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Home My WebLink About201-048Imam.,- Project Well History File Coveri'"~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O L- 0 ~--~ Well History File Identifier Organizing ,,~ ~,,,~ [] R?CAN '~ Color items: Grayscale items: Poor Quality Originals: Other: NOTES: ~s, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY ~/Rescan Needed OVERSIZED (Scannable) Maps: [] Other items scannable by large scanner OVERSIZED (Non-.Scannable) [] Logs of various kinds ,/ ~ Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~~NINDY Scanning Preparation , ,/ X 30 = ,__'__~O BY: BEVERLY ROBIN VINCEN'r' SHERYt~~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~'~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES BY: BEVERt~INCENT, SHERYL. MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ................... YES ................ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION tS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO RESCANNEDB~/: BEVERL. Y ROBIN VINCENT SHERYL MARIA WINDY DATE: fst General Notes or Comments about this file: Q u a Ii ty C h e c k e d ~:,;:,~.,:.:~:~,,,,:::: ;, III IIIIIIIIIIIII III 12/10/02Rev3NOTScanned,wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS ~~C ~ ~ 2007 1 Operations Performed: '° ~ •=G'~ . ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Ente~$~3I~d Well i ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other r ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-048 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22808-60-00 ' 7. KB Elevation (ft): 65.68 9. Well Name and Number: MPH-08BL1 ' 8. Property Designation: 10. Field /Pool(s): ADL 380109 Milne Poi nt Unit !Schrader Bluff 11. Present well condition summary Total depth: measured 11510 feet true vertical 4253 feet Plugs (measured) N/A Effective depth: measured 11510 feet Junk (measured) N/A true vertical 4253 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 8557' 7" 8588' 3899' 7240 5410 Intermediate Production 649' 4-1/2" 8436' - 9060' 3793' - 4150' 8430 7500 Liner 2352' 2-7/8" 9030' - 11485' 4143' - 4252' 13450 13890 Perforation Depth MD (ft): Slotted 9106' - 11450' Perforation Depth TVD (ft): 4166' - 4248' 4-1/2", 12.6# L-80 8425' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1 /2" Baker S-3 8389' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ' ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Drilling Technologist Sig ature Phone 564-4750 Date + Prepared By Name/Number: ~ " I~f "~~Sondra Stewman, 564-4750 nrl Form 10-40~vised 04/2006 c ~~ .. • ° ' . ;. ~`~ ;~- ~ Submit Original Only ~ ~" 2DD7 ,~~a~~~~,~,~ m • Tree: 4-1/16" - 5M Cameron M P H ~0 ~ ~ Orig. KB Elev. = 64.9' (N 22E) Wellhead: 11" x 11" 5M FMC Orig. GL Elev. = 36.0' Gen 6, w/ 11"x 4 1/2" tubing hanger FM RT To Tbg. Spool = 30.6(N 22E) TC-II threads top and btm 4" CIW "H" style BPV Profile 20" 91.1 ppf, H-40 115' SLB 4 1/2" x 1" KBG-2 2478° ID = 3.833" 4 1/2" 12.6 ppf L-80 IBT-M tbg. MIN ID in tbg = 3.725" (cap = .0152 bpf) 8413` and "HES XN Nipple" 7 " 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) (capacity w/ 4 1/2 tbg = 0.0186 bpf) HES XD Sliding Sleeve 8324' 3.81" polish bore KOP @ 300' Max. hole angle = 78 to 80 deg. f/ 3600' to 7450' Hole angle thru' perfs =Horizontal Milled 6-1/8" window at 8588'- 8600' (12') 4.5", 12.6# L-80 IBT Solid liner. H-086 (OA sand) TOL 9078' Baker whipstock top 9082' RA marker 9092' Whipstock bottom 9096' H-08B L1 (OB sand NB Lateral OA Lateral TOL 9030' TIW whipstock 9062' RA marker 9071' Whipstock bottom 9075' Soth laterals lined with 2 7/8", 6.6# tubing, predrilled at 4 spf Note: It is not possible to reenter the OA lateral DATE I REV. BY 4120101 MDO 8/30/05 MDO 05/14/06 MDO 11/22/07 JLP & LH Baker S-3 packer 8389` 4 1i2" HES "XN" Hippie 8413` 3.813 polish bore & 3.725 No-go ID 4 1/2" WLEG 8424` Baker ZXP Liner top packer " ' 8421 ` w/6 tie back (5.25 ID) Baker 5" x 7" HMC liner hanger 8436` (4.375" ID) Baker HMCV cement valve Baker CTC 20' PZP ECP 8979` H-08A P&A with cement below bottom whi pstock 3/15/01 X X ~~//~ X (~/L/~d x ~~. X X X X X X ;OA sand ; X TD 11,448' Shoe 11,430' X X X X X X TD 11,510' Shoe 11,485' X X X X X X X OB sand X COMMENTS 10-Ot-97 Drilled and Cased by Nabors 221 6/20/98 Frac and completion by Nabors 4-Et 12/19/99 P&A well sidetrack 4-ES 1/19/00 Sidetrack completed forjet pump CTU Sidetrack Nabors 3S Jet Pump to ESP Conversion Nabors 4-es ESP RWO & Heat trace instalation 3S Conversion to JP -Nabors 4ES MILNE POINT UNIT WELL No: MPH-08B API : 50-029-22808-02 BP EXPLORATION (AK) • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date I From- To I Hours ( Task I Code I NPT 11/13/2007 106:00 - 08:00 I 2.001 RIGD 1 P 08:00 - 13:00 5.00 MOB P 13:00 - 15:00 2.00 RIGU P 15:00 - 18:00 3.00 RIGD P 18:00 - 20:00 2.00 WHSUR P 20:00 - 21:00 I 1.001 WHSUR P 21:00 - 21:30 0.50 KILL P 21:30 - 00:00 2.50 KILL P 111/14/2007 100:00 - 01:00 I 1.001 KILL I P 01:00 - 02:30 I 1.501 DHB I P 02:30 - 04:30 2.00 WHSUR P 04:30 - 11:30 7.00 BOPSU P 11:30 - 18:00 I 6.501 BOPSURP 20:30 - 22:30 2.00 KILL UR I P 22:30 - 00:00 I 1.501 PULL I P Spud Date: 9/3/1997 Start: 11/13/2007 End: I Rig Release: 11 /20/2007 Rig Number: Phase Description of Operations PRE PJSM. Rig down rig components, scope down & lay over derrick. PRE PJSM. Move rig & rig components from MPF-25 to MPH-08. PRE Spotted and bermed rig. PRE Raised and scoped derrick. Leveled rig, RU mud and derrick lines. Accepted rig @ 18:00 hrs 11/13/2007. DECOMP Held crew change and performed pre-tour checks. RU lines to tree and tiger tank. Took on 130 deg seawater. DECOMP RU lubricator and tested to 500 psi. Pulled BPV and LD same. DECOMP Tested lines to 3500 psi. DECOMP Opened well to closed choke. Tubing pressure 80 psi, annulus pressure 80 psi. Opened choke, bled pressures to 0 psi. Displaced tubing volume (45 bbls) with heated 8.5 ppg seawater. Closed choke and attempted to bullhead; pump pressure increased to 2000 psi after 9 bbls injected. Shut down and bled tubing pressure through choke. Opened choke and continued circulating the long way through holes in tubing at 7178 ;staged pump up to 5 bpm @ 1400 psi holding 330 psi back pressure. Circulated a total of 355 bbls, getting crude, diesel, and brine in returns. DECOMP Stopped pumping, well initially on vacuum. Closed choke and monitored well; 0 psi on tubing and casing.. DECOMP RU lubricator and tested to 500 psi. FMC set TWC. Tested TWC from above to 3500 psi for 10 minutes. Pumped into annulus, tested TWC from below to 850 psi. Charted both tests. DECOMP RD and blew down lines. Bled pressure from tubing hanger void. ND tree. DECOMP Installed spacer spool. NU BOPE. Problems associated with wellhead on previous RWO in may did not reoccur. Stabilized BOP stack with turnbuckles and continued on with nippling up. DECOMP P/T BOPE to 250-psi LO / 3500-psi HI per BP/AOGCC requirements. Choke manifold valve #12 failed to test. Disassembled same and cleaned out frac proppant. Retested O.K. AOGCC -Lou Grimaldi waived State of Alaska right to witness BOPE testing. Repaired drive chain on drawworks, loaded pipe shed with 4-1 /2" completion tubing, rabbited and strapped same. Also performed various rig maintenance activities while testing ROPE. Totco RigWatch system non-operational. Investigated trouble with RigWatch system with aid of Quadco technician via telephone. Unable to return to service. Quadco dispatching technician to slope to repair system. DECOMP RU lubricator. Pulled and LD TWC. RD lubricator. DECOMP Circulated seawater surface to surface with full retums. Well took 4 bbls to fill initially. Pumped 2 bpm @ 270 psi, 3 bpm @ 570 psi, 4 bpm @ 970 psi, 5 bpm @ 1350 psi. Shut down and monitored after getting bottoms up, had 10 psi on tubing and annulus. Continued circulating a total of 265 bbls. Shut down and monitored; 0 psi on tubing and annulus. DECOMP Held PJSM. PU landing joint and cross-over to 2-7/8" 8rd. Screwed into tubing hanger. BOLDS. Pulled tubing hanger to floor with 48k Ib PU. Disconnected ESP cable and heat trace Printed: 12/4/2007 9:23:15 AM BP EXPLORATION Page Z of 5 Operatiolns Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/14/2007 22:30 - 00:00 1.50 PULL P DECOMP from tubing hanger. LD landing joint and tubing hanger. 11/15/2007 00:00 - 02:00 2.00 PULL P DECOMP Pulled ESP cable and heat trace cable over double cable sheave and through elephant trunk to ESP cable spooler. Prepared and attached cable ends to spools in ESP cable spooler. 02:00 - 06:00 4.00 PULL P DECOMP Continued POH, standing back 2-7/8" tubing. Spooled ESP cable and heat trace. Cut 45 flat guard bands per stand. Recovering heat trace flat guards and bands. Well remaining full after adding twice steel displacement plus about 1 bbl seawater per 10 stands. Recovered hardware heavily coated with crude. 15 stands pulled @ 05:30 hrs. Ordered 50-Bbls. diesel to flush tubing and cables to aid in removing crude oil. 06:00 - 10:30 4.50 PULL P DECOMP Continued on POH w/ESP-Heat Trace completion. Recovered 3415' heat trace cable, 2-7/8" tubing and ESP cable @ 0930-hrs. Rigged down heat trace handling tools. Cleared and ' cleaned floor of heat trace flat guards and baskets. Spooled up end of heat trace cable to cable spooler. 10:30 - 13:30 3.00 PULL P DECOMP MIRU LRS. PJSM to discuss diesel heating/pumping. Pumped 50-bbls. 120E diesel down tubing @ 1.5-bpm @ 600-psi taking returns to rig pits. S/D LRS. Closed annular preventer on tubing and ESP cable to divert returns through super choke. Circu{ated diesel out with heated SW from rig pits @ 5.0-bpm @ 900-psi while holding 300-psi backpressure on choke. Tubing and cable coming out much cleaner. 13:30 - 16:30 3.00 PULL DECOMP Continued POH w/ESP cable and tubing. Recovered 69 total Lasalle clamps, 6 protectorlisers and 3 Armstergaurds. Recovered 515 6' flat guards, 28 4' flat guards, 20 3' flat guards and 1726 carbon steel superbands. The ESP pump shaft rotation was locked and the ESP motor passed all integrity tests. 16:30 - 18:00 1.50 PULL P DECOMP BO/LD and inspect ESP BHA. Tubing in good condition. No signs of scale or other foreign material deposition on ESP assembly or tubing. Pulled ESP cable over cable sheave. LD ESP assembly. Cleared rig floor. 18:00 - 19:30 1.50 PULL P DECOMP Held crew change. Performed pre-tour checks. Continued LD ESP and motor assembly. Cleared and cleaned floor. 19:30 - 20:30 1.00 CLEAN P DECOMP RU to run bit and scraper on 2-7/8" tubing from derrick. Loaded BHA into pipe shed. 20:30 - 00:00 3.50 CLEAN N WAIT DECOMP MPU declared Phase III weather conditions @ 1630-hrs.. 17 rig related personnel on location. Cleared location. Performed general rig housekeeping, including painting rig floor, organizing rig floor equipment, maintaining rig vehicles, and updating operations procedures. 