87 -4883.08 6039960.00 553204.00 70 31 11.604 N 149 33 51.972 W MPC-43L1 Target 5 7341.10 10529.21 -5307.91 6040113.00 552778.00 70 31 13.139 N 149 34 4.495 W MPC-43L1 Target3 7351.10 10204.63 -4471.34 6039795.00 553617.00 70 31 9.952 N 149 33 39.836 W MPC-43L1 Targetl 7361.10 9868.80 -3730.88 6039465.00 554360.00 70 31 6.654 N 149 33 18.011 W MPC-43L1 Target 2 i 7371.10 10037.04 -4142.61 6039630.00 553947.00 70 31 8.306 N 149 33 30.146 W Annotation r - M D TVD __ ----- -- -- - ------ - fr j 13379.14 7113.23 TIP - - ~ -_-~ 13460.00 7192.81 KOP 13480.00 7212.52 End of 9 Deg/100' DLS b ~ BP Alaska ~ ~'`~ P Baker Hughes INTEQ Planning Report iNTE Q Company: BP Amoco Pate. 10/20/2008 Time: 09:54:42 Ps~ge. 2 p"Field: Milne Point Co-ordinate(NE)Reference: Well: MPG-43, True North Site: M Pt C Pad Vertical"(TVD) Reference: MPC-43: 51.1 ' Well: MPC-43 Section (VS) Reference: Well (O.OON,000E,325.OOAzi) Wellpath: Plan 3, MPC-43L1 Survey Calculation Method: Minimum Curvature llb: Sybase~ Annotation MD TVD n ft 13530.00 7258.84 4 13617.54 7316.54 End of 42 Deg/100' DLS 13864.63 7369.95 6 j 14164.63 7371.54 7 14324.63 7371.76 8 14394.63 7369.48 9 14594.63 7356.18 10 14664.63 7351.39 11 14864.63 7340.65 12 14964.63 7339.06 13 15134.63 7340.99 14 15234.63 7341.52 15 ~ 15484.63 7341.45 16 j 15585.00 0.00 TD Plan Section Information - -- - -_ __ ---- ---- -- ---- - - - I MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft'deg/100ft deg/100ft deg 13379.14 11.35 342.66 7113.23 9686.75 -3511.42 0.00 0.00 0.00 0.00 13460.00 8.99 341.75 7192.81 9700.34 -3515.77 2.93 -2.92 -1.13 183.45 13480.00 10.79 341.75 7212.52 9703.60 -3516.85 9.00 9.00 0.00 0.00 13530.00 31.79 341.75 7258.84 9720.75 -3522.50 42.00 42.00 0.00 0.00 13617.54 65.00 319.49 7316.54 9774.67 -3556.67 42.00 37.94 -25.43 325.00 13864.63 90.00 303.01 7369.95 9930.59 -3737.06 12.00 10.12 -6.67 325.00 114164.63 89.41 267.01 7371.54 10007.01 -4022.08 12.00 -0.20 -12.00 269.00 114324.63 90.43 286.18 7371.76 10025.31 -4180.27 12.00 0.64 11.98 87.00 j 14394.63 93.29 294.09 7369.48 10049.36 -4245.90 12.00 4.09 11.29 70.00 14594.63 94.23 318.12 7356.18 10166.07 -4405.97 12.00 0.47 12.02 87.00 14664.63 93.60 309.72 7351.39 10214.47 -4456.23 12.00 -0.90 -11.99 266.00 14864.63 92.47 285.72 7340.65 10306.67 -4631.73 12.00 -0.56 -12.00 268.00 14964.63 89.34 274.13 7339.06 10323.87 -4730.04 12.00 -3.14 -11.59 255.00 15134.63 89.38 294.53 7340.99 10365.72 -4893.87 12.00 0.02 12.00 90.00 15234.63 90.02 306.52 7341.52 10416.42 -4979.86 12.00 0.64 11.98 87.00 15484.63 90.01 276.52 7341.45 10507.06 -5209.79 12.00 0.00 -12.00 270.00 15585.00 90.01 288.56 7341.42 10528.81 -5307.59 12.00 0.00 12.00 90.00 Survey MD Incl Azim SS TVD N/S FJW" MapN NIapE DLS VS TFO Tuo ft_ deg deg ft ft ft ft ft deg/100ft ft deg 13379.14 11.35 342.66 7062.13 9686.75 -3511.42 6039284.69 554580.85 0.00 9948.99 0.00 MWD 13400.00 10.74 342.46 7082.60 9690.56 -3512.62 6039288.49 554579.62 2.93 9952.80 183.45 MWD 13425.00 10.01 342.20 7107.19 9694.85 -3513.99 6039292.77 554578.22 2.93 9957.10 183.64 MWD 13450.00 9.28 341.89 7131.84 9698.83 -3515.28 6039296.75 554576.90 2.93 9961.10 183.90 MWD 13460.00 8.99 341.75 7141.71 9700.34 -3515.77 6039298.25 554576.39 2.93 9962.62 184.21 MWD 13475.00 10.34 341.75 7156.50 9702.73 -3516.56 6039300.64 554575.58 9.00 9965.03 360.00 MWD I 13480.00 10.79 341.75 7161.42 9703.60 -3516.85 6039301.50 554575.29 9.00 9965.91 0.00 MWD I 13500.00 19.19 341.75 7180.72 9708.51 -3518.47 6039306.40 554573.63 42.00 9970.86 0.00 MWD ~ 13525.00 29.69 341.75 7203.45 9718.32 -3521.70 6039316.18 554570.32 42.00 9980.75 0.00 MW D ~' 13530.00 31.79 341.75 7207.74 9720.75 -3522.50 6039318.60 554569.50 42.00 9983.20 360.00 MWD 13550.00 38.94 334.09 7224.05 9731.42 -3526.91 6039329.24 554565.02 42.00 9994.47 325.00 MWD 13575.00 48.37 327.36 7242.13 9746.40 -3535.40 6039344.15 554556.40 42.00 10011.61 331.26 MWD 13600.00 58.08 322.38 7257.08 9762.72 -3546.95 6039360.37 554544.73 42.00 10031.60 336.15 MWD 13617.54 65.00 319.49 7265.44 9774.67 -3556.67 6039372.25 554534.92 42.00 10046.96 339.15 MWD 13625.00 65.73 318.93 7268.55 9779.81 -3561.10 6039377.35 554530.44 12.00 10053.71 325.00 MWD 13650.00 68.21 317.09 7278.33 9796.90 -3576.50 6039394.32 554514.92 12.00 10076.55 325.23 MWD' 13675.00 70.71 315.31 7287.10 9813.79 -3592.70 6039411.08 554498.58 12.00 10099.68 325.96 MWD 13683.98 71.61 314.68 7290.00 9819.80 -3598.71 6039417.04 554492.53 12.00 10108.05 326.58 MPC- L 13700.00 73.22 313.58 7294.84 9830.43 -3609.67 6039427.59 554481.49 12.00 10123.04 326.78 MWD 13718.91 75.13 312.31 7300.00 9842.83 -3622.99 6039439.88 554468.07 12.00 10140.84 327.11 MPC- L b ~ BP Alaska ~ ~ P Baker Hughes INTEQ Planning Report INTG Q _-- Company: BP Amoco Field. Milne Point Site: M Pt C Pad Well: MPC-43 Wellpath: Plan 3, MPC-43L1 _ - - -- --- -- - _ Date. 1.0/20/2008 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: -Survey Calculation &iethod; --- - Time. 09 54;42 Yage. Well: MPC-43, True North MPC-43: 51.1 Well (O.OON,O.OOE,325.OOAzi) Minimum Curvature Db: 3 ybase I Survey ~ NID Intl Azim SS TVD N/S IN'JW MapN MapF, DLS VS TFO Too ft deg deg ft ' ft ft ft ft deg/1OOft ft deg I 13725.00 75.74 311.90 7301.53 9846.78 -3627.36 6039443.79 554463.67 12.00 10146.58 327. 46 MWD 13750.00 78.28 310.26 7307.15 9862.78 -3645.73 6039459.65 554445.18 12.00 10170.22 327. 56 MWD 13765.00 79.81 309.29 7310.00 9872.20 -3657.04 6039468.98 554433.79 12.00 10184.43 327. 93 MPC- L 13775.00 80.83 308.65 7311.68 9878.40 -3664.71 6039475.12 554426.08 12.00 10193.90 328. 12 MWD 13800.00 83.38 307.06 7315.12 9893.59 -3684.26 6039490.16 554406.41 12.00 10217.56 328. 23 MWD 13825.00 85.94 305.48 7317.44 9908.32 -3704.33 6039504.72 554386.23 12.00 10241.13 328. 44 MWD 13850.00 88.50 303.92 7318.66 9922.53 -3724.85 6039518.77 554365.60 12.00 10264.55 328. 59 MWD 13864.63 90.00 303.01 7318.85 9930.59 -3737.06 6039526.74 554353.33 12.00 10278.15 328. 67 MWD 13875.00 89.98 301.76 7318.85 9936.15 -3745.81 6039532.23 554344.53 12.00 10287.73 269. 00 MWD 13900.00 89.93 298.76 7318.87 9948.75 -3767.41 6039544.65 554322.85 12.00 10310.43 269. 00 MWD I 13925.00 89.87 295.76 7318.91 9960.20 -3789.63 6039555.93 554300.54 12.00 10332.56 269. 00 MWD 13950.00 89.82 292.76 7318.98 9970.47 -3812.41 6039566.02 554277.67 12.00 10354.04 269. 01 MWD 13975.00 89.77 289.76 7319.07 9979.53 -3835.71 6039574.90 554254.31 12.00 10374.83 269. 02 MWD. 14000.00 89.72 286.76 7319.18 9987.37 -3859.45 6039582.55 554230.51 12.00 10394.86 269. 03 MWD j I 14025.00 89.67 283.76 7319.31 9993.95 -3883.56 6039588.94 554206.35 12.00 10414.08 269. 04 MWD I ~ 14050.00 89.62 280.76 7319.47 9999.26 -3907.99 6039594.06 554181.89 12.00 10432.44 269. 06 MWD 14075.00 89.57 277.76 7319.64 10003.28 -3932.66 6039597.89 554157.19 12.00 10449.89 269. 07 MWD 14100.00 89.53 274.77 7319.84 10006.01 -3957.51 6039600.42 554132.32 12.00 10466.38 269 .10 MWD 14125.00 89.48 271.77 7320.06 10007.43 -3982.46 6039601.65 554107.36 12.00 10481.86 269 .12 MWD 14150.00 89.44 268.77 7320.29 10007.55 -4007.46 6039601.57 554082.37 12.00 10496.29 269 .15 MWD 14164.63 89.41 267.01 7320.44 10007.01 -4022.08 6039600.92 554067.75 12.00 10504.23 269 .17 MWD ~i 14175.00 89.48 268.25 7320.54 10006.58 -4032.44 6039600.41 554057.40 12.00 10509.82 87 .00 MWD 14200.00 89.64 271.25 7320.73 10006.47 -4057.43 6039600.11 554032.41 12.00 10524.07 86 .99 MWD 14225.00 89.80 274.24 7320.86 10007.67 -4082.40 6039601.11 554007.43 12.00 10539.37 86 .96 MWD, 14250.00 89.95 277.24 7320.91 10010.17 -4107.27 6039603.41 553982.54 12.00 10555.69 86 .95 MWD i 14275.00 90.11 280.24 7320.90 10013.97 -4131.98 6039607.02 553957.81 12.00 10572.97 86 .94 MWD 14300.00 90.27 283.23 7320.81 10019.05 -4156.45 6039611.91 553933.30 12.00 10591.17 86 .95 MWD 14325.00 90.45 286.23 7320.66 10025.41 -4180.63 6039618.08 553909.08 11.99 10610.24 86 .71 MWD 14350.00 91.47 289.04 7320.24 10032.98 -4204.45 6039625.46 553885.20 12.00 10630.11 70 .00 MWD 14375.00 92.49 291.87 7319.37 10041.71 -4227.86 6039634.01 553861.73. 12.00 10650.69 70 .05 MWD 14394.63 93.29 294.09 7318.38 10049.36 -4245.90 6039641.52 553843.62 12.00 10667.31 70 .15 MWD 14400.00 93.32 294.73 7318.07 10051.58 -4250.79 6039643.69 553838.72 12.00 10671.92 87 .00 MWD 14425.00 93.47 297.73 7316.59 10062.61 -4273.17 6039654.55 553816.26 12.00 10693.80 87 .04 MWD 14450.00 93.62 300.74 7315.04 10074.79 -4294.94 6039666.56 553794.39 12.00 10716.26 87 .22 MWD 14475.00 93.75 303.74 7313.44 10088.10 -4316.04 6039679.70 553773.19 12.00 10739.27 87 .40 MWD i 14500.00 93.87 306.74 7311.78 10102.49 -4336.41 6039693.93 553752.71 12.00 10762.74 87 .59 MWD 14525.00 93.98 309.75 7310.07 10117.93 -4356.00 6039709.21 553733.01 12.00 10786.62 87 .79 MWD 14550.00 94.08 312.75 7308.31 10134.37 -4374.75 6039725.50 553714.13 12.00 10810.84 88 .00 MWD 14575.00 94.16 315.76 7306.51 10151.77 -4392.60 6039742.76 553696.14 12.00 10835.34 88 .21 MWD 14594.63 94.23 318.12 7305.08 10166.07 -4405.97 6039756.96 553682.67 12.00 10854.72 88 .43 MWD 14600.00 94.18 317.48 7304.68 10170.04 -4409.57 6039760.90 553679.04 12.00 10860.03 266 .00 MWD 14625.00 93.96 314.48 7302.91 10187.97 -4426.89 6039778.69 553661.57 12.00 10884.66 265 .95 MWD 14650.00 93.74 311.48 7301.23 10204.97 -4445.14 6039795.55 553643.19 12.00 10909.05 265 .74 MWD ~ 14664.63 93.60 309.72 7300.29 10214.47 -4456.23 6039804.96 553632.04 12.00 10923.19 265 .54 MWD ~ 14675.00 93.55 308.48 7299.65 10221.00 -4464.26 6039811.42 553623.95 12.00 10933.15 268 .00 MWD , 14700.00 93.44 305.48 7298.12 10236.01 -4484.19 6039826.27 553603.91 12.00 10956.87 267 .92 MWD 14725.00 93.32 302.47 7296.65 10249.95 -4504.88 6039840.05 553583.11 12.00 10980.16 267 .74 MWD 14750.00 93.18 299.47 7295.23 10262.80 -4526.28 6039852.73 553561.61 12.00 11002.96 267 .56 MWD 14775.00 93.04 296.47 7293.87 10274.50 -4548.33 6039864.26 553539.48 12.00 11025.19 267 .39 MWD 14800.00 92.89 293.47 7292.58 10285.04 -4570.96 6039874.62 553516.77 12.00 11046.80 267 .23 MWD I 14825.00 92.74 290.47 7291.35 10294.38 -4594.11 6039883.78 553493.54 12.00 11067.74 267 .07 MWD ' 14850.00 92.57 287.47 7290.19 10302.50 -4617.73 6039891.71 553469.87 12.00 11087.93 266 .93 M e ~~ BP Alaska ~ $ P Baker Hughes INTEQ Planning Report IlNTE Q Company: BP Amoco Field: Milne Point Site: M PT C Pad Well: MPC-43 Wellpath: Plan 3 `MPC-43L1 Date: 10/20/2008 Time: 09`.54:42 Page: 4 Co-ordinate(NE)ReYerence: Well: MPC-43, True North Vertical (TVD) Reference: MPC-43: 51.1 Section (VS) Reference: Welk(O.OON,O.OOE,325.OOAzi) Survey Calculation Method:, Minimum Curvature. Db: Sybase ~ Survey MD , L~cl Azim SS TVD N/S E/W MapN MapE DLS VS '1'FO Tuo ft' deg deg ft -ft ft ft ft deg/i00ft ft deg 14864.63 92.47 285.72 7289.55 10306. 67 -4631.73 6039895.77 553455.83 12.00 11099.38 266.79 MWD 14875.00 92.15 284.51 7289.13 10309. 37 -4641.74 6039898.40 553445.81 12.00 11107.33 255.00 MWD 14900.00 91.37 281.62 7288.36 10315. 02 -4666.07 6039903.85 553421.43 12.00 11125.92 254.95 MWD 14925.00 90.58 278.72 7287.94 10319. 43 -4690.67 6039908.07 553396.80 12.00 11143.65 254.86 i MWD 14950.00 89.80 275.82 7287.85 10322. 60 -4715.47 6039911.04 553371.98 12.00 11160.46 254.81 MWD ~ 14964.63 89.34 274.13 7287.96 10323. 87 -4730.04 6039912.20 553357.40 12.00 11169.86 254.80 MWD 14975.00 89.34 275.38 7288.08 10324. 73 -4740.38 6039912.98 553347.06 12.00 11176.49 90.00 MWD 15000.00 89.34 278.38 7288.37 10327. 72 -4765.19 6039915.77 553322.22 12.00 11193.17 89.99 MWD 15025.00 89.34 281.38 7288.66 10332. 00 -4789.82 6039919.87 553297.57 12.00 11210.81 89.95 MWD 15050.00 89.35 284.38 7288.94 10337. 57 -4814.19 6039925.25 553273.16 12.00 11229.35 89.92 MWD 15075.00 89.36 287.38 7289.23 10344. 41 -4838.23 6039931.89 553249.07 12.00 11248.74 89.88 MWD 15100 00 89 36 290 38 7289 51 10352. 50 -4861.88 6039939.79 553225.35 12.00 11268.93 89.85 MWD i . 15125.00 . 89.37 . 293.38 . 7289.78 10361. 81 -4885.08 6039948.93 553202.09 12.00 11289.86 89.81 MWD ' 15134.63 89.38 294.53 7289.89 10365. 72 -4893.87 6039952.77 553193.26 12.00 11298.11 89.78 MWD 15150.00 89.48 296.37 7290.04 10372. 33 -4907.75 6039959.26 553179.33 12.00 11311.48 87.00 MWD 15175.00 89.63 299.37 7290.23 10384. 01 -4929.85 6039970.77 553157.15 12.00 11333.73 86.98 MWD ~ 15200.00 89.79 302.37 7290.36 10396 .84 -4951.30 6039983.43 553135.59 12.00 11356.54 86.96 MWD 15225.00 89.95 305.36 7290.41 10410 .77 -4972.06 6039997.19 553114.73 12.00 11379.86 86.94 MWD 15234.63 90.02 306.52 7290.42 10416 .42 -4979.86 6040002.78 553106.89 12.00 11388.96 86.94 MWD 15250.00 90.02 304.67 7290.41 10425 .36 -4992.36 6040011.63 553094.32 12.00 11403.46 270.00 MWD 15275.00 90.02 301.67 7290.40 10439 .04 -5013.28 6040025.14 553073.30 12.00 11426.66 270.00 MWD i 15300.00 90.02 298.67 7290.40 10451 .60 -5034.89 6040037.53 553051.59 12.00 11449.35 270.00 MWD' 15325.00 90.02 295.67 7290.39 10463 .02 -5057.13 6040048.77 553029.26 12.00 11471.45 270.00 MWD i 15350.00 90.02 292.67 7290.38 10473 .25 -5079.94 6040058.83 553006.38 12.00 11492.92 270.00 MWD 15375.00 90.02 289.67 7290.38 10482 .28 -5103.25 6040067.67 552983.00 12.00 11513.68 270.00 MWD 15400.00 90.02 286.67 7290.37 10490 .08 -5127.00 6040075.28 552959.20 12.00 11533.69 270.00 MWD 15425.00 90.02 283.67 7290.36 10496 .62 -5151.12 6040081.63 552935.02 12.00 11552.89 269.99 MWD 15450.00 90.01 280.67 7290.36 10501 .89 -5175.56 6040086.71 552910.55 12.00 11571.22 269.99 MWD 15475.00 90.01 277.67 7290.35 10505 .87 -5200.23 6040090.50 552885.84 12.00 11588.64 269.99 MWD ~ 15484.63 90.01 276.52 7290.35 10507 .06 -5209.79 6040091.61 552876.28 12.00 11595.09 269.99 MWD 15500.00 90.01 278.36 7290.34 10509 .05 -5225.03 6040093.48 552861.02 12.00 11605.46 90.00 MWD 15525.00 90.01 281.36 7290.34 10513 .33 -5249.66 6040097.57 552836.37 12.00 11623.10 90.00 MWD 15550.00 90.01 284.36 7290.33 10518 .89 -5274.03 6040102.94 552811.96 12.00 11641.63 90.00 MWD 15575.00 90.01 287.36 7290.32 10525 .72 -5298.07 6040109.59 552787.86 12.00 11661.02 90.00 MWD 15585.00 90.01 288.56 7290.32 - 10528 .81. -5307.59 6040112.59 552778.32 12.00 11669.00 90.00 3.5" BP Alaska wew~>'n ce>'uu a~zlza~xaow" ~«.r w.nw~e: rw .. ro. onsa4 N..am x M. Wfwe: ~f l: 61.tOM 8 Hyy O A 9 m u ~ m a> m 2 __ LEGEND .