11!16/2007 00:00 - 06:00 6.00 CLEAN N WAIT DECOMP Continued clearing location, painting rig floor, organizing rig floor equipment, maintaining rig vehicles, performing general rig housekeeping, and updating rig operations procedures.. Continued in Phase III weather conditions. 06:00 - 07:30 1.50 CLEAN N WAIT DECOMP WOW. Phase condition reduced to Phase II at 0730-hrs. by MPU Operations. 07:30 - 09:00 1.50 CLEAN P DECOMP PJSM -BHA Handling. PUMU 7" casing scraper/4-3/4" bit BHA as follows: 4-3/4" bit, bit sub, 2-718" PAC pup jt., double pin sub, 7" scraper & XO. 09:00 - 14:30 5.50 CLEAN P DECOMP RIH w/7" scraper/4-3/4" bit BHA, 2-7/8" tubing from derrick and Printed: 12/4/2007 9:23:15 AM • u BP EXPLORATION Page 3 of 5 Operatioins Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task .Code NPT Phase. Description of Operations 11/16/2007 09:00 - 14:30 5.50 CLEAN P DECOMP singles of 2-718" tubing from pipe shed. Target depth for 4-3/4" bit = 8433'. Noted an obstruction @ 7314'. Worked scraper through section and obstruction no longer there. Obtained PUW and SOW before tagging liner top. PUW = 45K; SOW = 22; Tagged liner top @ 8421'. Tagged bottom of liner tie-back receptacle @ 8431' w/bit. Reciprocated scraper from 8398' to 8418' four times. 14:30 - 18:00 3.50 CLEAN P DECOMP Make up headpin and circulating hose to tubing. Circulate long way @ 5.5-bpm @ 850-psi. Recovered small amount of very fine sediment and crude oil across shaker screen. Mixed and circulated 30-Bbl. Hi-Vis sweep long way @ 5.5-bpm @ 850-psi. Monitored well, 0 psi. 18:00 - 22:00 4.00 CLEAN P DECOMP Held crew change and PJSM. Performed pre-tour checks. TOH with BHA #1 (4-3l4" bit, 7" casing scraper). LD double, stood back 89 stands. Filled well with calculated pipe displacement plus 1 bbl seawater. 22:00 - 23:00 1.00 CLEAN P DECOMP Held PJSM with rig crew and tool operator. LD BHA #1 (bit and scraper). PUMU 7" RTTS. 23:00 - 00:00 1.00 CLEAN P DECOMP TIH with 7" RTTS on 2-7/8" tubing from derrick. Continued loading pipe shed with 4-1/2" tubing, tallying joints, cleaning and inspecting threads. 11/17/2007 00:00 - 02:30 2.50 CLEAN P DECOMP Continued TIH with 7" RTTS on 2-7l8" tubing from derrick. Continued preparing for 4-1/2" completion. 02:30 - 04:00 1.50 CLEAN P DECOMP PU wt 45k Ib. SO wt 20k Ib. Set RTTS @ 8397' with 10k Ib additional SO. Closed VBR and annular BOP. RU to pressure up annulus. Tested 7" casing to 3500 psi for 30 minutes. Bled pressure, opened VBR and annular. 04:00 - 04:45 0.75 CLEAN P DECOMP Made up head pin and circulating hose to tubing. Circulated seawater 5 bpm at 1200 psi. 04:45 - 06:00 1.25 CLEAN P DECOMP POOH LD 2-7/8 tbg 36 jts LD at 0600-hrs. Pre-tour HSE meeting with day crew 0530-0600 hrs. 06:00 - 13:45 7.75 CLEAN P DECOMP Crew change at 06:00-hrs. Check PVT alarms, grease drawworks and blocks, grease crown and derrick inspection. Cont. POOH LD 2-7/8 tbg 36 jts LD at 06:00-hrs. 189 jt. POH at 10:45-hrs. BO/LD 7" Halco RTTS packer. Packer returned to surface with all parts intact. Currently in Phase 1 weather conditions. 13:45 - 14:15 0.50 CLEAN P DECOMP Clear & clean rig floor. 14:15 - 14:45 0.50 EVAL P DECOMP ND flow nipple. 14:45 - 15:30 0.75 EVAL P DECOMP NU shooting flange. 15:30 - 16:30 1.00 EVAL P DECOMP Weekly HSE meeting -All day crew. 16:30 - 18:15 1.75 EVAL N WAIT DECOMP SWS a-line enroute to wellpad from Deadhorse and are behind Nordic 1 rig move. 18:15 - 23:30 5.25 EVAL P DECOMP Held crew change and performed pre-tour checks. Cleared pad and spotted E-line equipment. Held PJSM. RU E-line service with full pressure control. MU USIT tool string. 23:30 - 00:00 0.50 EVAL P DECOMP RIH with USIT. 11/18/2007 00:00 - 00:30 0.50 EVAL P DECOMP Continued RiH with USIT. Could not work logging tools deeper than 3380'. Well bore inclination at 3380' is 77 deg. 00:30 - 06:00 5.50 EVAL P DECOMP Logged up with USIT from 3380' to surface. Made repeat passes across TOC and corroded intervals. Sent logging information to Schlumberger town and engineer who spoke to RWO engineer about results. No further action required with Printed: 12/4/2007 9:23:15 AM • • BP EXPLORATION 'Page 4 of 5 Operations Summary Report IiLegal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 (Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2007 00:30 - 06:00 5.50 EVAL P DECOMP respect to casing integrity. Held weekly HSE meeting with night crew. Continued clearing location with front loader. Maintainance mud pump. Performed general rig housekeeping. 06:00 - 07:30 1.50 EVAL P DECOMP Rig down -move off SWS a-line unit. Reviewed "Rigging Down E-line and Tools" procedure with rig crew. 07:30 - 09:00 1.50 RUNCO RUNCMP ND shooting flange. NU flow nipple. RU floor with 4-1l2" tubing handling tools. Review completion running order with Baker Packers representative. Note: Well program completion running order modified per MPU H pad engineer to include 4-1 /2" x 1" GLM w/DCK-2 shear valve set to shear at 3000-psi and located at -2500' MD. Tool Service expeditor NORM tested and cleared all pulled completion jewelry, tubing, tubing hanger, tree and tubing adapter spool. 09:00 - 09:30 0.50 RUNCO RUNCMP PJSM -Reviewed "RIH w/Completion Tubing" procedure with crew and described requirements for running in hole with IBT-M tubing. Sanded well pad area around rig to ensure all walking/working surfaces safe. 09:30 - 18:00 8.50 RUNCO RUNCMP PUMU WLEG/XN nipple asst'., 7" x 4-1/2" Baker packer asst'., and HES sliding sleeve asst'. and RIH on 4-1/2" 12.6#, L-80 IBT-M tubing. Made up all connections to mark and using Best-O-Life 2000 joint compound. Inspecting teflon seal rings in each connection joint by joint prior to makeup. LD and replaced jt. #73 due to bad threads. RIH w/105 jts. at 1620-hrs. 18:00 - 21:00 3.00 RUNCO RUNCMP Held crew change. Performed pre-tour checks. Held PJSM. Continued RIH with 4-1/2", 12.6#, L-80 IBT-M tubing. Made up connections to mark and used Best-O-Life 2000 joint compound, inspected teflon seal rings in each connection joint by joint prior to makeup. 21:00 - 22:30 1.50 RUNCO RUNCMP Established parameters: PU 75k Ib, SO 32k Ib. PU jt #204. Tagged 2.5' in on jt #204 @ 8427'. SO 12k Ib, carefully rotated tubing. Circulated the long way 3 bpm @ 260 psi. Saw no indication of circulating through tie-back receptacle. 22:30 - 00:00 1.50 RUNCO RUNCMP LD jts 204, 203, 202. Spaced out 2' above tag depth @ 8425'. MU 7.80' spaceout pup, jt #202, tubing hanger, XO and landing joint with TIW valve. Based on measured depth of tubing, WLEG is landed 4' deep in tie-back receptacle. 11/19/2007 00:00 - 00:30 0.50 RUNCO RUNCMP Landed tubing hanger and RILDS. 00:30 - 01:00 0.50 RUNCO DPRB RUNCMP Closed blind rams. Confirmed ability to circulate the long way 3 bpm at 260 psi. 01:00 - 02:00 1.00 RUNCO DPRB RUNCMP ND flow nipple. NU shooting flange. 02:00 - 04:00 2.00 RUNCO DPRB RUNCMP Held PJSM. RU slickline with riser extension, pump in sub, BOP, and lubricator. Tested lubricator and flange connections to 500 psi. 04:00 - 08:30 4.50 RUNCO DPRB RUNCMP RIH with ball and rod on slickline. Ball and rod fell to -4450'. Began pumping with rig 1 bpm, and increasing rate in 1/2 bpm increments to 3 bpm. Wireline RIH speed -40 ft./min. Line speed decreased to 10-20 ft./min. when tool string depth reached 6800'. Tag RHC seat at 8420' WLM. Pull ball & rod up 200'. 08:30 - 11:30 3.00 RUNCO RUNCMP MIRU CH2 vac trucks and reverse cirulate 200-Bbls. 140E seawater and 125 bbls. 140E corrosion inhibited seawater @ Printed: 12/4/2007 9:23:15 AM C • $P EXPLORATION Page 5 of 5 Operations Summary Report 'Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 11/13/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/20/2007 Rig Name: NABORS 4ES Rig Number: Date From - To 11!19/2007 08:30 - 11:30 Hours I Task. l Coded NPT Phase Description of Operations 3.001 RU 11:30 - 13:30 I 2.00 13:30 - 16:15 2.75 16:15 - 0.00 16:15 - 17;00 I 0.75 17:00 - 18:00 1.00 18:00 - 20:00 I 2.00 20:00 - 20:30 I 0.50 20:30 - 22:30 I 2.001 RU N 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 BOPSU P 11/20/2007 00:00 - 01:30 1.50 BOPSU P 01:30 - 04:00 I 2.501 WHSUR I P 04:00 - 05:00 I 1.001 WHSUR I P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 07:30 I 1.501 WHSUR I P 07:30 - 08:30 I 1.001 WHSUR I P 08:30 - 09:00 I 0.501 WHSUR I P RUNCMP 3.0-bpm @ 190-psi taking returns to rig pits. No indication of slickline tool string moving uphole while reverse circulating @ 3.0-bpm. WAIT RUNCMP Clean rig while working plan forward with Anchorage engineering staff. RUNCMP PJSM and review newly developed plan forward. DPRB RUNCMP slickline RIH and set ball & rod on seat. Pressure tubing up to 3500-psi to set packer. held 3500-psi on tubing for 30-charted minutes. Bled tubing pressure to 1500-psi. Pressure up IA to 3500-psi and held pressure for 30 charted minutes. Bled tubing to 0-psi and sheared DCK-2 shear valve. Circulated both ways through shear valve at 3.0-bpm at 1100-psi. DPRB RUNCMP slickline POH w/ball & rod. DPRB RUNCMP Held PJSM with all personnel; discussed handling of high-explosive E-fire equipment. RU wireline retrievable plug setting head arming and firing equipment. DPRB RUNCMP Held crew change and performed pre-tour checks. PU and RIH with wireline retrievable plug (WRP). Established depth, detonated E-fire head, set WRP @ 2650'. DPRB RUNCMP RU to pump down tubing. Tested WRP to 1000 psi for 10 minutes. DPRB RUNCMP Held PJSM with all personnel on retrieving and handling spent firing head. POH with slickline and firing head. RDMO slickline service. RD pert flange. Installed flow nipple. RUNCMP FMC representative installed TWC. RU to pressure test. Tested TWC from above and below to 1000 psi for 10 minutes each. Charted tests. Released pressure, blew down lines. RUNCMP Drained BOPE stack. RUNCMP Held PJSM. ND BOPE. Disconnected choke and kill lines. ND spool extension. ND DSA. Held fire drill in well cellar. RUNCMP NU lock down flange and adapter spool. Tested to 5000 psi for i 30 minutes. Moved in LRS in preparation for rig up. RUNCMP NU tree and tested to 5000 psi. MPH-Pad operator verified tree orientation. RUNCMP PU lubricator and makeup to tree cap. P/T lubricator to 500-psi against closed swab valve. MPU Well Support pull TWC. Set lubricator back. RUNCMP RU LRS and Pff lines to 3500-psi. Pump 85-Bbls. diesel through swab valve on tree and through shear valve at 2.0-bpm to freeze protect tubing and IA taking returns to rig pits. RUNCMP PU lubricator and makeup to tree cap. PIT lubricator to 500-psi against closed swab valve. MPU Well Support set BPV. LD lubricator. RDMO LRS. RUNCMP Secure tree and cellar. Release rig @ 0900-hrs. Printed: 12/4/2007 9:23:15 AM Ø//q/tJ£, RECEIVED a STATE OF ALASKA a ALA_ OIL AND GAS CONSERVATION COM~ION JUL 1 4 2006 REPORT OF SUNDRY WELL OPERA T1~s~a~ìl & Gas Cons. Coomission 1. Operations Performed: - o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 201-048 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22808-60-00 7. KB Elevation (ft): 65.68 9. Well Name and Number: MPH-08BL 1 8. Property Designation: 10. Field 1 Pool(s): ADL Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 11510 feet true vertical 4253 feet Plugs (measured) N/A Effective depth: measured 11510 feet Junk (measured) N/A true vertical 4253 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 8557' 7" 8588' 3899' 7240 5410 Intermediate Production 649' 4-1/2" 8436' - 9060' 3793' - 4150' 8430 7500 Liner 2352' 2-7/8" 9030' - 11485' 4143' - 4252' 13450 13890 ., t.,"'.'''',' r\ ) ~~, ............