~ ~ x+vn., ~.xx "vaiam --- MPC-03~MPCd3) a, - MPC-03(Plan 3, MPG-431-01) --- - - PWn 3, MPC-03L1 ~'~r.°aTm: - - ~r Plan#3 +a a.~...a ~;, ~;~ a ~~ NK,x~ ui~.: ~am~am-nano E nazi. oni m~~i~g.~xn wm vewea xoe~o..f azs.oo• ~sonn.~ • _ T Plan: Plan k3 (MPC-031PIan 3, MPC-03L1) co, iMer'cFaot ~~~~ BP Alaska da ~Ma oi~ M nzimums tO True NOM Grealee By BP Date: 10120/2008 ~M` eo ql sA~, R n1xe~1~ No,o,. zz.s6° cnackae: Dale: 1#~G1lS by M~w~kv~¢la WELVATM pETJILi of lnNfaCL]I Slre Ih_5]663nT oe lMpL ~1 DiD rg1e-60.96° Gnniaci in~ormat:on wo3 i~x]¢~L1 is ~NV -,ol ~ Olt]100] „'~P~;zq TEQ 899^ a~,IN~,aa,=o~ r... i~«r ro[ +iPaiiu , , cen. Im] 3o,-as]o _ iziMPC-,inae,l eman. diimicnxsso~@:m~ "IMVC-ie~ o.r. woa°.: arq wrcii s+.~on -;°s INPC-,s .Yiii aMl-w ~rnl ,s luPC-,sj s iNPC,vI us.oo- om o.oo aaia xIUPC-m;l a, IMaGRII znl REFERENCE INFORMATION ~ ~' Co-ordinate (N/E) Re/erence: Well Centre: MPC-03, True NoM - zs'M c asx~ VeNral (ND)) Reference: MPC-03: 51.10 t+INacs+l Section (VB) Reference: Slot - (O.OON.D.OOE) s+IP:e~NPC-z+nl Measured Depth Reference: MPC-03: 51.10 _- ~ zs~nt Calculation Methotl. Minimum Curvature ~~ xse) __ 1n 1MP 2~6it1 E M Tuu FB11 `` x6.1 fsa nD a,e YI HVa • M olN s~ Yl~e M1nwr -_ it (MP IPB89~ B; IP ~1 ~5 (MPC 91 ~a fM~~l - JI ~MP ,Ln a[ (II IPCJ[j 9[1 J'~i SPie ~M L,Lt - e ~ ~ nC MrorTtinl ((~~cc nn fienaer (Pmn ~n +]+ssxs.oo wat ]w.R lYrJ3 +xsxul axnex +x.w wAO „Mx40 - sep lnl~ ~ ne IIW 11 8( PL uR Sa IP4n uf`C Uru~an _ ~, fMPC-0II ai (Ma a31 - al D6 ~MrP ~C61 a>IMPI~O]1 _ h t _ 12000_ ..._ ~ ~~~. 'T. ~-F ~,~'_i .~__... ... .~__._.. ~ _ _.._.. 1 l.. r~ _ '.-_ -`., 11800- ~ - 1' _ .... _ . 1 ~ '~ ~ 1 L `+ 1{ ~. { ~, - TT ,~ - t '~ '.• ,__ 1 -_; MPC-161MPL•16) ... - . - t. I t ~. ~ 1""" .: { ~ / L _ MPC35 MPC-25 ` _.~: .-+ T r ,. .. ._ 1160 - 1 ~ ~ `~ l /~ _ _ ~ 7 0 -+ ,~1 _; , 11400 7 y ~ ... .-- ,~ 112o j ~ - 6900 _ - I ~ MP429 MPL-Y91'~ .. .... 1 7200 ~ ~ { 1 ~ `- _ ~ F-~- ~ .l mot. t t + T t - 1100 ~ 7500 ,~~6600 - _ 8900 "1 ~ "r _ 1 }-,-1-'r MPC43 PIan3 MPU3L1-01 ` ~~ - 1080 ~ a 1 - 7200 1 L-..-.. 83 6800 .t t~ w 10600- ` - - I y ,. ~i ~+. O ~ Plan 7 MPC43L1 _ + - T t .... 10400 +Y r'f ~ ~- i ' .. + _ _ ~ `- i~ ~ _ I ~~ ~ ~- +L + 6800 7 ~ -'T T+ Y~ t 1 ? ) ~L ~.. 63 ~ 10000 ~ _ _ 1 w r-~ { 7't k+ 1t - ~ / .. { _ .. + ~\ MPC-43 MPC-03 .. 1 t T C 9800 ~ _-.... ._.._ _ 1(~~ - ~ -. ~ _ (A MPL-16A MP41611 -- ~ 8700 ~~ ~-' Y ~ - y 9fiD0 7200 .:.. ', - ~ -- .~ ~ - _ ~' \6900 \8600 8600 _ - ' 'i ~ ~y- { ? Y' 940D-.. 8300 - _ ~ _ _ 18300 Ttt t 8000 ~-_ j 6000 ~ ~ ~~ ~ 1 ~ 4 ~~ -~ ~ 1 _ L}ii -. `:. ' ~ 4 - _ - 6000 MPG21 (MP431 ~ ~ 92D0~ - 8700 +T ~ .r( - - T1{ I 7500 _ 5800 ^{ ~ 1-.!-, 1 ~{- _ ~ { T. - N 9000 - 500 1 -~ 00 7200 ~ t ~-~ ~~'. -: : .. ._. ... ~ 57 .. 8800 T ....- ~ __ _- ~ _ - ~_. - - ~-+_ r. r. .t.,-L _~---~ _ _ ..6900 - f-- _'1 ,_ 1 _ ...111 ~- 1 it -' ~ ii __ . __ .. 1... .. :_. \ ~ '.8600 57 1 . -.. .. _ - ~ ~ ~ .. -... ~ ~ rT~ - T- rT, i r-r ; -. ~_ ~\. 5100 - + TTT-.-. r. .. -"-T---r-rTT T-^-~f'7,~TTr'?n rrl~n-:-rr~TT,,~~- -8200 -8000 -78D0 -7600 -7400 -7200 -7000 -6800 -66D0 E40D {200 6000 -5800 -5600 -5400 -5200 -5000 -0800 -0600 -0400 <200 -0ODO -3800 -3600 -340D -32D0 -3D00 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 <00 West(-)/East(+) [~OOWin] WELL DETAILS A1:TI-COLL151O1: SF.TTDvGS COMPA:VV Ut-TAILS i:ame -~l-S -F:/-W AaMing Eazling LaliNdc Longitude Slot Interyolation MethNMD Interval: SU.00 dP Amoco DepN Range From: 131"/9.14 Tn: 15585 W MPC-13??]8 _'? 1].36 60'_96~M1.64 SSAIfi].b(1 ]U°~9'~9.60(.1: 149°31'?R O]4W ~/A Maximum Rangr: I]SS.U3 Refererce: Plan: Plan b3 Calculation Method: Minimum Cwvarun F rSVrtxm: ISCW'SA Scan ~teth~d: Trev [vlindxr Varth E.rnr sa.raex: EnipdFal-ca:iaF WaminF Methnd'. Rule. da.xd SIIRVEV PROGRAM DxPlh Fm Depth TO SurveyNlan 133]9.14 ISSAS W Plamud: Plm .'3 V3 w1:LLPATII DETAILS Twl Plan?.MPC-0?LI SW~Y?3?006U NWU Parcm Wellpath-. MPC-03 Tie m~ MD: 133)9.16 Rig: NaNic 2 Rxl: Uatum: MPC-03' SI.IOfl V.Sanmt Origin Origin Sunmg Angle ~VI-S -FJ-N' Fmm NU ??5.1X1' 000 0.00 J4.]0 LEGEND MPC-25 (MPC-25), Major Risk MPC-43 (MPC-43), Major Risk MPL-16 (MPL-16), Major Risk Plan 3, MPC-43L1 Plan N3 • ,~ ~ I ~\ % ~ I I 11 + I \ i / Is \\\\ ~ / s3 -. ~ , i ~ ~ - ~ ~~ o ~~ i ~ / ;~~ 58 ]5 \ - ~/ / ,. ~,, 1 % / / ° \ f 9A ._ ~b 105 -- ~ ~ v(\\~ \ 113 IiU -. .'_U ~ ..fir \ n / lig .__ 135 _ .. I -- - 143 •_ /' ~ i I50 _. Im i ISM ,' j;: x ~ i ~ _.. __ __ _r R< / Ifi5 I]3 _ _ _.n }I ~SU IRO - ~- ie^ IRA •. roc ~ lc. % TnvcllinF Cylinder Aiimmh ITFO- A/11 ~degJ v~ Crntre to Centre Separation J I SfVinJ Pia, Pw.,,,~a,PW,,.xRr.tFII by ~~ 1NTEt2 S. MO Irc Aei nU 5ltl NNSDYTA`k-N TYxe VSrc srg ~2a • ~'~'~~~ , BP Alaska • BAKER ^ .. : by HUGHES 's*++~' Anticollision Report INTEQ Company: BP Amoco Date: 10/20/2008 Time:" 11:43'33 Page: 1 i Fieldi Milne Poinl ~ Reference Site: M Pt C Pad Co-ordinate(NE) Reference: Well: MPC-43, True North Reference Well: ' MPC-43 Vertical (TVI)) Reference: MPC-43: 51.1 ;;Reference Wellpath: Plan 3, MPC-43L1 llb: 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: 13379.14 to 15585.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1755.03 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/17/2008 Validated: No Planned From To Survey ft ft 81.00 632.00 MPC-43 GYRO (81.00-632.00) (0) 653.60 13379.14 MPC-43 (653.60-13744.68) (0) 13379.14 15585.00 Planned: Plan #3 V3 Casing Points MD TVD Diameter ft ft in 15585.00 7341.42 3.500 - - -. Versron: 0 Toolcode Tool Name CB-GYRO-SS Camera based gyro single shots MWD+IFR+MS MWD +IFR + Multi Station ~ , MWD MWD -Standard 1 Hole Size Name in 4.125 3.5" 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 CPad MPC-25 MPC-25 V1 Out of range M Pt C Pad MPC-43 MPC-43 V7 13400.00 13400.00 0.00 233.85 -233.85 FAIL: Major Risk M Pt C Pad MPC-43 Plan 3, MPC-43L1-01 VO 13649.10 13650.00 7.18 355.37 -348.19 FAIL: Major Risk M Pt L Pad MPL-16 MPL-16 V2 15375.00 14800.00 849.54 304.35 545.18 Pass: Major Risk Site: M Pt C Pad Well: MPC-43 Rule Assigned: Major Risk Wellpath: MPC-43 V7 Inter-Site Error: 0.00 ft 1eference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVI)" Ref "Offset TFO+AZI TFO-HS Casing/HSUistancc Area- Deviation Warning ft ft` ft ft ft ft deg deg , in ft ft ft 13400.00 7133.70 13400.00 7133.70 56.79 57.80 342.46 0.00 4.500 0.00 233.85 -233.85 FAIL 13425.00 7158.29 13425.00 7158.29 56.82 57.81 342.20 0.00 4.500 0.00 233.32 -233.32 FAIL 13450.00 7182.94 13450.00 7182.94 56.85 57.83 341.89 0.00 4.500 0.00 232.77 -232.77 FAIL 13475.00 7207.60 13475.00 7207.64 56.88 57.84 162.68 180.93 4.500 0.24 93.83 -93.60 FAIL 113499.65 7231.49 13500.00 7232.37 56.93 57.86 162.10 180.35 4.500 2.70 101.87 -99.17 FAIL 13522.71 7252.54 13525.00 7257.12 56.99 57.88 161.89 180.14 4.500 9.52 110.18 -100.66 FAIL 13543.43 7269.95 13550.00 7281.89 56.99 57.81 159.68 183.36 4.500 20.08 114.63 -94.55 FAIL 13561.53 7283.84 13575.00 7306.67 56.72 57.46 155.24 184.55 4.500 33.43 117.89 -84.46 FAIL 13576.88 7294.47 13600.00 7331.48 56.29 56.96 151.35 184.42 4.500 49.12 121.58 -72.46 FAIL 13589.70 7302.44 13625.00 7356.30 55.82 56.41 148.24 183.97 4.500 66.69 124.29 -57.60 FAIL 13600.38 7308.38 13650.00 7381.14 55.35 55.88 145.78 183.47 4.500 85.73 125.73 -40.00 FAIL 13609.28 7312.84 13675.00 7405.99 54.91 55.39 143.81 183.01 4.500 105.91 126.23 -20.32 FAIL 13616.77 7316.21 13700.00 7430.85 54.52 54.95 142.19 182.58 4.500 126.93 126.17 0.77 Pass 13626.56 7320.29 13725.00 7455.72 54.30 54.68 140.95 182.14 4.500 148.48 126.66 21.82 Pass 13636.12 7324.12 13750.00 7480.59 54.11 54.42 139.90 181.80 4.500 170.27 127.44 42.84 Pass 13645.11 7327.59 13775.00 7505.46 53.92 54.17 138.97 181.53 4.500 192.28 131.94 60.34 Pass 13653.59 7330.75 13800.00 7530.33 53.74 53.93 138.13 181.31 4.500 214.46 136.36 78.11 Pass 13659.07 7332.73 13817.00 7547.24 53.62 53.77 137.61 181.18 4.500 229.65 139.32 90.33 Pass Site: M Pt C Pad Well: MPC-43 Rule Assigned: Major Risk Wellpath: Plan 3, MPC-43L1-01 VO Plan: Plan #3 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable ~I MD TVD MD TVD Ref Offset ' TFO+A21 TFO-HS Casing/HSflistance Area Deviation Warning ft ft` ft ft ft ft deg `' deg in ft ft J ft 13400.00 7133.70 13400.00 7133.70 56.79 56.83 342.46 0.00 0.00 233.70 -233.70 FAIL 13425.00 7158.29 13425.00 7158.29 56.82 56.86 342.20 0.00 0.00 233.15 -233.15 FAIL -- ~ - -- _ _ z -}~, ~ BP Alaska ! B~~N~ by s Anticollision Report iNTEQ Company:.. QP Amoco Date: 10/20!2008 Time 1.1:43:33 Page:: 2 Field: Milne Point Reference Site. M Pt C Pad Co-ordinate(NE) Reference: Well: MPC-43, True North Reference Well: MPC-43 Vertical (TVD) Reference: MPC-43: 51.1 .Reference Wellpath: Plan 3, MPC-43L1 Db; Oracle Site: M Pt C Pad Well: MPC-43 Rule Assigned: Major Risk Wellpath: Plan 3, MPC-43L1-01 VO Plan: Plan #3 V2 Inter-Site Error: 0.00 ft Reference Offset ..Semi-Major Axis Ctr-Ctr No-Go Albwable MD TVll MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Arca Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13450.00 7182.94 13450.00 7182.94 56.85 56.89 341.89 0.00 0.00 232.59 -232.59 FAIL 13475.00 7207.60 13475.00 7207.60 56.88 56.92 341.75 0.00 0.00 233.17 -233.17 FAIL 13500.00 7231.82 13500.00 7231.82 56.93 56.96 341.75 0.00 0.00 237.95 -237.95 FAIL 13525.00 7254.55 13525.00 7254.55 57.00 57.04 341.75 0.00 0.00 242.80 -242.80 FAIL (13550.00 7275.15 13550.00 7275.15 56.93 56.97 334.09 0.00 0.00 246.08 -246.08 FAIL ~ 13575.00 7293.23 13575.00 7293.23 56.35 56.40 327,36 0.00 0.00 249.95 -249.95 FAIL 13600.00 7308.18 13600.00 7308.18 55.37 55.40 322.38 0.00 0.00 248.89 -248.89 FAIL 13624.83 7319.58 13625.00 7320.38 54.34 54.37 73.83 114.89 2.10 345.10 -343.00 FAIL 13649.10 7329.09 13650.00 7330.41 53.84 53.87 58.57 101.42 7.18 355.37 -348.19 FAIL 13672.69 7337.43 13675.00 7337.74 53.31 53.34 46.80 91.33 14.16 351.77 -337.61 FAIL 13695.68 7344.68 13700.00 7341.89 52.77 52.80 36.39 82.51 22.38 341.54 -319.16 FAIL 13717.95 7350.85 13725.00 7342.81 52.21 52.25 27.33 74.96 32.09 328.18 -296.09 FAIL 13740.18 7356.17 93750.00 7342.42 51.64 51.68 21.36 70.46 42.14 318.08 -275.94 FAIL 113762.88 7360.72 13775.00 7342.13 51.04 51.08 17.86 68.44 51.43 312.76 -261.33 FAIL 13785.95 7364.42 13800.00 7341.94 50.43 50.45 15.63 67.68 59.80 310.30 -250.50 FAIL 13809.33 7367.22 13825.00 7341.83 49.81 49.81 14.16 67.69 67.19 309.60 -242.40 FAIL 13832.93 7369.05 13850.00 7341.89 49.19 49.18 13.29 68.30 73.57 310.03 -236.46 FAIL 13856.63 7369.89 13875.00 7342.15 48.58 48.55 12.93 69.42 78.93 311.10 -232.17 FAIL 13878.60 7369.95 13900.00 7342.62 47.49 47.46 12.22 70.89 83.47 307.87 -224.39 FAIL 13899.55 7369.97 13925.00 7343.29 46.11 46.07 11.12 72.30 87.79 301.73 -213.94 FAIL 13920.36 7370.00 13950.00 7344.04 44.64 44.60 9.91 73.59 91.93 294.73 -202.80 FAIL 13941.04 7370.05 13975.00 7344.78 43.11 43.07 8.56 74.72 95.91 286.98 -191.07 FAIL 13961.60 7370.12 14000.00 7345.53 41.52 41.47 7.09 75.72 99.71 278.58 -178.87 FAIL 13982.05 7370.20 14025.00 7346.26 39.88 39.83 5.52 76.61 103.32 269.63 -166.31 FAIL 14002.39 7370.29 14050.00 7346.99 38.18 38.12 3.87 77.39 106.73 260.20 -153.47 FAIL 14022.65 7370.40 14075.00 7347.71 36.44 36.38 2.13 78.09 109.92 250.32 -140.40 FAIL 14042.82 7370.52 14100.00 7348.42 34.66 34.59 0.33 78.71 112.88 240.07 -127.19 FAIL 14062.91 7370.66 14125.00 7349.11 32.84 32.77 358.47 79.26 115.62 229.52 -113.90 FAIL '~ 14082.93 7370.80 14150.00 7349.78 31.00 30.93 356.56 79.75 118.11 218.72 -100.61 FAIL 14102.89 7370.96 14175.00 7350.44 29.15 29.07 354.60 80.18 120.37 207.72 -87.36 FAIL 14122.80 7371.14 14200.00 7351.00 27.29 27.20 352.56 80.53 122.40 196.58 -74.18 FAIL 14142.66 7371.32 14225.00 7351.21 25.44 25.35 350.33 80.69 124.28 185.39 -61.11 FAIL 14162.38 7371.52 14250.00 7351.20 23.63 23.55 348.07 80.79 126.98 174.27 -47.29 FAIL 14194.51 7371.80 14275.00 7351.19 26.79 26.71 351.53 80.94 130.88 193.58 -62.70 FAIL 14228.72 7371.97 14300.00 7351.00 30.68 30.60 355.71 81.02 134.32 216.96 -82.64 FAIL 14263.34 7372.01 14325.00 7350.37 34.56 34.48 -0.23 80.93 137.26 240.08 -102.81 FAIL 14298.30 7371.92 14350.00 7349.30 38.36 38.28 3.71 80.68 139.68 262.59 -122.91 FAIL 14333.49 7371.67 14375.00 7347.93 41.98 41.90 7.53 80.35 141.59 284.07 -142.48 FAIL 14368.80 7370.73 14400.00 7346.39 45.35 45.26 11.36 80.19 142.98 304.37 -161.39 FAIL 14404.32 7368.92 14425.00 7344.67 48.55 48.46 15.53 80.28 143.86 323.56 -179.70 FAIL 14440.00 7366.77 14450.00 7342.79 . 