~ ~ Perforation Depth MD (ft): Slotted 9106' - 11450' Perforation Depth TVD (ft): 4166' - 4248' 2-718",6.5# L-80 7300' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Service 181 Daily Report of Well Operations o Exploratory 181 Development 16. Well Status after proposed work: 181 Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant ~ /' Prepared By Name/Number: S~tur:)t;~:\ /.~- (\i,~t { , ~. ~ Phone 564-4750 DateDl-/-l{-D(rßondra Stewman, 564-4750 Form 10-4õ4"RêV1Sed 04/20Œ .~.~;. " "~ 'to ~C~' Submit Original Only OR,G\l\JAL ~.. .),-""'-/'-'''1-- .. RBDMS BFL JUl 1. -1 Z006 MPU H-08B Orig. KB Elev. = 64.9' (N 22E) Orig. GL Elev. = 36.0' RT To Tbg. Spool = 30.6 (N 22E) ~ 2-9/16" - SM FMC Wellhead' 11" x 2-9/16" SM FMC Gen 6, w 2-7/8" FMC Tbg. Hgr., 8rd.EUE Top & Btm, 2.S" CIW BPV Profile 20" 91.1 ppf, H-40 115' KOP @ 300' Max. hole angle = 78 to 80 deg. fl 3600' to 7450' Hole angle thru' perfs = Horizontal 2-7/8" 6.S ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00S92 bpf ) 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf) Note: Centrilift Motor was re-rated KME-1 130 HP 214SV 135A Milled 6-1/8" window at 8588'- 8600' (12') 4.5",12.6# l-80 IBT Solid liner. H-08B (OA sand) TOl Baker whipstock top RA marker Whipstock bottom 907S' 90S2' 9092' 9096' Cameo 2-7/8" x l' KBMM 164' I Heat trace installed @ 341S' md. Cameo 2-7/8"x l' KBMM 7,083' XN Nipple (2.313 packing 10) I 7,224' (2.205 no-go 10) Centrilift GPMTAR 1/1 145/GC 53SP11 7,24S' Tandem I Gas Separator GRSFTX AR H6 7,262' Tandem Seal Assembly I GSB3DBUT AS;I·jSN PFSA 7,266' GSB3DBlTAB: HSNFSA Centrilift KMH Motor I 7,280' 152 HP, 2325v/40amp Pumpmate Sensor wI fins I 7,294' Baker ZXP Liner top packer I 8421' w/6' tie back (5.25" ID) Baker 5"x?" HMC liner I 8436' hanger (4.375" ID) Baker HMCV cement valve 8961' Baker CTC 20' PZP ECP 8979' H-OSA P&A with cement below bottom whipstock I 3/15/01 " H-08B L 1 (OB sand) TOl 9030' TIWwhipstock 9062' ~ RA marker 9071' Whipstock bottom 9075' Both laterals lined with 2 7/S", 6.6# tubing, predrilled at 4 spf Note: It is not possible to reenter the OA lateral DATE REV. BY COMMENTS 10-01-97 Drilled and Cased by Nabors 22 6/20/91 Frac and com letion b Nabors 4-E 12119/9¡ P&A well sidetrack 4-ES 1/19/0C Sidetrack completed for jet pump CTU Sidetrack Nabors 38 Jet Pump to ESP Conversion Nabors 4-es ESP RWO & Heat trace instalation 3S 4/20101 8/30105 OS/14/06 MDO MDO MOO MILNE POINT UNIT WELL No : H-08B L-01 API : 50-029-22808-02 BP EXPLORATION (AK) e BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 5/7/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 5/8/2006 00:00 - 03:00 3.00 MOB P PRE RDMO GPB DS15-06 03:00 - 18:00 15.00 MOB P PRE Move rig from GPB DS15-06 to MPH-08B. 18:00 - 00:00 6.00 MOB P PRE MIRU on MPH-08B. 5/9/2006 00:00 - 06:30 I 6.50 MOB P PRE MIRU on MPH-08B. 0030-hrs. - 24-hr. notification to AOGCC of impending BOPE test. ATP meeting held at 0530-hrs. with MPU management and day rig crew and toolpusher. 06:30 - 11 :00 4.50 MOB P PRE R/U Vac Trucks and take on 1200 F seawater to Pits. H/U hardline to Tiger Tank and test with air. Check all circulating lines. Actuate SSV with Porta-Power pump, install Fusible Cap, bleed off actuator pressure. P/U Lubricator and pull BPV. Casing and Tubing pressures = O-psi. Wait on Mist Extractor for Tiger Tank. Install Mist Extractor. Hold PJSM for circulating out diesel freeze protect. Rig accept @ 0700 hrs. 11 :00 - 13:00 2.00 KILL P DECOMP Line up valves to Reverse Circulate Tubing. Take all returns to Tiger Tank. Mud Pump developed a pounding sound. Troubleshoot to ensure pump not being starved. Check individual cylinders and find chunks of rubber under valve plates. Clean out Mud Pump Fluid End. 13:00 - 16:00 3.00 KILL P DECOMP Reverse circulate, 3.5-BPM, 300-psi Annulus, 20-psi Tubing for 75-Bbls. Realign valves and circulate long way 3.5-BPM, 500 to 650-psi Tubing, 300 down to 10-psi Annulus for 355-Bbls until returns cleaned up. SII and Tubing and Casing at O-psi. No fluid losses to formation. 16:00 - 18:30 2.50 WHSUR P DECOMP Install TWC and N/D Tree. 18:30 - 00:00 5.50 BOPSUF P DECOMP N/U BOPE 5/10/2006 00:00 - 03:00 3.00 BOPSUF P DECOMP N/U BOPE 03:00 - 06:00 3.00 BOPSUF N DECOMP The Wellhead rotates and sways back and forth once the BOP Stack is set on it. FMC and Pad Op notified. FMC says that swaying should not be possible due to an existing load shoulder. FMC to come inspect swaying. 06:00 - 08:00 2.00 BOPSUF N DECOMP The ground surface inside and surrounding the Cellar appears to have subsided 3 to 4 inches, allowing the 20" conductor slip bowl to drop away from the fluted landing ring of the 7" Casing. Nabors 3S Tool Pusher said they had not encountered the same problem when they worked over the well in August 2005. The 7" Casing to Casing Head seal will only hold 800-psi, but the leak is to the inside because fluid was used to fill the void during the pressure test and none of it escaped to the outside of the Casing Head Seal Lock Ring. Discussed with engineering and will use normal turnbuckle restraints to centralize the 7" Casing and BOP Stack in order to continue with the RWO. 08:00 - 09:30 1.50 BOPSUF P DECOMP Finish N/U BOPE and stabilizing BOP Stack. 09:30 - 12:30 3.00 BOPSUF P DECOMP Test BOPE 250-psi low and 3500-psi high. The Hydril bag won't seal, so decide to complete all tests, with exception of the Hydril. When Driller released the pressure on the Hydril bag, he inadvertently actuated the blind shear rams which cut the test joint. 12:30 - 13:30 1.00 BOPSUF N HMAN DECOMP Open Hydril, open Blind Rams doors and inspect shear faces and find them in good shape. Lasso the 2-7/8" test joint stump and POH. Close doors. 13:30 - 15:30 2.00 BOPSUF P DECOMP Complete remaining BOPE tests, except the Hydril test. 15:30 - 00:00 8.50 BOPSUF N RREP DECOMP Change out Hydril bag and seals. Printed: 512212006 11 :55:55 AM e BP EXPLORATION Page 2 of 3 Operations Summary Rèport Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 517/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 5/11/2006 00:00 - 03:00 3.00 BOPSUF P DECOMP Finish BOPE Test to 250 psi Low 13500 psi High. 03:00 - 04:30 1.50 RIGU P I DECOMP Pre-job safety meeting. R/U Sheave and Elephant Trunk. 04:30 - 07:30 3.00 PULL P DECOMP PUMU lubricator. Pull TWC. SITP = O. SICP=O. UD lubricator. PUMU landing jt. Screw into tubing hanger. BOLDS. Unland tubing hanger. Hanger pulled free @ 44,000 Ibs. Pull and UD landing jt. and tubing hanger. FMC transported tubing hanger to their shop for redress. 07:30 - 16:30 9.00 PULL P DECOMP POOH 2 7/8 tbg wI ESP pump. SIB dbls in derrick. SLM 16:30 - 18:00 1.50 PULL P DECOMP Pull ESP pump and tail out cable. 18:00 - 20:00 2.00 PULL P DECOMP UD pump and motor, clear and clean rig floor. 20:00 - 20:30 0.50 PULL P DECOMP Service crown and blocks, straighten wrap on dead man anchor 20:30 - 00:00 3.50 PULL X WAIT DECOMP Clean rig, wait on 2 7/8 pac pipe. 5/12/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Load and strap 2 7/8 pac in pipe shed. Remove 21 jts. 2 7/8 EUE from shed, install wear bushing. 01 :00 - 12:00 11.00 CLEAN P CLEAN P/U and RIH 21 jts. 2 7/8 PAC, followed by 49 jts. 2 7/8 EUE tubing from pipe shed, and 101 stands of 2-7/8" EUE. Drift tubulars on skate. Tagged Fill @ 8522'. 12:00 - 18:00 6.00 CLEAN P CLEAN RIH wI single jt. 3.5" DP while Circulating @ 5 BPM. Reverse Circulate @ 5 BPM bottoms up plus 5 Bbls. 18:00 - 23:00 5.00 CLEAN P CLEAN Cont. RIH wI work string on 3.5" DP, washing down & reverse circulating drill string volume on each connection. Can not RIH with out washing down. 23:00 - 00:00 1.00 CLEAN P CLEAN Taking weight wI pump on @ 8970'. Wash t/8975 in 1-2' , increments. Reverse circulate bottoms up @ 167 GPM 720 PSI 5/13/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Cont. RIH fl 8975' t/ 9001' washing down in 2-4' increments, picking up & working through. Max set down weight 1-2K, before P/U. 01 :00 - 02:00 1.00 CLEAN P CLEAN Pump 25 BBL Hi Vis sweep & reverse CBU surface to surface @ 9001' 02:00 - 02:45 0.75 CLEAN P CLEAN Cont. to wash 11 9001' to 9004' taking weight and making no headway. 02:45 - 03:00 0.25 CLEAN P CLEAN Reverse tubing volume 03:00 - 05:00 2.00 CLEAN P CLEAN Cont. attempts to wash from 9004' setting down no more than 2-3 K. No headway. 05:00 - 06:00 1.00 CLEAN P CLEAN Pump 25 BBL Hi-Vis sweep reverse circulate surface to surface. 06:00 - 09:00 3.00 CLEAN P CLEAN POOH to 8400' MD, above 4.5" Liner, and perform injectivity test. 0.15 BPM @ 1500 psi. 09:00 - 14:00 5.00 CLEAN P CLEAN RIH and Tag up once more. Tagged @ 9009' MD. Wash down to 9027' and tag top of Liner. Reverse Circulate Duo-Vis Pill surface to surface. Found metal shavings in returns. 14:00 - 17:00 3.00 CLEAN P CLEAN POOH to 8400' MD and perform injectivity test. 2.5 BPM @ 1000 psi. Reverse Circulate Duo-Vis Pill surface to surface. At 1000 PSI pressure dropped off to 0 PSI. Monitor well & check surface equipment. Well on vacuum. Losses @ - 15 BBUHR 17:00 - 22:00 5.00 CLEAN P CLEAN POOH SIB 101 stds. 2 7/8 EUE tbg. Losses @ -22 BBLS I HR 22:00 - 00:00 2.00 CLEAN P CLEAN PJSM- POOH & UD 49 Jts. 2 7/8 EUE Tbg. 5/14/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN PJSM, Change out handling equipment & UD 21 Jts. 2 7/8 PAC 01:30 - 03:30 2.00 RIGU P RUNCMP Clear floor & rig up to run ESP 03:30 - 06:00 2.50 RUNCm f" RUNCMP PJSM, PIU & M/U ESP & motor assy. Printed: 5/2212006 11 :55:55 AM e e BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08 Spud Date: 9/3/1997 Event Name: WORKOVER Start: 5/7/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2006 06:00 - 18:00 12.00 RUNcm IP RUNCMP RIH wI new ESP Completion on 2-7/8" Tubing from Derrick. Heat trace line picked up @ 3415' From surface. Check conductivity of electric cable every 2000'. 18:00 - 00:00 6.00 RUNcm P RUNCMP ConI. RIH wI ESP completion assy. on 2 7/8 EUE Tbg. wI dual cables, testing conductivity every 2000' Ran in to -6133' 5/15/2006 00:00 - 05:30 5.50 RUNCm IP RUNCMP ConI. RIH WI ESP completion assy. F/ 6133' WI dual cables testing conductivity every 2000' 05:30 - 06:00 0.50 RUNCm IP RUNCMP MU Tubing hanger Prep cables for splice. Ran 69 LaSalle Clamps,S Protectolizers, 3 Flat Guards. 06:00 - 11 :00 5.00 RUNCm IP RUNCMP Space out ESP Cable and Heat Trace to Hanger and make electrical connection to the Penetrator. 11 :00 - 13:00 2.00 RUNCm P RUNCMP Land tubing hanger, P/U WI. 46K S/O WI. 26K. RILDS. Set TWC & test same 13:00 - 17:00 4.00 RUNCm IP RUNCMP N/D BOPE. 17:00 - 00:00 7.00 RUNCm IP RUNCMP N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Good test. Centriflift run final checks. P/U lubricator. Pull TWC. Set BPV. UD Lubricator. Wait on Veco to locate BPV. Clean pits, Remove valves & flanges from well head. Prep for move. 5/16/2006 00:00 - 01 :00 1.00 RIGD P RUNCMP ConI. Prep for rig move, while wait on Veco for BPV. 01 :00 - 01 :30 0.50 RIGD P RUNCMP Set BPV, Secure well. 01 :30 - 06:00 4.50 RIGD P RUNCMP ConI. RID, cleaning pits, jack down pits & pipe shed, blow down steam, disconnect electrical lines. Printed: 5/2212006 11 :55:55 AM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ Marker.doc RECE:IVeO STATE OF ALASKA. .. ALASKA )L AND GAS CONSERVATION CO.lISSION OCT 1 0 2.005 REPORT OF SUNDRY WELL OPERATIOJiS,I&GasCons.Commission AnchOfage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program Change Jet Pump to ESP o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 65.68 8. Property Designation: ADL 11. Present well condition summary Total depth: measured 11510 true vertical 4253 Effective depth: measured 11510 true vertical 4253 Casing Length Structural Conductor 78' Surface 8557' Intermediate Production 649' Liner 2352' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 201-048 6. API Number: 50-029-22808-60-00 99519-6612 9. Well Name and Number: MPH-08BL 1 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 7" 8588' 3899' 7240 5410 4-1/2" 8436' - 9060' 3793' - 4150' 8430 7500 2-7/8" 9030' - 11485' 4143' - 4252' 13450 13890 Slotted 9106' - 11450' 4166' - 4248' $ÇANNEl' t~O\Þ Ü' B 2005 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 7346' N/A RBDMS 8Fl OCi'ï/ .~ 2005 Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Signa Form 10-404 Revised 04/2004 Title Technical Assistant Phone o N Prepared By Name/Number: Date 0'-\- Ul-c.DSondra Stewman, 564-4750 Submit Original Only 564-4750 ORIGINAL } H -oad [or~'. KB Elev.: 64.~' (N 22E) ..., leF,b. GL Elev. - 36.0 RT To Tbg. Spool = 30.6 (N 22E) ) MPU .Iœ.e.;. 2-9/16" - 5M FMC Wellhead: 11" x 2-9/16" 5M FMC Gen 6, w 2-7/8" FMC Tbg. Hgr., 8rd.EUE Top & Btm, 2.5" CIW BPV Profile I~ .. Camco 2-7/8"x l' KBMM 20" 91.1 ppf, H-40 115' I 170' I KOP @ 300' Max. hole angle = 78 to 80 deg. fl 3600' to 7450' Hole angle thru' perfs = Horizontal 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) 7,094' Cameo 2-7/8"x l' KSMM XN Nipple (2.813 packing 10) I (2.75 no-go 10) 7,235' 7 " 26 ppf, L-80, BTC mod production csg. ( drift 10 = 6.276", cap. = 0.0383 bpf ) Centrilift GPMTAR 1/1 100/GC 1150 ESP, 16 GCNPSH Tandem Gas Separator GRSFTX AR H6 I Tandem Seal Assembly I I I I I 7,256' 7,309' I 7,314' I 7,328' I 7,344' I 8421' I 8436' I 8961' 8979' GSB~~OBlJT At:>/H~~N PFSAlF~:";A cI·,······..··,:·.·.··..··.··.,·,,'·:..···,·:..^···...."....."'."...".::..'.'.,............'....'...'..........'...........,., '..'..,... "'~: ,;;' 11i¡:¡ O$ß3DßL TAB I HSNFSA Centrilift KMH Motor 133 HP, 2205 vI 37 amp Pumpmate Sensor wI fins __ . Baker ZXP Liner top packer w/6' tie back (5.25" 10) = Baker 5"x7" HMC liner ;: hanger (4.375" 10) ~ Baker HMCV cement valve r Baker CTC 20' PZP ECP . Milled 6-1/8" window at 8588'- ~ 8600' (12') 1 H-08A P&A with cement below bottom whipstock 3/15/01 4.5", 12.6# L-80 1ST Solid liner. H-OSB (OA sand) TOL Baker whipstock top RA marker Whipstock bottom ~ ~..... '~J' ~~ )OAsand : ') TO 11,448' Shoe 11,430' 9078' 9082' 9092' 9096' , ~~ ç X ,7;% H-OSB L 1 (OB sand) : X ; TOL 9030' ~: X X TIW whipstock 9062' X X ~ RA marker 9071' X X Whipstock bottom 9075' ~ Both laterals lined with 27/8",6.6# tubing, predrilled at 4 spl X ~ XX X TO 11,510' Shoe 11 ,485' Note: It is not possible to reenter the OA lateral X X X X ^ A ^ )f. " " ^ ~ v X X X X 08 sand X . a a ~ .... ..... a a . . '- DATE REV. BY COMMENTS 10-01-97 Drilled and Cased by Nabors 2:< 6/20/9E Frac and completion by Nabors 4-E 12119/9~ P&A well sidetrack 4-ES 1/19/0( Sidetrack completed for jet pump CTU Sidetrack Nabors 35 Jet Pump to ESP Conversion Nabors 4-es MILNE POINT UNIT WELL No : H-OSB\L-01 API: 50-029-22Soå-02-oo Ai> \... 5o--o;q-~~- lo(XjC) BP EXPLORATION (AK) 4 I 20 I 01 8/30/05 MOO MDO ) } BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/25/2005 12:00 - 22:00 10.00 RIGU P DEcaMP Move rig from MPC-43 to MPH-08B. 5 mile move. Spot rig over well, ACCEPT RIG @ 2200 hrs. 22:00 - 00:00 2.00 RIGU P DECaMP MIRU. Hook up kill lines and rig up Tiger tank. Fill rig pits with 460 bbls. 2% KCL water. Prep to kill well. 8/26/2005 00:00 - 02:00 2.00 RIGU P DECaMP PIT kill lines to 3500 psi and return line to Tiger tank to 120 psi. 02:00 - 04:30 2.50 KILL P DECOMP Notify Milne Point front desk of gas venting on H pad. SITP = 40 psi, SICP = 180 psi. Open well & Bleed off well to Tiger tank. Fill hole. Break conventional circulation down 4.5" tubing at 4 bpm at 220 psi. Take returns from annulus to Tiger tank. Pumped 350 bbls. 2% KCL to displace tubing and casing and kill well. 04:30 - 06:00 0.00 PULL P DECaMP Install TWC. Attempt to test, No good. P/?U lubricator & pull TWC. Install new TWC & test to 1000 psi, Ok. 06:00 - 08:00 2.00 WHSUR P DECOMP Bleed off tubing void. N/D tree & adapter flange. 08:00 - 11 :30 3.50 BOPSUF P DECOMP N/U DSA & test spool. N/U BOPE. 11 :30 - 12:30 1.00 BOPSUF P DECaMP R/U test equip. Set test plug. 12:30 - 16:30 4.00 BOPSUP P DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Bop test witnessing waived by Jeff Jones wI AOGCC. All tests good, no failures. RID test equip. 16:30 - 18:00 1.50 WHSUR P DECOMP P/U lubricator & pull TWC. Ud lubricator. Monitor well. Well dead. 18:00 - 19:00 1.00 PULL P DECaMP M/U landing jt into hanger. P/U & pull hanger to floor. Pulled 100K# to 150K# to try to work tubing free at jet cut. UD landing jt. 19:00 - 22:00 3.00 FISH P DECOMP P/U double grapple spear wlone jt. 3 1/2" DP. Engage tubing hanger. Clear rig floor of all personnel. Work tubing pulling 160k# to 21 OK# in 10K# increments from 80K# pickup weight. No-go. Land tubing hanger. UD DP and spear. 22:00 - 23:00 1.00 PULL P DECOMP NID flow nipple. N/U shooting nipple. 23:00 - 00:00 1.00 PULL P DECOMP Prep rig for E-line ops. Wait on SWS e-line. 8/27/2005 00:00 - 03:30 3.50 PULL C DECOMP PJSM with rig crew and SWS e-line crew. MIRU SWS e-line eqpt. Kinked e-line. Cut and rehead e-line. 03:30 - 09:00 5.50 PULL C DECOMP P/U wireline packoff and pump-in sub. RIH wI tool string and string shot to +1-8398. Pumped tools in well @ 3.0 bpm @ 200 psi. Could not get below +/- 3100'. Made several attempts. 09:00 - 11 :00 2.00 PULL C DECOMP POOH & UD string shot. Mix & pump 40 bbl E-P Mud Lube pill. Spot to 4000'. 11 :00 - 14:00 3.00 PULL C DECOMP Hold PJSM prior to P/U chemical cutter. M/U & arm chemical cutter. RIH. Had to pump down. Pumped .5 to 3.0 BPM to get tool to go. At 3 BPM pressure was 800 psi. Correlate & tie-in to cutting depth. Fire cutter @ 8396.5'. Good indication of firing. POOH & UD cutter. 14:00 - 16:30 2.50 PULL C DECOMP RID & set aside logging equip. Mlu 41/2" Double spear, RIH & engauge into tubing. Pull & work pipe to 190K. Tubing not coming free. 16:30 - 18:00 1.50 PULL DECOMP Call town & review operation. Mix 50 bbl E-P Mud Lube pill. N/D shooting flange. N/U flow nipple. 18:00 - 20:00 2.00 PULL C DECOMP Reverse circulate 50 bbl. pill of water and EP mud lube down annulus. Work pipe from 25K# to 170k#. Pipe came free. P/U wt. 65K#. Finish rigging down SWS e-line eqpt. 20:00 - 00:00 4.00 PULL P DECOMP Rig up floor. UD tubing hanger. POH & UD 4 1/2" production tubing. Printed: 9/12/2005 10:04:24 AM ) }- BP EXPLORATION Operations Summary Report Page 2 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/28/2005 00:00 - 06:00 6.00 PULL P DECOMP POH & UD completion. Recovered 5 x 10' 12.6# L80 BTC pup jts., 202 jts. - 4 1/2" 12.6# L80 BTC tubing, 1 x 4 1/2" HES "XD" SSD assy. wI 1 x 4 1/2" 3' 12.6# L80 pup jt. in top of assy. and 1 x 41/2" 3' 12.6# L80 pup jt. in bttm .of assy. and 1x cut 10' 12.6# L80 BTC pup jt. Cut 4 1/2" x 10' pup jt. in top of packer - recovered 6.46'. Stub looking up - 4 1/2" x 3.18'. Possible chemical cut at 1.5' down from top of stub. 06:00 - 06:30 0.50 PULL P DECOMP Service rig. 06:30 - 07:30 1.00 PULL P DECOMP Clear & clean rig floor. Install Wear Bushing. 07:30 - 09:00 1.50 PULL P DECOMP Load, tally & M/U BHA #1 as follows: 63/4" MM Mill, 4 Boot Baskets, Bit Sub, LBS, Oil Jars, 9 * 4 3/4" Dcs, Accel. TL = 328.75'. 09:00 - 14:30 5.50 PULL P DECOMP P/U 31/2" DP, 1x1 & RIH wI BHA #1. 14:30 -18:00 3.50 CLEAN P DECOMP P/U kelly. Break circulation. Tag up @ 8368'. Mill from 8368' to 8381'. P/U Wt = 85K, SIO Wt = 52K, Rot Wt = 63K. 60 RPMs, 10-13 WOB, Torq. 3.2K, 3 BPM @ 450 psi. Fluid losses = 55 bbls./hr. 18:00 - 00:00 6.00 CLEAN P DECaMP Mill from 8381' to 8389". P/U Wt = 85K, SIO Wt = 52K, Rot Wt = 63K. 60 RPMs, 10-13 WOB, Torq. 3.2K, 3 BPM @ 450 psi. Fluid losses = 55 bbls/hr. 8/29/2005 00:00 - 04:00 4.00 FISH P DECaMP Mill from 8389' to 8393'. P/U Wt = 85K, S/O Wt = 52K, Rot Wt = 63K. 40-120 RPMs, 5-15 WOB, Torq. 1.5K, 3-5 BPM @ 450 psi. Fluid losses = 55 bblslhr. 04:00 - 06:00 2.00 FISH P DECOMP Repair rig mud pump. Line up manifold for reverse circulation. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig. 06:30 - 07:30 1.00 FISH P DECOMP Close annular & reverse 2 bottoms up. 4 BPM @ 800 psi. Recovered a very small amount of sand & scale. 07:30 - 10:00 2.50 FISH P DECOMP POOH & stand back 31/2" DP & 4 3/4" DCs. 10:00 - 12:00 2.00 FISH DECOMP Break off MM Mill & inspect same. Mill worn out. Appears to have run on Packer. Break out & empty junk baskets. Recovered approx. 35# of metal shavings & some piece of slips. Discuss options wI town engineer. Clear & clean rig floor. 12:00 - 12:30 0.50 FISH P DECOMP M/U BHA #2 as follows: Spear wI 3.947" Grapple,LBS, Oil Jar, 9* 4 3/4" DCs, Accel. TL = 313.49'. 12:30 - 15:00 2.50 FISH P DECOMP RIH wI BHA #2. 15:00 - 15:30 0.50 FISH P DECOMP P/U kelly & 24' pup jt. RIH & en gauge fish. Set down wI 15K. P/U & had 25K overpull to 1 08K. Weight dropped to 83K. Appears to be dragging slightly. P/U Wt = 82K, S/O Wt = 52K. 15:30 - 16:00 0.50 FISH P DECOMP Pump tubng volume. 