51.57 51.48 19.94 80.41 144.20 341.43 -197.23 FAIL 14475.69 7364.49 14475.00 7340.74 54.33 54.23 24.30 80.48 144.00 357.69 -213.69 FAIL 14511.30 7362.11 14500.00 7338.53 56.77 56.68 28.60 80.50 143.24 372.05 -228.80 FAIL 14546.48 7359.66 14525.00 7336.29 58.91 58.81 32.73 80.40 140.44 384.42 -243.98 FAIL 14580.43 7357.22 14550.00 7334.10 60.66 60.57 36.50 80.08 134.60 394.37 -259.77 FAIL 14605.05 7355.42 14575.00 7331.97 61.05 60.96 36.14 79.27 126.31 396.00 -269.69 FAIL 14623.64 7354.10 14600.00 7329.90 60.53 60.43 32.72 78.08 117.51 392.03 -274.53 FAIL 14642.41 7352.83 14625.00 7327.90 59.91 59.82 29.07 76.68 108.45 387.17 -278.71 FAIL 14661.49 7351.59 14650.00 7325.98 59.21 59.11 25.15 75.05 99.46 381.41 -281.95 FAIL 14681.43 7350.35 14675.00 7324.17 58.37 58.27 21.20 73.50 92.31 374.86 -282.55 FAIL 14702.12 7349.10 14700.00 7322.49 57.42 57.31 17.46 72.24 87.38 367.93 -280.56 FAIL ~'~~ , BP Alaska ~ BAK Rr~ by liw+~li~s ""~ Anticollision Report INTEQ Company: BP Amoco Date: 10/20/2008. Time:. 11:43:33 Page: 3 Field: Milne Point Reference Site: M Pt C Pad Co-ordinate(NE) Reference: WeIE MPC-43, True North Reference Well: MPC-43 Vertical (TVD) Reference: MPC-43: 51:1 .Reference Wellpath: Plan 3 MPC-43L1 1)b: Oracle Site: M Pt C Pad Well: MPC-43 Wellpath: Plan 3, MPC-43L1-01 VO Plan: 'Reference Offset MD TVD MD TVD ft ft ft ft Plan #3 V2 Semi-Major Axis Ref Offset. ft ft FO+AZI deg FO-HS deg Rule Assigned: Inter-Site Error: Ctr-Ctr No-Go Casjng/HSflistance Area in ft ft Major Risk 0.00 ft Allowable Deviation Warning ft 14723.28 7347.85 14725.00 7320.93 56.34 56.23 14.11 71.43 84.68 360.87 -276.19 FAIL 14744.65 7346.63 14750.00 7319.54 55.14 55.03 11.26 71.15 83.95 353.90 -269.95 FAIL i 14766.04 7345.45 14775.00 7318.62 53.85 53.75 8.73 71.18 83.30 346.80 -263.49 FAIL 1 14787.45 7344.32 14800.00 7318.05 52.47 52.37 6.37 71.39 82.45 339.36 -256.91 FAIL 14808.88 7343.23 14825.00 7317.57 51.00 50.90 4.01 71.60 81.41 331.36 -249.95 FAIL 14830.34 7342.20 14850.00 7317.19 49.45 49.34 1.63 71.81 80.19 322.81 -242.62 FAIL 14851.84 7341.21 14875.00 7316.90 47.82 47.70 359.26 72.01 78.79 313.75 -234.96 FAIL 14873.34 7340.29 14900.00 7316.70 46.11 46.00 356.90 72.19 77.21 304.03 -226.82 FAIL 14894.85 7339.59 14925.00 7316.60 44.35 44.24 354.47 72.26 75.48 293.52 -218.04 FAIL 14916.44 7339.14 14950.00 7316.56 42.52 42.42 352.09 72.38 74.60 282.64 -208.04 FAIL 14937.99 7338.95 14975.00 7316.52 40.65 40.55 350.07 72.86 76.09 271.74 -195.66 FAIL 14959.20 7339.01 15000.00 7316.49 38.77 38.67 348.39 73.63 79.94 260.96 -181.02 FAIL 14986.28 7339.31 15025.00 7316.45 40.81 40.73 351.20 74.47 85.43 273.09 -187.66 FAIL 15015.96 7339.65 15050.00 7316.41 44.20 44.11 355.46 75.17 90.81 293.03 -202.23 FAIL 15046.12 7340.00 15075.00 7316.37 47.51 47.41 -0.35 75.74 95.95 312.54 -216.59 FAIL 15076.94 7340.35 15100.00 7316.35 50.72 50.61 3.70 76.09 99.83 331.39 -231.57 FAIL 15108.33 7340.70 15125.00 7316.38 53.78 53.68 7.42 76.05 100.87 349.09 -248.22 FAIL 15139.62 7341.04 15150.00 7316.45 56.65 56.53 10.76 75.63 99.05 365.15 -266.10 FAIL 15170.22 7341.30 15175.00 7316.57 59.22 59.10 13.61 74.81 94.40 379.05 -284.64 FAIL 15199.45 7341.46 15200.00 7316.73 61.47 61.34 15.80 73.50 87.07 390.15 -303.08 FAIL 15226.84 7341.51 15225.00 7316.94 63.37 63.24 17.04 71.46 77.28 397.59 -320.31 FAIL 15248.47 7341.51 15250.00 7317.19 63.31 63.17 13.46 68.61 66.68 391.72 -325.05 FAIL 15269.24 7341.51 15275.00 7317.49 62.36 62.24 7.96 65.60 58.14 379.95 -321.81 FAIL 15291.02 7341.50 15300.00 7317.83 61.27 61.15 2.57 62.82 51.83 367.39 -315.56 FAIL 15313.55 7341.49 15325.00 7318.21 60.03 59.91 357.85 60.81 47.73 355.74 -308.01 FAIL 15336.51 7341.49 15350.00 7318.62 58.65 58.53 354.36 60.07 45.82 346.79 -300.97 FAIL 15359.57 7341.48 15375.00 7319.03 57.15 57.03 352.38 60.86 46.10 341.25 -295.15 FAIL 15382.38 7341.47 15400.00 7319.44 55.56 55.44 351.82 63.04 48.60 338.24 -289.64 FAIL 115404.62 7341.47 15425.00 7319.84 53.92 53.80 352.23 66.11 53.40 335.88 -282.48 FAIL 15425.98 7341.46 15450.00 7320.24 52.26 52.14 353.03 69.48 60.53 332.58 -272.05 FAIL 15446.23 7341.46 15475.00 7320.64 50.61 50.49 353.81 72.69 69.97 327.73 -257.77 FAIL 15465.16 7341.45 15500.00 7321.02 49.00 48.90 354.35 75.50 81.59 321.58 -239.99 FAIL 15482.64 7341.45 15525.00 7321.40 47.49 47.38 354.60 77.85 95.24 314.68 -219.45 FAIL 15506.80 7341.44 15550.00 7321.77 49.86 49.75 358.88 79.71 110.08 329.76 -219.68 FAIL Site: M Pt L Pad Well: MPL-16 Rule Assigned: Major Risk Wellpath: MPL-16 V2 Inter-Site Error: 0.00 ft Reference _ Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offsek TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 15567.34 7341.43 14125.00 6437.64 56.39 47.86 303 00 16.56 942.92 184.07 758.85 Pass 15543.12 7341.43 14150.00 6451.64 53.87 52.18 301.40 17.87 934.90 188.81 746.09 Pass 15514.18 7341.44 14175.00 6465.81 50.69 57.22 299.22 19.16 926.99 193.82 733.16 Pass 15483.57 7341.45 14200.00 6480.17 47.41 62.03 297.07 20.43 919.08 198.96 720.12 Pass 15476.34 7341.45 14225.00 6494.71 48.05 60.94 299.22 21.71 911.37 203.52 707.86 Pass 15469.44 7341.45 14250.00 6509.41 48.64 59.88 301.35 23.02 904.00 208.18 695.83 Pass 15462.87 7341.45 14275.00 6524.28 49.20 58.86 303.48 24.35 897.00 212.93 684.07 Pass 15456.60 7341.45 14300.00 6539.31 49.74 57.89 305.60 25.72 890.37 217.77 672.60 Pass 15450.61 7341.46 14325.00 6554.52 50.25 56.95 307.71 27.12 884.11 222.66 661.46 Pass 15444.89 7341.46 14350.00 6569.94 50.72 56.04 309.82 28.54 878.21 227.57 650.64 Pass 4~+'A': ~ BP Alaska ~ BAKER' by HUGHES +'~ Anticollision Report LNTEQ Company: BP AMOCO "Field:: Milne Poinf (..Reference Site: M Pt'C Pad Reference Well: MPC-43 Reference Wellpat66 Plan 3, MPC-43L1 Site: M Pt L Pad Well: MPL-16 Wellpath: MPL-16 V2 Reference Offset MD TVD MD TVD ft ft. ft ft ml-MajorAxis Ref Offset ft ft Date: 10/20/2008 Time: 11:43:33 ' Page: 4 Caordinate(NE) Reference: Weil: MPC-43, True North Vertical (TVD) Reference:. MPC-43: 51.1 Ub: Oracle Rule Assigned: Major Risk Inter-Site Error: 0.00 ft Ctr-Ctr No-Go Allowable TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning deg deg in ft ft ft 15439.42 7341.46 14375.00 6585.54 51.17 5517 31192 29.98 872.68 232.51 640.18 Pass 15434.18 7341.46 14400.00 6601.35 51.59 54.34 314.02 31.45 867.54 237.45 630.09 Pass 15429.17 7341.46 14425.00 6617.34 52.00 53.53 316.11 32.94 862.80 242.38 620.42 Pass 15425.00 7341.46 14450.00 6633.52 52.34 52.86 318.12 34.45 