3 BPM @ 400 psi. Set back kelly. 16:00 - 20:00 4.00 FISH P DECOMP POOH wI BHA #2. UD fish. Packer completely milled up except for bottom 4/1/2" NSCT connection. Recovered 3x 4 1/2" 10' 12.6# L80 pup jts., 1 x 4 1/2" HES "XN" nipple and 1 x 4 1/2" muleshoe WLEG. Now have 100% completion recovery. 20:00 - 00:00 4.00 FISH P DECOMP RIH w/9x 43/4" DC's and 31/2" DP. 8/30/2005 00:00 - 06:00 6.00 FISH P DECOMP POH LOOP 06:00 - 06:30 0.50 FISH P DECOMP Service rig 06:30 - 07:00 0.50 FISH P DECOMP Finish POOH & UD a total of 253 jts 31/2" DP. 07:00 - 07:30 0.50 FISH P DECOMP Change out handling tools & UD 9 * 4 3/4" DCs. 07:30 - 08:30 1.00 RUNCOtvP RUNCMP Pull Wear Bushing. Clear & clean rig floor. 08:30 - 11 :30 3.00 RUNCOtvP RUNCMP P/U, MIU & service ESP. Run attach and test cable 11 :30 - 12:00 0.50 RUNCOtvP RUNCMP Clean and clear rig floor 12:00 - 21:00 9.00 RUNCOtvP RUNCMP TIH 2-7/8" 6.5# EUE 8rd New Tbg ESP Completion with LaSalle Clamps on cable testing cable continuity and filling tbg Printed: 9/12/2005 10:04:24 AM ) )' BP EXPLORATION Operations Summary Report Page 3 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-08 MPH-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/25/2005 Rig Release: 8/31/2005 Rig Number: *4ES Spud Date: 9/3/1997 End: 8/31/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/30/2005 12:00 - 21 :00 9.00 RUNCOrvP RUNCMP every 2000' 21 :00 - 23:00 2.00 RUNCOrvP RUNCMP Make up Tbg Hanger I Make up and test connector cable I P/U Wt. 39K S/O Wt. 24K Land Hanger and RILDS. 222 Lasalle Clamps, 3 Flat Gaurds, & 6 Protectrolizers run 23:00 - 00:00 1.00 RUNCOrvP RUNCMP PJSM for BOPE rig down. Set TWC and test 1000 psi 8/31/2005 00:00 - 03:00 3.00 RUNCOM RUNCMP NID Flow nipple and BOPE 03:00 - 05:00 2.00 RUNCOM RUNCMP N/U Tree Test Hanger 5000 psi, Test Tree 5000 psi 05:00 - 06:00 1.00 RUNCOM RUNCMP Clear rig and pits for rig move: Rig released @ 06:00 Printed: 9/12/2005 10:04:24 AM Permit to Drill 2010480 DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. MILNE PT UNIT SB H-08BL1 Operator BP EXPLORATION (ALASKA) INC MD 11510 -' TVD 4253 Completion Dat 4/20/2001 ~ Completion Statu 1-OIL Current Status 1-OIL UIC N APl No. 50-029-22808-60-00 REQUIRED INFORMATION Mud Log N__Qo Sample N__9 Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received .Number~.~ Comments 8685 11500 Open 9120/2001 ~10304 8685-11500 -E)l~ctional Survey FINAL OH 7/6/2001 Directional Survey, Paper Copy 10304 FINAL ~ 8685-11500 Digital Data 8685 11500 OH 9/20/2001 OH 9/20/2001 11500 OH 9/20/2001 ~1445 OH 9/20/2001 1445 OH 9/20/2001 ~on FINAL R~libore Profile / 2/5 FINAL C-MD~esistivity / GR 2/5 FINAL -I-VD Resistivity / GR 2/5 FINAL J.~S-Verification 9030-11500 BL, Sepia 9108-11445 BL, Sepia 9108-11445 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~.~ Chips Received? ~ Analysis ~ R ~.n~.iv~.d ? Daily History Received? (~)N Formation Tops /'~/N Comments: Permit to Drill 20t 0480 MD 11510 'I'VD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. MILNE PT UNIT SB H-08BL1 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22808-60-00 4253 Ition Dat 4/20/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Transmittal Form BAKER : ~"~'"~ HUGHES ~ Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference · Miline Point Unit MPH-08B L1 Contains the following: LAS Format disk Film Set Measured Depth GR print TVD-GR print R. esistb,'itv r~ .. ., rlnt LAC Reference Number: 15326 Sent By: JosefBerg Date: Sept 17, 2001 Received ~ t/~~o~-) Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A4 --G E iVE D BP EXPLORATION (ALASKA) PETROCHEIvlICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 SEP 2 0 2001 ~aska 0~i & Gas Cons. C, ommi~6n · ~ch~a~e STATE OF ALASKA ALAS ~IL AND GAS CONSERVATION COM ,oSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator :j. OC.A:i.i~t~- 7. Permit Number BP Exploration (Alaska)Inc. ¥1~r-a:~ 201-048 3. Address 8. APl Number Box 196612, Anchorage, Alaska 99519-6612 ~ ~) 50- 029-22808-60 P.O. 4. Location of well at surface :' ~~' 9. Unit or Lease Name 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM.. ~ Milne Point Unit At top of productive interval '~ ~./~._/~.~ ~! 964' SNL, 2049' EWL, SEC. 01, T12N, R10E, UM (OB Sands) -- At total depth ': .' '. 'i 10. Well Number MPH-08BL1 2817' SHE, 3020' EWL, SEC. 01, T12N, R10E, UM " ...... ~.~.-- ..... 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 65.68' AMSL ADL 380109 12. Date Spudded4/15/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'4/10/2001 4/20/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11510 4253 FTI 11510 4253 FTI []Yes []NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run GR, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 260 sx Arctic Set (Approx.) 7" 26# L-80 31' 8588' 8-1/2" ;'047 sx PF 'E', 263 sx 'G', 191 sx PF 'C 4-1/2" 12.6# L-80 8436' 9060' 6" ¢6 sx Class 'G' 2-7/8" 6.16# L-80 9030' 11485' 3-3/4" Uncemented Slotted Liner 24. Perforations pp. en to, P.roducti,on (M,D+,TVD of Top and 25. TUBING RECORD Bottom and ~mervak s~ze an(] number) SIZE DEPTH SET (MD) pACKER SET (MD) Uncemented Slotted Liner 4-1/2", 12.6#, L-80 8433' 8398' MD TVD MD TVD 9106'- 11450' 4166'-4250' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL {MD) AMOUNT & KIND OF MATERIAL USED 9062' Set Flow-Through Whipstock Freeze Protect 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 30, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/1/2001 12 TEST PERIOD 1048 179 0I 171 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Subm,'.~~sf~ ' %i ~-,'~" ~ t~' ~ ;' ,..~!as!.a Oil & C-as Or.;r:s. (,orn~.,sslon ..,"it, I Anchorage Form 10-407 Rev. 07-01-80 GF~ Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Top Schrader OB Sands 9195' 4208' Base Schrader OB Sands 9310' 4243' Base Schrader OB Sands 9400' 4246' Top Schrader OB Sands 10722' 4215' Top Schrader OB Sands 10908' 4221' Base Schrader OB Sands 11436' 4249' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~ ~ Title TechnicalAssistant Date {~"~0'{~/ MPH-08BL1 201-048 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Appro,,vaI,No. , , ,, , ,, , , , ,, ,, ,,, 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page 11 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: RIG Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 3/27/2001 00:00 - 06:00 6.00 MOB PRE Rig down from MPC-12A. 06:00 - 18:00 12.00 MOB TRAN PRE Wait on trucks to move rig. 18:00 - 20:00 2.00 MOB PRE Move rig and equipment from MPC to MPH pad. 20:00 - 22:00 2.00 MOB PRE Set rig mats. Back rig over well. 22:00 - 00:00 2.00 MOB PRE Set pits. Build dike for return tanks. 3/28/2001 00:00 - 04:00 4.00 RIGU PRE Rig up. Rig accepted @ 00:01 3/28/01 04:00 - 16:00 12.00 RIGU PRE Nipple up BOP stack. Install second set of TOT's to stack. 16:00 - 19:30 3.50 RIGU PRE Function test BOP. Attempt body test. Determine master valve leaking. Call for test plug. 19:30 - 20:15 0.75 RIGU PRE ' Hold EMS meeting with new crews on slope. Presented by MPU , Environmental. 20:15 - 00:00 3.75 RIGU TREE PRE :Wait for test plug. Grease valves. 3/29/2001 00:00 - 01:30 1.50 RIGU TREE PRE Install test plug, grease choke manifold. Test witness waived by AOGCC inspector Lou Grimaldi. 01:30 - 10:30 9.00 RIGU PRE Pressure test BOP. 10:30 - 12:00 1.50 RIGU PRE Pull test plug. Make up OXP coil connector. 12:00 - 13:00 1.00 RIGU PRE Hold pre-spud meeting with day crew. Stress differences in operation; MPU, Schrader Bluff formation, OXP. 13:00 - 18:30 5.50 RIGU PRE M/U BHI electrical connection. 18:30 - 19:30 1.00 RIGU i PRE Hold Pre-spud meeting with night crew. 19:30 - 20:20 0.83 RIGU PRE Complete M/U of BHI electrical connections. 20:20 - 21:30 1.17 STWHIP 'PROD1 Circulate methanol water into e-coil. Pump 44 Bbls. Coil pressures up. (6.5 Bbls short of displacement ~ 1000') Two heaters have been on coil since yesterday when it arrived. Decide to M/U BHA and run into hole to thaw. 21:30 - 23:00 1.50 STWHIP PROD1 M/U BHA #1, Window Master mill, string reamer, Mud Motor, PH-6, Mech. release, EDC. OAL = 100.11'. 23:00 - 00:00 1.00 STWHIP PROD1 Surface test BHA. Witness EDC functioning. Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 1 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: N^BORS 3S Rig Number: · Sub Date From - To Hours Task Code Phase , Description of Operations 3/30/2001 00:00 - 01:20 1.33 STWHIP PROD1 Continue surface checks with EDC. 01:20 - 03:45 2.42 STWHIP PROD1 RIH. Pump 10 Bbls methanol @ 4000'. Pressures up once to 1600~. Broke free. 8300' tool shorts out. Pump and move pipe. No change. 03:45 - 07:30 3.75 STWHIP BHA PROD1 POH. Change out pawl on level-wind. 07:30 - 09:30 2.00 S'i'WHIP BHA PROD1 At surface. Break off below EDC. EDC found to be the problem. Change out and surface test. OK. 09:30 - 11:15 1.75 S'I'WHIP BHA PROD1 RIH with BHA #2. Circulate in milling fluid; 1/2ppb Biozan in 9.2 ppg KCL/NaCL, with Klagard and corrosion inhibitor. RIH weight ~ 2-4k#. 11:15 - 11:45 0.50 S'I'WHIP PROD1 Set down on 5" x 7" liner hanger. Complete displacement of 60/40 from coil. close EDC. Pump minimum rate. Make it past liner hanger. Continue RIH pu[nping minimum rate. Tag cement at 9051' CTM. 11:45 - 12:20 0.58 STWHIP PROD1 Pick up 40k#. B~ing pUmp rate up to 2.8 bpm. 3200 free spin. Wash through soft cement to 9088'. Start seeing motor work. Call this notch. 12:20 - 14:30 2.17 STWHIP PROD1 Mill window from9085'. String weight showing -4k#. Milling rate increases @9097'. (BOW) Make pass up through window. 1 stall in up direction. 14:30 - 17:15 2.75 STWHIP PROD1 Milling open hole at 6-21 fph from 9097'. Mill OH to 9108'. Circulate 30 Bbls 2 ppb Biozan pill on bottom. Catch samples on bottoms up. Shut down pump. Drift window. Clean up and down. Above window, open EDC. 2.8 bpm, 2900~ ctp. No fluid losses through milling operation. 17:15 - 18:00 0.75 STVVHIP PROD1 Circulate milling fluid at 9070' while wiating on mud truck. Mud arrives. 18:00 - 18:30 0.50 STWHIP PROD1 PJSM with night crew. Mud swap and recovery. 18:30 - 19:30 1.00 STWHIP PROD1 Pump down pit levels. Ship milling fluids to clean tiger tank. Displace well to 9.2ppg FIoPro. 19:30 - 21:30 2.00 STWHIP PROD1 POH circulating. 21:30 - 23:40 2.17 STWHIP PROD1 L/D BHA #2. Window mill guages 3.73" (chromed from formation) string reamer guages 3.8". M/U BHA #3, build assembly w/1.7 M.Motor. 23:40 - 00:00 0.33 DRILL PROD1 RIH with BHA #3. OAL = 63.1' 3/31/2001 00:00 - 01:30 1.50 DRILL PROD1 RIH w/BHA #3. 01:30 - 06:30 5.00 DRILL DATA PROD1 Attempt GR tie-in twice. Computer/Depth problems. 06:30 - 07:30 1.00 DRILL PROD1 Log GR tie-in, -4'. 07:30 - 08:10 0.67 DRILL PROD1 RIH and tag bottom @ 9104'. 08:10 - 09:30 1.33 DRILL PROD1 Drill build f/9104' to 9163'. 1.8 bpm, 2920 psi off bottom, 3200 drilling, BHP=2500. Up wt 35k#, slack off to 2k#, DH WOB ~ 2k#. TF 33L. !(oriented from 111L, slow due to temp. 65 F.) 'Begin heating recovered milling fluid w/HB&R. Fluid temp. starting @ 30 F. 09:30 - 11:15 1.75 DRILL POWR PROD1 Repair Dowell and BHI computer problems along with rig fuel line freezing. 5 sec. sample rate on Dowell computer appears to be locking it up. Second time in two days. Adjust rate to 30 sec. rate. Wind picking up to 30 mph. Phase one conditions called. 11:15 - 12:25 1.17 DRILL 'PROD1 Drill to 9200' with 3k# WOB. Losses at 1 bph. 12:25 - 15:00 2.58 DRILL PROD1 POH. Open circ. valve above window. 15:00 - 16:30 1.50 DRILL PROD1 Change bit, adjust AKO, add resistivity. 16:30 - 21:00 4.50 DRILL OTHR PROD1 USMPR resistivity tool not responding in string. Trouble shoot. Break out tool. Retest. Working. M/U BHA #4. 21:00 - 00:00 3.00 DRILL OTHR PROD1 RIH w/BHA ~,. OAL = 74.86'. Continue to trouble shoot USMPR ~roblem. 4/1/2001 00:00 - 00:30 0.50 DRILL OTHR PROD1 Trouble shoot USMPR. May be mud-temperature induced. 00:30 - 03:00 2.50 DRILL PROD1 RIH. 03:00 - 04:30 1.50 DRILL OTHR PROD1 Configure Resistivity display out-put. Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 2 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 4/1/2001 04:30 - 05:00 0.50 DRILL PROD1 Log GR tie-in. 05:00 - 07:15 2.25 DRILL TREE PROD1 POH for o-ring failure on lubricator. 07:15- 08:00 0.75 DRILL TREE PROD1 CIO O-ring. 08:00 - 09:30 1.50 DRILL TREE PROD1 RIH circulating through circ. sub. OXP power supply problem. 09:30 - 11:00 1.50 DRILL BHA PROD1 POH due to OXP problems. 11:00 - 21:00 10.00 DRILL BHA PROD1 Trouble shoot OXP problems. Witness communication problem w/ OXP computers. Erratic voltage through CTE-line. USMPR still not working on surface. Cut coil to straighten and re-head e-line. Find collector drive-bolts sheared. Repair with hardened bolts the propper length. 21:00 - 22:15 1.25 DRILL BHA PROD1 Make up CT to BHA. Test electrical connections. Circulate out meth/wtr. 22:15 - 23:30 1.25 DRILL PROD1 RIH w/BHA #4. 23:30 - 00:00 0.50 DRILL PROD1 Log GR tie-in. 4/2/2001 00:00 - 04:00 4.00 DRILL OTHR PROD1 Shut down Dowell computer and replace hard drive. 04:00 - 04:45 0.75 DRILL PROD1 Log GR Tie-in. (-11') 04:45 - 05:10 0.42 DRILL PROD1 RIH to bottom. 05:10 - 06:10 1.00 DRILL PROD1 Close circ. sub. Orient TF to 90R and drill 3'. 06:10 - 06:55 0.75 DRILL PROD1 Safety meeting and discussion of directional plan between Geo. and D.D. 06:55 - 07:20 0.42 DRILL PROD1 Drill f/9203' to 9230'. 2.2 bpm, 3500 ctp, 2970 inner/2440 outer pressure, 34k# up, 3k# dn, 2k# wob. 07:20 - 08:30 1.17 DRILL PROD1 Orient TF f/75 R to 90 L. Find clockwise stop at 103 L. Turn TF CCW to 70L. 08:30 - 09:25 0.92 DRILL PROD1 Drill f/9230' to 9295'. 2.1 bpm, 3300 ctp, 2950 inner/2430 outer, 2k# wob. Stalled motor. Calcite stringer? Kicked inclination up to 95 deg. 09:25 - 11:45 2.33 DRILL PROD1 Drill to 9350'. Appear to be in calcite stringer. 11:45 - 12:15 0.50 DRILL PROD1 Short trip to window. 12:15 - 16:50 4.58 DRILL PROD1 Pull above window to log from 8950' to TD to get one continuous log from above Shrader Bluff formation to TD for definitive Geological reference. Hole in good condition. Logging at 100 fph, 0.5 bpm. Mud weight @ 9.1 ppg. Add NaCI to bring back up to 9.2 ppg. 16:50 - 19:05 2.25 DRILL PROD1 Drill f/9350' to 9480'. Bringing angle down. ROP varies from 10 to 100 fph. 19:05 - 19:50 0.75 DRILL PROD1 Short trip to window. Replace Nabors pump pop-off and clean suction screens. 19:50 - 21:20 1.50 DRILL PROD1 Drill ahead f/9480'. Snubbing -ek# and getting 4-5k# WOB. Drilling slow. Angle dropping below 90 deg. 21:20 - 00:00 2.67 DRILL PROD1 Continue drilling at 9630'. Still stacking 4-6k# w/1-3k# getting to BHA. 2 bpm, 3500# surface pressure, 3145~ inned2570# outer pressure. 4/3/2001 00:00 - 12:45 12.75 DRILL PROD1 Make wiper trip f/9630'. 12:45 - 04:10 15.42 DRILL PROD1 Drill to 9770'. Hit fast-drilling streak @9680'. 2 BPM, 3430 surface pressure, 3110 inned2588 outer. 2k-4k WOB. 04:10 - 04:55 0.75 DRILL PROD1 Wiper trip f/9770'. Hole clean, complete string weight running back in hole 2k-3k#. 04:55 - 09:45 4.83 DRILL PROD1 Slow drilling to 9926'. Break through stringer @ 9886'. ROP increases :to 100 fph. 09:45 - 10:45 1.00 DRILL PROD1 'Short trip to window. Hole is clean. 10:45 - 12:25 1.67 DRILL PROD1 Drill f/9925'. Takes off drilling 70 fph for short distance. Goes slow again to 9960'. 12:25 - 14:40 2.25 DRILL PROD1 Drilling and string weight and ROP increase intermitantly. Lose weight transfer to bit. Drilled to 9997'. 14:40 - 16:10 1.50 DRILL PROD1 Short trip 100'. No improvement. Pull wiper trip to window. Order new Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 3 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Sub Phase Description of Operations, ' Code 4/3/2001 14:40 - 16:10 1.50 DRILL PROD1 batch of mud to be mixed. 16:10 - 19:10 3.00 DRILL PROD1 Drilling with -7k# string weight. 2 bpm, 3750 surface/3240 inner/2630 outer, 3k# wob. 10,036' top increases slightly. Drill to 10056'. 19:10 - 19:45 0.58 DRILL PROD1 PUH to casing. 19:45 - 20:45 1.00 DRILL PROD1 Repair Dowell computer. 20:45 - 21:20 0.58 DRILL PROD1 Log GR tie-in. (+8') 21:20- 21:50 0.50 DRILL PROD1 RIH 121:50 - 22:50 1.00 DRILL PROD1 Drill to 10,092' Still within shale In side BHA pressure 3330 psi outside 2635 psi,Coil pressure 3750 free spin 3500psi. WOB 3.6K ~22:50 - 00:00 1.17 DRILL PROD1 Drill to 10,110 still in shale. Inside BHA pressure 3335psi, outside BHA pressure 2660 psi, Coil tubing presssure 3820 psi. 4/4/2001 00:00 - 03:40 3.67 DRILL PROD1 Drill to 10180' still in shale 03:40 - 04:30 0.83 STKOH PROD1 Pull to window 04:30 - 04:45 0.25 STKOH PROD1 Open circulation port and circulate bottoms up. 04:45 - 07:15 2.50 STKOH PROD1 Discuss options with Anchorage team members and develop open-hole side-track directional plans. Target Iow-side kick-off @ 9800' md. 07:15 - 08:00 0.75 STKOH PROD1 RIH to begin trenching. 08:00 - 12:30 4.50 STKOH PROD1 Begin "trenching" for Iow-side exit f/9770' to 9800'. Tool Face ~ 177 R. Pumping 2 bpm, 3550 CTP, 3080 inner/2615 outer, 3k# string weight reaming down. 12:30 - 18:00 5.50 STKOH PROD1 Shut down pump and test ledge. RIH and stack lk# on lip at 9800'. Pick up and begin time drilling @ 9800'. Make several repeats of 9803'. Appear to be drilling new hole. 18:00 - 19:00 1.00 STKOH PROD1 Drill to 9813. Inner BHA pressure 2884 psi, outer BHA pressure 2559, WOB .4K 1.6 bpm. 19:00 - 23:00 4.00 STKOH PROD1 Drill to 9819. Inner BHA pressure 2884 psi, outer BHA pressure 2559, WOB .4K 1.6 bpm. Drill to 9928 Inner BHA pressure 3148 psi, outer BHA pressure 2635 psi, WOB 1.6 K 2.0bpm. 23:00 - 00:00 1.00 STKOH PROD1 Drill to 9960'. Inner BHA pressure 3166 psi, outer BHA pressure 2647psi, WOB 2.6 K 2.0 bpm. 4/5/2001 00:00 - 00:23 0.38 STKOH PROD1 Wiper trip to window 900'. .00:23 - 01:24 1.02 STKOH PROD1 Reboot Computers 01:24 - 03:30 2.10 STKOH PROD1 Directionally drill to 10,110 :03:30 - 04:00 0.50 STKOH PROD1 Tie in +6' RIH ,04:00 - 05:30 1.50 STKOH PROD1 Directionally drill to 10116. Pressur inside BHA 3252 psi, Pressure outside BHA 2686 psi, WOB 4.6K 4129 TVD, @2bpm. 05:30 - 09:00 3.50 STKOH PROD1 Drill ahead. Hit hard stringer or shale @ 11,115'. Break through hard spot@ 10125'. (Confirmed calcite) Drilling 90fph. 2.6k#wob,-lk# string weight. Run into hard stall/drilling @ 10185'. Make 10200'. Still i drilling slowly. Acts like shale. 09:00 - 09:20 0.33 DRILL PROD1 Drill to 10201' @ 1.9 bpm. Stacking and stalling motor. Poorweight transfer. Acts like fault. BHP at 1.9 bpm @ 2700#. Begin losing returns up to 20 bph. Reduce circ. rate to 1 bpm and regain 1 for 1 returns. BHP 2550#. 09:20 - 13:00 3.67 DRILL PROD1 Pull up to casing at 1 for 1 returns. Shut down pump. No flow. Circulate 1 bpm, POH for BOP test. 13:00 - 13:15 0.25 DRILL PROD1 PJSM for BHA, Slack management. 13:15 - 13:45 0.50 DRILL PROD1 Rack back BHA. Bit in good shape. Guages at 3.75". 13:45 - 16:15 2.50 DRILL PROD1 Cut off e-line anchor. Reverse circulate 150 bbls mud up coil at 3 BPM, 4000 psi. Pump coil volume of meth/water at 1 bpm. Find 41" of e-line hanging out of coil. 16:15 - 17:15 1.00 DRILL PROD1 Set two way check for BOP test. Cut extra e-line. Stab on well. 17:15 - 18:00 0.75 DRILL PROD1 Reverse circ. 70 Bbls mud into coil @ 3bpm. Check coil. E-line further ,, Printed: 5/1/2001 10;29:37 AM BP EXPLORATION Page 4 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/5/2001 17:15 - 18:00 0.75 DRILL PROD1 than 5' inside coil. 18:00 - 19:30 1.50 DRILL PROD1 Freeze protect coil with methanol reversing. 19:30 - 00:00 4.50 DRILL PROD1 Cut off 7' coil. install and pull test coil connector. Pressure test coil connector. Test BOP. 4/6/2001 00:00 - 00:45 0.75 BOPSUI; PROD1 Continue to rehead and Test BOP. 00:45 - 05:30 4.75 BOPSUF; PROD1 Continue to test BOP 05:30 - 06:30 1.00 BOPSUF; PROD1 Pull TWC. 06:30- 08:00 1.50 DRILL PROD1 M/U BHA#5. RR DS-49. Test OXP tools. Open circ. sub. Circulate out methanol water. 08:00 - 08:45 0.75 DRILL PROD1 RIH with BHA #5, OAL = 74.75'. Make 2200'. 08:45 - 09:15 0.50 DRILL BHA PROD1 Problem with OXP. Check collector. POH. 09:15 - 10:45 1.50 DRILL BHA PROD1 OOH. Put on circulating sub on coil. Check out tools. Replace EDC. Retest tools. OK. M/U to coil. 10:45 - 11:15 0.50 DRILL BHA PROD1 RIH w/BHA. 2000'. Looking good. 11:15 - 13:00 1.75 DRILL PROD1 Continue running in hole. 13:00 - 13:20 0.33 DRILL PROD1 Log GR tie-in, (-2') 13:20 - 14:00 0.67 DRILL PROD1 Close circ. valve, pass window. RIH. Hole in good, smooth condition. Tag @ 10198'. Circulating 0.5 bpm, getting I for 1 returns. ~2300 bhp Circulating 1.0 bpm, getting 80% returns. ,.-2400 bhp Circulating 1.5 bpm, getting 50% returns..-.2500 bhp 14:00 - 18:00 4.00 DRILL SUPP PROD1 PUH to casing and wait for new mud. Ordered @ 05:30. Waiting for vac. truck transportation. Perform step rate test in casing again. This time work up to 2 bpm at 1/4 bpm increments, 100% returns. (yesterday had losses) 18:00 - 18:45 0.75 DRILL PROD1 Circulate in new mud through circulating sub in casing @ 2 bpm. 18:45 - 20:00 1.25 DRILL PROD1 Dowell computer locks up. Reboot. Change data sample time from 5 second to 10 second. 