858.49 247.36 611.13 Pass 15419.85 7341.46 14475.00 6649.90 52.74 52.02 320.27 35.98 854.61 252.14 602.47 Pass 15415.51 7341.46 14500.00 6666.46 53.08 51.32 322.34 37.53 851.18 256.94 594.24 Pass 15411.35 7341.47 14525.00 6683.20 53.40 50.64 324.41 39.10 848.20 261.66 586.54 Pass 15407.34 7341.47 14550.00 6700.10 53.71 49.98 326.47 40.68 845.69 266.28 579.40 Pass 15403.47 7341.47 14575.00 6717.18 54.01 49.35 328.52 42.27 843.64 270.79 572.84 Pass i 15400.00 7341.47 14600.00 6734.42 54.28 48.78 330.54 43.87 842.06 275.22 566.84 Pass I 15396.15 7341.47 14625.00 6751.81 54.56 48.14 332.61 45.48 840.98 279.39 561.59 Pass 15392.71 7341.47 14650.00 6769.35 54.81 47.58 334.64 47.10 840.44 283.47 556.97 Pass 15389.42 7341.47 14675.00 6787.03 55.05 47.03 336.66 48.72 840.43 287.39 553.03 Pass 15386.26 7341.47 14700.00 6804.86 55.28 46.52 338.67 50.35 840.96 291.15 549.80 Pass 15383.23 7341.47 14725.00 6822.78 55.50 46.02 340.66 51.98 842.09 294.73 547.36 Pass ~ 15380.31 7341.47 14750.00 6840.74 55.72 45.54 342.64 53.60 843.90 298.12 545.78 Pass ~~ 15375.00 7341.48 14775.00 6858.73 56.10 44.62 344.89 55.22 846.39 300.73 545.66 Pass 15375.00 7341.48 14800.00 6876.77 56.10 44.67 346.51 56.84 849.54 304.35 545.18 Pass 15375.00 7341.48 14825.00 6894.83 56.10 44.72 348.11 58.44 853.37 307.78 545.59 Pass 15369.59 7341.48 14850.00 6912.93 56.47 43.78 350.35 60.03 857.86 309.57 548.29 Pass 15367.15 7341.48 14875.00 6931.05 56.64 43.39 352.22 61.60 863.03 311.89 551.13 Pass 15364.81 7341.48 14900.00 6949.21 56.80 43.01 354.05 63.16 868.85 314.01 554.84 Pass 15362.54 7341.48 14925.00 6967.38 56.95 42.64 355.86 64.70 875.31 315.91 559.40 Pass 15360.32 7341.48 14950.00 6985.57 57.10 42.28 357.64 66.21 882.41 317.60 564.81 Pass 15358.16 7341.48 14975.00 7003.76 57.25 41.93 359.39 67.70 890.12 319.07 571.05 Pass 15356.05 7341.48 15000.00 7021.96 57.39 41.60 1.11 69.17 898.44 320.35 578.09 Pass 15350.00 7341.48 15025.00 7040.17 57.80 40.54 3.27 70.60 907.37 320.17 587.20 Pass 15350.00 7341.48 15050.00 7058.39 57.80 40.59 4.69 72.01 916.85 321.69 595.16 Pass 15350.00 7341.48 15075.00 7076.61 57.80 40.63 6.07 73.40 926.91 323.04 603.87 Pass 15350.00 7341.48 15100.00 7094.84 57.80 40.68 7.42 74.75 937.53 324.23 613.30 Pass 15350.00 7341.48 15125.00 7113.09 57.80 40.72 8.74 76.07 948.70 325.25 623.44 Pass 15344.74 7341.48 15150.00 7131.38 58.13 39.81 10.66 77.36 960.35 324.25 636.11 Pass 15343.16 7341.48 15175.00 7149.70 58.23 39.57 12.12 78.63 972.53 324.39 648.14 Pass ~ 15341.68 7341.48 15200.00 7168.06 58.32 39.34 13.53 79.86 985.20 324.43 660.77 Pass 15340.26 7341.49 15225.00 7186.45 58.41 39.13 14.91 81.07 998.29 324.35 673.94 Pass 15338.85 7341.49 15250.00 7204.90 58.50 38.92 16.25 82.24 1011.74 324.15 687.59 Pass 15337.46 7341.49 15275.00 7223.40 58.59 38.71 17.56 83.39 1025.55 323.84 701.70 Pass 15336.07 7341.49 15300.00 7241.95 58.68 38.50 18.85 84.51 1039.68 323.43 716.25 Pass 15334.67 7341.49 15325.00 7260.56 58.76 38.29 20.11 85.60 1054.11 322.93 731.19 Pass i 15333.24 7341.49 15350.00 7279.24 58.85 38.08 21.34 86.66 1068.78 322.32 746.47 Pass 15331.78 7341.49 15375.00 7297.99 58.95 37.87 22.56 87.70 1083.68 321.61 762.07 Pass 15325.00 7341.49 15400.00 7316.80 59.37 36.73 24.38 88.71 1098.85 318.73 780.12 Pass 15325.00 7341.49 15425.00 7335.72 59.37 36.77 25.37 89.70 1114.14 318.45 795.69 Pass 15325.00 7341.49 15450.00 7354.78 59.37 36.81 26.34 90.67 1129.61 318.10 811.51 Pass 15325.00 7341.49 15475.00 7373.97 59.37 36.85 27.30 91.63 1145.24 317.70 827.54 Pass ~ 15325.00 7341.49 15500.00 7393.30 59.37 36.90 28.23 92.56 1161.03 317.25 843.78 Pass 15325.00 7341.49 15525.00 7412.77 59.37 36.94 29.14 93.47 1176.96 316.75 860.21 Pass 15325.00 7341.49 15550.00 7432.39 59.37 36.98 30.04 94.37 1193.02 316.20 876.82 Pass 15325.00 7341.49 15575.00 7452.14 59.37 37.02 30.92 95.25 1209.19 315.61 893.58 Pass 15325.00 7341.49 15600.00 7472.03 59.37 37.06 31.79 96.12 1225.48 314.98 910.50 Pass 15317.63 7341.49 15625.00 7492.08 59.79 35.76 33.52 96.97 1241.78 310.43 931.36 Pass ,r „~~';•~ ~ BP Alaska ~ BAKER ~ . by HY~iNES "'hE`` Anticollision Report INTEQ Company: BP Amoco Date: 10/20/2008'. Time: 11;43;33 Pagc: 5 ', Field: Milne Point Reference Site: M Pt C Pad Co-ordlnate(NE) Reference: Well: MPC-43, True North j Reference Well: MPC-43 Vertical (1'VD) Reference: MPC-43'51.1 ~ Reference Wellpath: Plan 3; MPC-43L1 Db: Oracle:. Site: M Pt L Pad Well: MPL-16 Rule Ass igned: Major Ris k Wellpath: MPL-16 V2 Inter-Site Error: 0.00 ft "Reference Offset Semi-Major Axis Ctr-Ctr No-Gu Allowable MD TVD MD TVD ' Ref .Offset TFO+AZI TFO-IiS Casing/HSDiskance Area Deviation Warning ft ft" ft ft ft ft deg deg in ft ft ft 15316.34 7341.49 15650.00 7512.32 59.87 35.49 34 51 97.80 1258.20 308.32 949.87 Pass 15315.07 7341.49 15675.00 7532.72 59.94 35.28 35.49 98.63 1274.67 306.82 967.84 Pass 1 15313.76 7341.49 15700.00 7553.23 60.02 35.07 36.46 99.44 1291.20 305.34 985.86 Pass 15312.44 7341.49 15725.00 7573.88 60.09 34.86 37.41 100.24 1307.75 303.82 1003.93 Pass 15311.08 7341.49 15750.00 7594.69 60.17 34.65 38.36 101.02 1324.29 302.26 1022.03 Pass 15309.70 7341.49 15775.00 7615.65 60.25 34.43 39.31 101.80 1340.79 300.66 1040.13 Pass 15308.28 7341.49 15800.00 7636.76 60.33 34.21 40.24 102.57 1357.25 299.02 1058.23 Pass 15306.82 7341.49 15825.00 7657.99 60.41 33.99 41.17 103.32 1373.70 297.35 1076.35 Pass 15300.00 7341.50 15850.00 7679.28 60.81 33.00 42.73 104.06 1390.23 293.29 1096.94 Pass 15300.00 7341.50 15875.00 7700.61 60.81 33.00 43.46 104.79 1406.83 292.24 1114.60 Pass 15300.00 7341.50 15900.00 7721.93 60.81 33.00 44.17 105.50 1423.68 291.18 1132.50 Pass L15300.00 7341.50 15912.00 7732.17 60.81 33.00 44.50 105.83 1431.85 290.12 1141.73 Pass • Rig Floor to Top of Lubricator Weil MPC-43L1 2.25 9.23 ffydril Annular 7 1,•'16" Annular x 5000 psi 5.00 • 7 1;16" 5000 psi, RX-46 Blind Shears 12.65 r~ roT 13.56 z-a a" Combi's 21116" 5000 psi , R-24 Mud Cross HCR M Mudf~Irs _'; 14.69 Choke Line 16.10 ~- zs~•x~~z' Variable Ram 16.66 ~ ;' 2-3.~8" Combi TOT SSV Master Valve Lock Down Screws Ground Level 6050000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6000000 5950000 5900000 5850000 '- 4 0000 sooooo u 500000 600000 700000 i ~ TRANSMITTA~7L LETTER CIiE2CKLIST WELL NAME ~~// ~ `- r ~`~ ~( PTD# tog /GS v Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL new ~Ilborg. se ent of existing The permit i~~ ~~ well ~ ' (If last two digits in Permit No. ~C.