20:00 - 21:00 1.00 DRILL PROD1 Continue to circulate in new mud. 21:00 - 22:00 1.00 DRILL PROD1 RIH 22:00 - 00:00 2.00 DRILL PROD1 Ddlling at hard spot @ 10200' 5k# wob (calcite?) Initial losses 30 BPH but heal as we drill. Drill to 10205'. Loss rate .2 bpm. Pressure at inside BHA 3086 psi, Pressure outside BHA 2577 psi. Coil tubing pressure 3366 psi @ 2pbm wob 2k. 4/7/2001 00:00 - 03:30 3.50 DRILL =PROD1 Drill to 10273, Coil tubing pressure 3200 psi Pessure inside BHA 3000 psi, Pressure outside BHA 2590 @ 1.8 BPM WOB lk loss rate. 1 bpm 03:30 - 04:30 1.00 DRILL PROD1 Drill to 10,338 Coil tubing pressure 3495 psi Pressure inside BHA 3180 psi, Pressure outside BHA 2605 @ 2.0 BPM WOB 3.9 k loss rate .1 bpm 04:30 - 05:00 0.50 DRILL PROD1 Drill to 10345' Coil tubing pressure 3380 psi Pessure inside BHA 3050 ~psi, Pressure outside BHA 2593 @ 2.0 BPM .loss rate .1 bpm 05:00 - 06:45 1.75 DRILL PROD1 i Wiper trip to window. See motor work back reaming @ 9380'. Hole takes weight @ 9430' when RIH. (Shale at top of OA sand) Hole takes weight @ 10000'. (silt stone) 06:45 - 08:15 1.50 DRILL PROD1 Resume drilling f/10345'. 2 bpm, 3600 ctp, 2620 outer, -6k# string wt, 3k# wob. Appear to be in shale. Drill to 10397'. 08:15 - 09:45 1.50 DRILL PROD1 Short trip for geological analysis. 09:45 - 13:25 3.67 DRILL PROD1 Resume drilling f/10397'. Progress increases slightly @ 10415'. Lose resistivity signal and regain 30 minutes later. Drilling in decent sand to 10550'. ROP @ 70 fph. Make wiper trip. OXP acting up. 13:25 - 15:00 1.58: DRILL LMWD PROD1 OXP Shorts out during wiper trip. Pull up to casing to check collector. All surface equipment checks out. Hole in decent shape. Slight bobble @ 9380'. Printed: 51112001 10:29:37AM BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 4/7/2001 15:00 - 18:50 3.83 DRILL LMWD PROD1 POH to check out OXP. 18:50 - 20:30 1.67 DRILL LMWD PROD1 ,ECD bad replace. No resistivity at surface. 20:30 - 21:30 1.00 DRILL LMWD PROD1 :Wait on information regarding availibility of subs to change out Circulation sieve. No additional subs availabe. Could use the ones we have on the other tool but choose to proceed with the current BHA. Have had previous instances where resisitivity didn't work onsurface but later did after it RIH and got warmed up. Decided to procede and if necessary we will mad pass to get resistivity. 21:30-22:00 0.50 DRILL LMWD PROD1 MU BHA. 22:00-00:00 2.00 DRILL LMWD PROD1 RIH 4/8/2001 00:00 - 00:45 0.75 DRILL LMWD PROD1 Tie in with RA tag -3'. Close circulation ports. 00:45 - 01:45 1.00 DRILL PROD1 Drill ahead 10550 to 10554 01:45 - 02:00 0.25 DRILL PROD1 Tool shorted out. Diagnose to confirm down hole failure 02:00-04:00 2.00 DRILL LMWD PROD1 POH 04:00 - 04:30 0.50 DRILL LMWD PROD1 Break down BHA 04:30 - 07:15 2.75 DRILL ;LMWD PROD1 Find broken wire in cable head. Repair and M/U BHA. 07:15 - 08:20 1.08' DRILL LMWD PROD1 4500' develope another short. 08:20 - 09:00 0.67i DRILL LMWD PROD1 POH. 09:00 - 11:15 2.251 DRILL LMWD PROD1 Rack back tools. Find connector on flapper valves off, and crimp connector on e-line disconnected. Find crimping tool set too strong. Reset. Make up new crimp connection. M/U BHA. Surface test ok. 11:15 - 12:10 0.92 DRILL LMVVD PROD1 Tool shorts out at 5500'. 12:10-13:00 0.83 DRILL LMWD PROD1 POH. 13:00 - 19:40 6.67 DRILL LMWD PROD1 EDC crapped out. Rehead and set up for dual mechanical release system. 12,140~ shear value in upper and lower as per town discussions. Check tools, ok. Break off of tools and circulate out methanol water. Make back up to tool. 19:40 - 22:50 3.17 DRILL LMWD PROD1 RIH w/BHA. Tie into whipstock pip-tag. (-9') Run to bottom. Resistivity not working at this time. 22:50 - 00:00 1.17 DRILL PROD1 Drill f/10554', lk# RIH wt. 2 bpm, 3350 free spin 3500 drilling, losing 15 bph mud initially. Drill to 10560'. 4/9/2001 00:00 - 00:15 0.25 DRILL POWR PROD1 Reboot BHI and Dowell computers. 00:15 - 03:00 2.75 DRILL PROD1 Drill f/10560'. 2 bpm, 3350 ctp, 3050 inner, 2600 outer. Up wt 28k#, slack off wt 1 k#, snubbing >8k# getting 2k# wob. Drilling 10t o 60 fph. Drill to 10682'. Losses heal to 1 bph. 03:00 - 04:45 1.75 DRILL PROD1 Short trip. 04:45 - 06:00 1.25 DRILL PROD1 Drilling f/10,682'. Break out into upper OA sand. ROP increases dramatically to >120 fph. Drill to 10800'. 06:00 - 08:30 2.50 DRILL PROD1 Short trip. Hole appears in good shape. 08:30 - 09:40 1.17 DRILL PROD1 Drill 10800'-10908', 75R-95R, 2 BPM, 3500 CT, 3100 inside, 2600 outside, good ROP (-120 fph) until hard spot at 10908'. In upper OA sand lobe. 09:40 - 10:00 0.33 DRILL PROD1 Short trip 200' to improve weight transfer. 10:00 - 10:20 0.33 DRILL PROD1 Drill 1' to 10909', hard calcite. Slow ROP of 3 fph. 1.5k lbs WOB with ~-7k snubbing. 10:20 - 12:35 2.25 DRILL PROD1 Decide to perform wiper trip to the window. PUH smooth. RBIH and set down at 9340' twice (OA sand upper lobe). Seems like a ledge. Orient to ~90L to get by. RIH and set down at 10650' and 10710' (silt). Work =through and RIH to bottom. 12:35 - 15:20 2.75 DRILL PROD1 Hard to get started drilling due to calcite stringer. Work through and ROP picks up to 120 fph, 2.6k lbs WOB. Drill 10909'-11070' in OA sand. ECD up 50 psi to 2650 psi. Have only lost 17 Bbl of mud from 0600-1530. Printed: 5/1/2001 10:29;37AM BP EXPLORATION Page 6 of 11 Operations Summar Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Date From-To Hours Task Code Phase 'Description of Operations 4/9/2001 15:20 - 16:30 1.17 DRILL PROD1 Wiper trip to the casing. 16:30 - 17:30 1.00 DRILL DATA PROD1 Load software on SLB computer to help troubleshoot intermittent crashes. 17:30 - 18:15 0.75 DRILL PROD1 RBIH. Set down at 10553' at directional change from 90L to 90R. Orient and go through at 10R. Set down at 11017, another directional change 90R to 90L. 18:15 - 19:00 0.75 DRILL DIR PROD1 Attempt to orient from 90R to 90L, but hole keeps pushing BHA over to 90R. PU to 10800 and get 90L orientation. RBIH past 11017' and tag bottom at 11070'. 19:00 - 21:30 2.50 DRILL PROD1 Drill 11070'-11203 '. Periodically hitting calcite stringers which slows ReP way down. Pump 2 BPM, 3500 psi CT, 3057 inner, 2670 psi outer. Hit another apparent calcite stringer at 11203'. Cannot get good weight transfer to the bit. Snub to -10klbs and see <lklbs at bit. Short trip and call for new mud. Current system is at ~0.8% solids. Had 5 Bbls of EMI 544 on location, but decide to swap mud to finish hole. 21:30 - 00:00 2.50 DRILL PROD1 Short trip to window. Hole smooth on the way up. Tie in and add 10'. New TD 11213'. RBIH and stack at 9380' & 10474 and push through. Stack at 10984' & 11025' and have to orient to direction drilled to get through. 4/10/2001 00:00 - 03:35 3.58 DRILL PROD1 Drill 11213-11320', 2 BPM, 3280 psi CT, 3100 psi inner, 2660 psi outer. PUW 28k, SOW to -10klbs when stacking out. Wieght transfer becoming a major problem. Stacking out with <lklbs WeB. New mud expected soon. 03:35 - 07:20 3.75 DRILL PROD1 Wiper trip to window. Log tie in and at 10'. RBIH. Take weight at 9385', 10630', 10648', 10972', 10990', 11025', and 11150'. Orient or push through. Various reasons for stacking, ledges & DLS speculated. Also mud is old. Short trips are down with full pump rate while POOH (2 BPM). When RIH pump rate is at minimum (0.5 BPM) to reduce the chance of sidetracking in soft sand. 07:20- 10:00 2.67 DRILL PROD1 Drill 11320-11443'. New mud in hole. Noticable increase in drill rate. 60 fph in sand. Dropping down from upper CA sand lobe to lower CA sand lobe at ~85 degree inclination. Stack out at 11443'. 10:00 - 13:00 3.00 DRILL PROD1 POOH. Pull 5k over (35k) at 9380' for a short period of time and then !free. Have 29 deg DLS at this point. Continue up hole with no :problems. Re tie in +6' correction to RA tag in whipstock at 9092'. RBIH. 13:00- 13:30 0.50 DRILL PROD1 Drill to 11448'. 13:30 - 17:45 4.25 DRILL PROD1 Wiper to window. Tie-in (no correction). TIH. Tag corrected TD 11445'. 17:45 - 21:00 3.25 DRILL PROD1 POOH. Tie-in at RA (+1' correction). Flag pipe 9031' EOP. POOH. 21:00 - 23:00 2.00 DRILL PROD1 Displace coil with methanol. LD BHA. 23:00 - 00:00 1.00 CASE COMP RU liner running equipment. 4/11/2001 00:00 - 00:30 0.50 CASE COMP Safety meeting -- run liner. 00:30 - 05:00 4.50 CASE COMP MU 72 joints 2-7/8" STL slotted liner. 05:00 - 06:00 1.00 CASE COMP MU swivel, 2-3/8" collar and pup for floor valve. 06:00 - 06:30 0.50 CASE COMP Safety meeting with day crew. 06:30 - 10:30 4.00 CASE COMP MU 72 jts 1-1/4" CSH. Tag top of slick stick in pack-off bushing. Space out with pups. MU GS spear, 2-3/8" collar, and swivel 10:30- 13:30 3.00 CASE COMP Finalize running procedure/equipment. 13:30 - 15:30 2.00 CASE COMP TEST GS SPEAR: PUH to deploy sleeve. Close 2-7~8" slips. LD 2-3~8" collar. Stab CTC on GS spear. NU riser. Pull test GS spear to Printed: 5/1/2001 10:29:37 AM BP EXPLORATION Page 7 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 91311997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Sub Phase Description of Operations Code 4/11/2001 13:30 - 15:30 2.00 CASE COMP 10k over. Slack-off. Circulate at 1.5 BPM and release spear. OK. Stab back in and pull test. OK. Stand back injector. MU 2-3/8" collar and swivel. 15:30 - 16:15 0.75 CASE COMP Displace methanol out of coil. Stab inj. 16:15 - 18:30 2.25 CASE COMP RIH at minimum rate. Correct depth at 6000' EOP flag (-12.4'). RIH. At 9000', 2k down and 24k up (seems light). RIH clean to 9950', then ratty 2k to -2k. Tag hard 10158'. SD pump. Clean PU to 28k. Try to work down. Repeat tags at same depth. Then got PU to 40k (must have dropped the liner at some point). RIH again and ran to 10860'. 18:30 - 00:00 5.50 CASE COMP Work pipe downhole from 10860' with neg 10k - 15k. To make progress, required alternating pumping (about 10 -20 bbls) and then working pipe down 5' - 30'. Some lost circulation noted 2.0 BPM in and 1.7 BPM out, but gradually improved to near full returns at tail end of pumping cycle. Occasionally lost liner if not fully bled down, but easy latch. No correction at 9031' EOP flag. RIH with liner to 11425'. 4/12/2001 00:00 - 02:30 2.50 CASE COMP Work liner to 11430'. No further progress. TeL at 9078'. 02:30 - 04:30 2.00 CASE COMP Unsting from GS. Circulate hole to 9.2 ppg brine. 04:30 - 05:30 1.00 CASE COMP Lay in 35 bbls 6 ppb lith hypo water in liner. 05:30 - 09:00 3.50 CASE COMP Park and let soak. 09:00 - 10:30 1.50 CASE COMP RIH displacing bleach. Getting 1:1. 10:30 - 12:00 1.50 CASE COMP I Lay in 35 bbls 9.2 ppg BaradrilI-N with 31 ppg CaCO3. 12:00- 14:00 2.00 CASE COMP POOH. 14:00 - 14:30 0.50 CASE COMP :Set inj on back deck. 14:30 - 15:00 0.50 CASE COMP Safety meeting. 15:00 - 16:30 1.50 CASE COMP Standback 1-1/4" CSH. 16:30 - 18:30 2.00 STWHIP WEXIT Prep for slack management. Pump hot KCL water to pits. 18:30 - 20:00 1.50 STWHIP WEXIT Change-out packoff. 20:00 - 22:45 2.75 STWHIP WEXIT Reverse methanol out of coil with hot KCL water. Surge to move cable. Cut pipe. Cable only moved a couple of feet. Repeat surge. Couple more feet. Call this good 22:45 - 00:00 1.25 STWHIP WEXlT Cut 250' of pipe for fatigue management. 4/13/2001 00:00 - 02:30 2.50' STWHIP WEXlT Install CTC. Pull test. Re-head E-line tools. 