~ ~-v API No. 50-~~ - Z 3 ~ - ~ API number are production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- _) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Atl dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for jpame of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~,~ompanv Name) must contact the Commission to obtain advance approval of such water well testing ro m. Rev: 7/132007 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT KR G43L1 Program DEV Well bore seg ^~ PTD#:2081650 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unrf 11328 On1Off Shore On Annular Disposal ^ Administration 1 Petmitfeeattached- --------- ---- --- -- - ---- NA- -- - ---- -- -- --- - ------ ---- --- - -- - ----- 2 Lease number approRnate______-__-___--------------- ---- ------Yes---- -._Top_Ptoductfveinten!al andTD_inADl3;i5Q17..-------------------------------------- 3 Unique well-name andnumbe[----- -- -- - --- Yes - --- --- -- ----- - ----- - -- -- -- ----- 4 Wfllllocatedfn-a-defined-pool__________________-__--____ _--_______Yes____ ___i<upatukftiverOilPool,govemed by ConservationOrde[NO.4320_____-..______-__.__________ 5 Well located Droper distance from dolling urlit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ Conservation Order No. 4~2C contains no spacing restrictions wish respect to drilling unit boundaries. _ - - _ _ _ _ 6 Well located proper distance from other wel_Is_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ Conservation Order No. 4~2C has no interwelispaeingresirictions, _ - _ _ - _ _ _ _ _ _ - . _ - - _ . _ _ _ _ _ _ 7 Sufficient acreage available indrilling unJl_ _ _ - _ _ _ - - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ -Conservation Order No. 4020 has no intenveli-spacingrestrictions, Wslibore-will be.more than 500' from _ _ - _ 8 If deviated, is wellbore plat.includad _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes an external property line_where-ownership orlandownersh~ changes. - - _ _ - - _ _ _ _ _ - - - _ - _ _ _ _ _ _ 9 Operakororlyaffededparty ----- --- -- -- - --- -Yes ---- --- ------- --- --- - --- - --- - -- -- 10 Operator bas_appropriafebond in f2rCe - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Petmitcan5eissuedwithoutconserYatlcnorder----------------- -----------Yes---- -------------------------------------------------------------- ---- Appr Date 12 Petmitcanbeissuedwithoutadministcative_approval-------------- -----------Yes--- ------------------.------------------------------------------------ D 10123!2008 13 14 CaDPermit_beaRRrevedbeforel5-daywait-------------------------------Yes---- Well located within area and strataauthorizedby_InjeCtionOtder-#(putlQ#in-comments)_(For_NA-___ ------------------------------------------------------------ --- .-_ ___________________________________________-_______-- -___ -- 15 Allwelis_within114_mileareaofrev~wident~ed(Fo[servicewellonly)____ ___________ NA____ : _^ ____-__.--__--________._______-___-_____-__-_-_______ 16 Pte-Aroducedinlector; duration ofPre~toduCtionlessthan3months(ForservicewellonJy)__-NA_____ __--__-__--________--___--------------------------------- ---- 17 NonCanven,gas_conforms io AS31,05,03Q(1.t.A),U.2.A-D) - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - Englneering 18 Conductorstring.prQVided----------------------------- ---------- NA____ -_CcnduGtorsQi-inMPC-43~204~039),--------------------.----------------------- 19 SurfacecasingproieotsallknownU$DWS__________________ __---._____ NA_____ ___Allaqurfersexempted,40CFR-147.1Q2(b)(3)and_AEO2._--______-___-__-____-_--_______ 20 CMTvoladegUate_tooirculateon_conductor8surf-csg--________-- ___-____--tdA_____ _--Surface Casing set in MPC-40____________________--______-___-------__-_-- 21 CMT_voladeguate-torte-in long string tosurfos9__--____-___- ___________ NA___- ___Production-oasingset in-MPC-43______________________---____.___--___-__-_____ 22 CMT_willcoverallkoownproduCiivehorizons__-_______________ ___________ No___ ___SlotiedlinercomRlettonplanned._______________________--_______-__________-_ 23 Casing des~ns adequate for C, T, B & permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ _ _ . Original well-met design speCificaiions. - NA for slotted liner.- - _ _ _ _ - _ _ _ . - _ _ - _ _ _ _ _ _ _ _ _ _ - _ . _ _ 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - -Yes _ _ _ - _ . _ Rig equipped wlth steel pits. No reserve pit planned._ All waste_to approved disposal well(s), _ . - - _ _ _ _ _ _ _ _ 25 Ifa_re-drill,has_a10-40Sfora4andonmentbeenapproved---------- ----------- NA----- ---------------------------------------------------------------------- 26 Adequate weilbore separatonproposed _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - Pr_oximfty analysis performed, Nearest segment is retained podion of MP_C-4$and paths diverge, - _ _ _ _ _ _ _ _ _ 27 If diverterrequired,doesitmeetregulations-__--____________ -__.____--NA-_--- --_BOPStack_willalready_beinplaCe,____--____---____--__-__.-----------_ -- Appr Date 28 Dulling fluid- program schematic & equip list adaquate_ - - _ _ - _ _ _ - _ _ _ _ _ _ - _ _ Yes _ _ _ _ _ _ Maximum expected formation pressure 5,9_ EMW._ MW planned $.$ Rp9• _Managed-pressure drilling will_be employ TEM 111512008 29 BO-PEs,_do.they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ - _ . - A surface Choke will hold pressure_when needed topteyent fiex~ng of shales.- - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPS-Press rating appropriate; lest to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ . _ _ _ _ _ _ _ _ . _ _ _ _ - _ _ _ . _ _ _ - _ _ _ _ _ _ MASP calculated at 1439psi, 3500_psi_BOP testplanned, 31 Choke-manifgldCQmplieswlAPl_RP-53(May$4)________________ ___________Yes____ _ _ _ _ : ____-__--__-____-__-- 32 Work willoccurwithoutoperationshutdown-------------------- -------- --Yes---- -------------------------------------------------------------------- 33 )s presence of H2S gas prgbable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - _ _ _ _ _ _ _ - _ Yes _ . - _ _ _ _ 510 ppm H2S repoRed at MPC.-Mud should preclude-H2S-on rig._ Rig has sensors and-alarms._ _ _ _ _ _ _ _ _ _ 34 _Mechanical.condltionofweliswithinAQRyerified(FOrservlcewellorly)-- ----------- NA----- ----------------------------------------------------- -- Geology 35 Pe[mitoan be issued wlo hYdrogensulfide meas~+tes _ _ - _ _ - - _ _ - _ _ _ _ _ _ - _ _ No_ _ _ _ _ _ _ _ Parent wellbore measured 5 ppm H2S; measures_rQquired _ _ _ _ _ _ - - _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 Data-preserted on potential overRressurezones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ - Reservoir pressure depleted to about 6ppg; willbe drilled-with a coifed tubing rig - - _ _ - . _ . - _ _ _ _ _ _ _ _ _ Appr Date 37 Seismic analysis ofshaliewgaszones______________.__--__ -_._-____._ NA____ ___usingmanagedpressUredritlingfechriques.-_____________:___-__-_______-__.-___-.- SFD 1012312008 38 Seabed_c4nditionsuryey.(ifoff-shore).-- - --- --- -- -- - ---- ~A- -- ---- - ----- --- - ------ ------ -- -- --- - ----- 39 CaniaCtnamelphoneforwQekiy_prog_ressrepo~ls_[explotatoryon~]----- ----------- NA----- -- -----------------------------------.---------_---------------------- Geobgic Date: Engineering Date Public ' ' Daie Multilateral well bare to produce from Kuparuk A2 and A3. Commissioner: si ssioner: Comm Com t ~~~~v ~~-s-~ !l S-~g Welt History File APPENDIX Information of detailed nature that is not I-.._I 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 effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 09/03/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/01/05 2368042 Ol 3" CTK *** LIS COMMENT RECORD *** !!~!!~~!!!!!!!!!!!! Remark File Version 1.000 ~~~~~~~~~!~!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 13090.0000: Starting Depth STOP.FT 15501.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPC-43L1 FLD FIELD: Milne Point Unit LOC LOCATION: 70 deg 29' 29.606"N 149 deg 31' 28.074"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 05 Jan 2009 API API NUMBER: 500292320060 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 10 TOWN.N T13N RANG. R10E PDAT. MSL EPD .F 0 LMF DF FAPD.F 51.1 DMF DF EKB .F 0 EDF .F 51.1 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~~s-l ~oS ~ ~~"~~~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage (OHMM) (OHMM) (OHMM) (OHMM) surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and any depth shifting has been waived by Dennis Urban with BP Exploration (Alaska), Inc. The MWD is the Primary Depth Control (PDC) log for well MPC-43L1. (8) The sidetrack was drilled from MPC-43 through a milled window in a 4 1/2 inch liner. Top of window 13463 ft.MD (7144.7 ft.TVDS5) Bottom of window 13473 ft.MD (7154.4 ft.TVDSS) (9) Tied to MPC-43 at 13379 feet MD (7062.1 feet TVDSS). (10) Resistivity data from 13470 feet to 13700 feet MD (7151.6 feet to 7286.8 feet TVDSS) was logged 20 hours after drilling on run 5. (11) The interval from 15469 feet to 15501 feet MD (7302 feet to 7302 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 78 records... 10 bytes 132 bytes *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and any depth shifting has been waived by Dennis Urban with BP Exploration (Alaska), Inc. The MWD is the Primary Depth Control (PDC) log for well MPC-43L1. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 134 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 13090.000000 Tape File End Depth = 15501.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 147 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 • . Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-ty pe is: 1 FRAME SPACE = 0. 250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 268 Tape File Start Depth = 13089.750000 Tape File End Depth = 15501.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 281 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/01/05 2368042 01 **** REEL TRAILER **** MWD 09/03/12 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 13090.0000 176.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13090.5000 163.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 137.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 108.8000 49.8000 5.2560 4.9450 4.5900 4.2430 13600.0000 87.8000 49.3000 9.2030 11.0720 10.7990 10.8070 13700.0000 66.9000 87.2000 24.4560 58.5090 58.9550 64.2500 13800.0000 54.2000 71.6000 21.8110 43.2560 49.1380 58.0670 13900.0000 57.6000 77.9000 17.6080 39.5580 41.0730 52.8190 14000.0000 86.4000 68.5000 18.6850 37.3030 42.1970 52.6660 14100.0000 78.2000 48.9000 23.0890 54.1360 46.9460 50.2800 14200.0000 56.7000 103.1000 20.5940 37.8770 48.1120 61.0270 14300.0000 62.1000 134.6000 23.4990 50.9150 52.4590 58.0670 14400.0000 59.7000 117.0000 17.7990 28.8860 35.6300 44.4040 14500.0000 50.6000 112.7000 21.6820 42.9340 49.1380 58.0670 14600.0000 45.1000 131.2000 15.4250 37.8470 61.7710 193.1920 14700.0000 88.9000 140.7000 17.6930 36.6510 50.0740 80.1970 14800.0000 65.7000 97.0000 17.4240 30.3010 39.2670 54.7120 14900.0000 49.2000 66.7000 16.9100 33.8690 s 42.5630 60.7870 15000.0000 55.9000 89.2000 74.7400 140.6040 15100.0000 72.4000 110.5000 32.5190 40.9440 15200.0000 45.2000 99.2000 44.2510 54.5150 15300.0000 85.0000 72.4000 42.5630 43.3750 15400.0000 60.6000 85.9000 38.7960 43.3750 15500.0000 -999.2500 79.8000 -999.2500 -999.2500 15501.0000 -999.2500 79.4000 -999.2500 -999.2500 Tape File Start Depth = 13090.000000 Tape File End Depth = 15501.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 18.7430 16.2730 19.5740 23.5050 20.0440 -999.2500 -999.2500 49.3320 28.9970 38.9300 45.4320 34.7830 -999.2500 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 13089.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13090.0000 176.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 137.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 108.8000 49.8000 5.2560 4.9450 4.5900 4.2430 13600.0000 87.8000 49.3000 9.2030 11.0720 10.7990 10.8070 13700.0000 66.9000 87.2000 24.4560 58.5090 58.9550 64.2500 13800.0000 54.2000 71.6000 21.8110 43.2560 49.1380 58.0670 13900.0000 57.6000 77.9000 17.6080 39.5580 41.0730 52.8190 14000.0000 86.4000 68.5000 18.6850 37.3030 42.1970 52.6660 14100.0000 78.2000 48.9000 23.0890 54.1360 46.9460 50.2800 14200.0000 56.7000 103.1000 20.5940 37.8770 48.1120 61.0270 14300.0000 62.1000 134.6000 23.4990 50.9150 52.4590 58.0670 14400.0000 59.7000 117.0000 17.7990 28.8860 35.6300 44.4040 14500.0000 50.6000 112.7000 21.6820 42.9340 49.1380 58.0670 14600.0000 45.1000 131.2000 15.4250 37.8470 61.7710 193.1920 14700.0000 88.9000 140.7000 17.6930 36.6510 50.0740 80.1970 14800.0000 65.7000 97.0000 17.4240 30.3010 39.2670 54.7120 14900.0000 49.2000 66.7000 16.9100 33.8690 42.5630 60.7870 15000.0000 55.9000 89.2000 74.7400 140.6040 15100.0000 72.4000 110.5000 32.5190 40.9440 15200.0000 45.2000 99.2000 44.2510 54.5150 15300.0000 85.0000 72.4000 42.5630 43.3750 15400.0000 60.6000 85.9000 38.7960 43.3750 15500.0000 -999.2500 79.8000 -999.2500 -999.2500 15501.0000 -999.2500 79.4000 -999.2500 -999.2500 Tape File Start Depth = 13089.750000 Tape File End Depth = 15501.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 18.7430 16.2730 19.5740 23.5050 20.0440 -999.2500 -999.2500 49.3320 28.9970 38.9300 45.4320 34.7830 -999.2500 -999.2500 • Tape Subfile 4 is type: LIS