02:30- 04:00 1.50 S'FWHIP WEXIT ' MU whipstock BHA. 04:00- 13:30 9.50 STWHIP BHA WEXlT RIH to 3900'. Lost communication with tools. Short. POOH. Had ~ulled out of weak point. We obviously slacked-off on our slack management. Reverse circulate again 3.5 BPM. Got 6' of cable movement. Re-head. Pump forward at 3.5 BPM to get slack distributed back to downhole end of coil. Heard cable rattle around for about 30 sec. MU BHA. 13:30 - 15:00 1.50 STWHIP WEXIT MU and RIH with whipstock. 15:00 - 15:30 0.50 S'I'WHIP WEXIT Log tie-in. Correct depth (-4'). 15:30 - 16:15 0.75 STVVHIP WEXIT RIH to 9078' clean (did not set down) while orienting whipstock face straight down. PUH. RIH to 9075'. Pressure coil to set whipstock. Sheared setting tool at 2400 psi. Stack 5k down on whipstock. Good. Whipstock top 9062'. 16:15 - 17:30 1.25 STVVHIP WEXIT POOH. Flag pipe at 8800' EOP. 17:30 - 18:45 1.25 STWHIP WEXIT LD BHA. 18:45 - 19:30 0.75 STWHIP VVEXIT Set TWC valve. 19:30 - 20:00 0.50 STWHIP WEXlT Safety meeting. 20:00 - 00:00 4.00 STWHIP WEXlT Perform weekly BOP test. 4/14/2001 00:00 - 02:00 2.00 STWHIP WEXlT Continue weekly BOP test. 02:00 - 04:00 2.00 STWHIP TEST WEXlT Downtime to fix Triplex pump and replace 2-7/8" ram rubbers (SI rams on no-go). Printed: 5/112001 10:29:37 AM BP EXPLORATION Page 8 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/14/2001 04:00 - 06:00 2.00 STWHIP WEXlT Finish BOP test. 06:00 - 06:30 0.50 STVVHIP WEXIT Safety meeting. 06:30 - 07:00 0.50 STVVHIP WEXlT Stab inj. PT stripper and inner reel valve. 07:00 - 08:30 1.50 STWHIP WEXIT Wait on crew to pull TWC. Pull it. 08:30 - 09:30 1.00 STWHIP WEXIT Displace methanol from coil. 09:30 - 10:30 1.00 STWHIP, WEXIT MU milling BH^ #11 (2.5 deg motor; tapered DSM) 10:30- 12:15 1.75 S'I'WHIP WEXlT RIH 12:15 - 12:45 0.50 STWHIP WEXIT Tie-in at 8700'. Correct depth (-3'). 12:45 - 13:00 0.25 STWHIP WEXIT RIH and dry tag whipstock 9062'. PUH. Est circ 2.5/3250'. 13:00 - 17:00 4.00 STWHIP WEXIT Time mill at 180 TF from 9060' to 9062.5'. 17:00- 18:45 1.75 STWHIP WEXIT POOH. 18:45 - 20:00 1.25 STWHIP WEXIT Swap 2.5 deg motor and mill with straight motor and tapered DSM + string mill. 20:00 - 21:30 1.50 STWHIP WEXIT RIH with BHA #12. 21:30 - 21:45 0.25 STWHIP WEXlT Log tie-in. Correct depth (-2'). 21:45 - 22:00 0.25 STWHIP WEXIT RIH with pumps 2.5/3050. Stall at 9061'. PUH. RIH slow. Motor work starting 9060.7'. 22:00 - 00:00 2.00 STWHIP WEXlT Mill window. 4/15/2001 00:00 - 01:45 1.75 STWHIP WEXlT Mill window to 9067.5'. Couple stalls, then popped thru here. Good ROP in formation. E-line signal going, going, then gone. 01:45 - 02:30 0.75 S'I'WHIP WEXlT Drill formation to 9079' 02:30 - 05:15 2.75 STWHIP WEXlT Ream and backream window. Dry tag clean. Start swapping well over to FIo-Pro. 05:15 - 07:30 2.25 STWHIP WEXIT POOH displacing well to FIo-Pro. 07:30 - 08:15 0.75 STWHIP WEXIT LD milling BHA. 08:15 - 10:15 2.00 STWHIP BHA WEXlT Troubleshoot short. Cable head OK. EDC OK. Short in OXP tool. Swap to different OXP. 10:15 - 11:00 0.75 DRILL PROD2 MU drilling BHA (1.4 deg motor; used DS49 bit). 11:00 - 12:45 1.75 DRILL PROD2 RIH. Sat down at 6264' with 110L TF. Repeat tag. Orient straight down. Run past tight spot. 12:45 - 14:45 2.00 DRILL FILL PROD2 RIH circulating thru bit to 8200'. Some sort of trash staying with us. Open circ sub. CBU at 3.1 BPM; 3700 psi (that's all we can get out of the pump). Bunch of metal puking-out over the shakers. Close circ sub and motor on down to 8900'. Open circ sub and again CBU. 14:45 - 15:15 0.50 DRILL PROD2 Tie-in. Correct depth (-4'). Run thru window clean with Iow side TF. 15:15 - 16:45 1.50 DRILL PROD2 Tag 9077'. Drill 2.5 BPM, 180 TF at 80 - 90 FPH to 9160'. 16:45 - 18:15 1.50 DRILL PROD2 Start working TF up. Drill 18:15 - 21:45 3.50 DRILL PROD2 Short trip to window. Drill to 9460'. 50-90 ft/hr pump pressure 3740 psi. Inside bha pressure 3300 psi, out side bha pressure 2575 psi @ 2.4 bpm. 21:45 - 00:00 2.25 DRILL LOG PROD2 OXP failure. POH 4/16/2001 00:00 - 03:45 3.75 DRILL BHA PROD2 LD BH^ #13. MU BHA #14 (new OXP). RIH. Tie-in and correct depth (-6'). 03:45 - 05:00 1.25 DRILL PROD2 'Drill to 9620'. 05:00 - 06:00 1.00 DRILL PROD2 Wiper to window. RIH at min rate. 06:00 - 08:00 2.00 DRILL PROD2 Drill to 9800'. BH AP = 2650 psi (650 psi annular friction). 08:00 - 09:45 1.75 DRILL PROD2 Wiper trip to window. Log tie-in. Looks like RA is at 9069' corrected. 09:45 - 11:45 2.00 DRILL PROD2 Drill to 9986'. BH AP approaching 2700 psi. Drill solids at 0.9%. Call for mud. 11:45 - 12:45 1.00 DRILL PROD2 Wiper to window. 12:45 - 15:30 2.75 DRILL PROD2 Drill to 10106'. Hit hard spot here. TF and inclination did a dance. 15:30 - 16:30 1.00 DRILL PROD2 Drill at a snails pace with -10k to 10132'. Stacking. 16:30 - 18:00 1.50 DRILL PROD2 Wiper to window. No motor work seen. Printed: 511/2001 10:29:37 AM BP EXPLORATION Page 9 of 11 Operations Summar Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/2012001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/16/2001 18:00 - 20:10 2.17 DRILL PROD2 Drilling at 10283. Pump pressure 3756 psi, Inside BHA pressure 3327 psi, Out side BHA pressure 2756 psi. @ 2.3 bpm. ECD 12.7 20:10 - 21:20 1.17 DRILL PROD2 Circular in new mud. Pump pressure 3524 psi BHA pressure 3272 psi, Out side BHA pressure 2688 psi. @ 2.4 bpm. ECD 12.4 21:20 - 00:00 2.67 DRILL PROD2 Short trip. drill to 10465. Pump pressure 3548 psi BHA pressure 3230 psi, Out side BHA pressure 2703 psi. @ 2.4 bpm. ECD 12.5 4/17/2001 00:00 - 00:10 0.17 DRILL PROD2 Drill to 10480'. Not seeing much change in pressures since mud swap. BH annular pressure still hanging around at about 2700 psi. 00:10 - 01:30 1.33 DRILL PROD2 Wiper trip to window. 01:30 - 03:00 1.50 DRILL PROD2 Drill to 10650'. 03:00 - 04:45 1.75 DRILL PROD2 Wiper to window. Hole in good shape. 04:45 - 08:30 3.75 DRILL PROD2 Drill. Hit hard spot at 10743'. Little sticky on pickup. Drill to 10776' 08:30 - 10:15 1.75 DRILL PROD2 Wiper to window while looking at the geo picture. Slight motor work at 9631', otherwise very clean. 10:15 - 12:15 2.00 DRILL PROD2 Drill with neg wt. and lots of stacking to 10880'. BH AP up to 2830 psi. About -10k wt off bottom RIH. 12:15 - 16:00 3.75 DRILL PROD2 Wiper to window. Wiper to 2200' at 2.6 BPM. Open circ sub and RIH at 3.0 BPM. 16:00 - 16:30 0.50 DRILL PROD2 Log tie-in at 8700'. Correct depth (+15'). RA coming in at 9071' corrected. Tag'd something at 9081'. PU. RI and fell thru clean. 16:30 - 17:15 0.75 DRILL PROD2 RIH to TD. 17:15 - 18:30 1.25 DRILL PROD2 Drill. Took off running 100+ FPH. Also, BH AP = 2730 psi (100 psi less than before the long wiper trip). Drilled to 11029'. 18:30 - 21:10 2.67 DRILL ; PROD2 Wiper trip to window. Pump min rate RIH. Tagged at 10700' Orient TF to 80R then went through okay. Work weight transfer last 5' to bottom. 21:10 - 21:15 0.08 DRILL PROD2 Drill to 11030'. Lost power to BHA. (Generator to BHI went down on "low oil" shut-off.) 21:15 - 21:35 0.33 DRILL PROD2 Restart generator. 21:35 - 23:15 1.67 DRILL PROD2 Resume drilling. 3650 psi 2.3 bpm 1.5klbs WOB 2750 BH AP. Drilled to 11200°. 23:15 - 00:00 0.75 DRILL PROD2 Start wiper trip to window. 4/18/2001 00:00 - 01:30 1.50 DRILL PROD2 Finish wiper trip. No problems. ;01:30 - 02:45 1.25 DRILL PROD2 11200' drilling ahead 100+ fph, 3775 psi 2.3/2.3, 1.6 klbs WOB, 2775 BH AP. Drill to 11350'. 02:45 - 05:45 3.00 DRILL PROD2 I Wiper trip to window. 05:45 - 06:05 0.33 DRILL PROD2 i Stacking weight just off bottom. Drill to 11372'. Stacking weight. Can't get back to bottom 06:05 - 07:30 1.42 DRILL PROD2 Wiper trip to 10200'. Struggle with slide getting back to bottom. Also, looks like a small ledge at about 10630'. 07:30 - 08:30 1.00 DRILL PROD2 Drill to 11383°. Stacking. Pump fresh mud pill while waiting on new mud. Drill to 11500'. 08:30 - 12:30 4.00 DRILL PROD2 Wiper trip to 2000' at 2.8 BPM. Open circ sub. RIH washing at 3.3 BPM out. 12:30 - 13:00 0.50 DRILL PROD2 Log tie-in at 8700'. Correct depth (+13'). PA, at 9072'. 13:00 - 14:00 1.00 DRILL PROD2 RIH. Tag TD 11,510' corrected. 14:00 - 17:00 3.00 DRILL PROD2 Wiper to window while displacing well to new FIo-Pro. Open circ sub and POOH circulating 3.1 BPM. Bump up. E-counter at 60.2'. 17:00 - 17:30 0.50 DRILL PROD2 Freeze protect coil. 17:30 - 19:30 2.00 DRILL PROD2 I./D BHA set back injector. 19:30 - 21:45 2.25 DRILL PROD2 PJSM. PJD rig//4 coil from injector and PJU ROC 2 3/8" coil. Prep rig floor for running liner. 21:45 - 22:20 0.58 CASE COMP PJSM running liner and CSH inner string. 22:20 - 00:00 1.67 CASE COMP Make up 2 7/8" 6.16~ STL Slotted liner. Printed: 5/1/2001 10:29:37AM BP EXPLORATION Page 10 of 11 Operations Summa Report Legal Well Name: MPH-08 Common Well Name: MPH-08B Spud Date: 9/3/1997 Event Name: REENTER+COMPLETE Start: 3/27/2001 End: 4/20/2001 Contractor Name: NABORS Rig Release: 4/20/2001 Group: COIL Rig Name: N^BORS 3S Rig Number: Sub Date From - To Hours Task Code Phase Description of Operations 4/19/2001 00:00 - 03:00 3.00 CASE COMP Continue M/U 2 7/8" 6.16~ STL Slotted liner. 03:00 - 06:30 3.50 CASE COMP Make up 1 1/4" CSH inner string. Stab into pack-off bushing, PU, and space-out. MU GS spear and 2-3/8" collar. Close 2-3/8" slip rams/ 06:30 - 07:00 0.50 CASE COMP Safety meeting. 07:00 - 09:00 2.00 CASE COMP Rehead. Pull test CTC. Fill coil with mud. MU disc, CV, circ sub. 09:00 - 22:45 13.75 CASE COMP RIH. 28k up; 3k down at window. RIH. Sat down at 10110', but fell thru. Sat down hard at 10820' (good slide until here). Unable to work past. PU and GS unstung from liner. Spent the next two hours trying to latch liner, including pulling washstring up near liner top to wash profile. Finally latched, PU, and RIH clean past 10820'. Work liner to 10885'. PU and lost liner again. Took about 15 attempts to latch liner. Consider POOH to swap GS with CTLRT. Pull liner uphole to 10787'. Nope - wrong idea. Pulled to 70k here. So much for getting liner back out; past point of no return. Continue working liner downhole, stacking to -20k. GS spear releases after every stack-out, but relatching becoming easier. Circulate 20 bbl slugs (2.5 BPM; 4000 psi) as needed when progress slows. Relatching more difficult after pumping and bleeding (must still be some minor flow across GS). Work pipe to 11,485'. TOL at 9030'. No further progress after a couple of pump and push cycles. 22:45 - 23:00 0.25 CASE COMP Unsting GS spear. 23:00 - 23:30 0.50 CASE COMP Safety meetng -- spotting bleach and displacing mud. 23:30 - 00:00 0.50 CASE COMP (EOP at 11445') Start displacement of FIo-Pro from wellbore w/50 bbl 9.2 ppg 3% KCL. 4120/2001 00:00 - 01:00 1.00 CASE COMP Continue pumping 50 bbl 9.2 ppg 3% KCL, 35 bbl bleach, followed by 29 bbl KCL. Then lay-in bleach 1:1 f/11445' to 9050'. 01:00 - 01:30 0.50 CASE COMP Switch to KCL and displace remaining FIo-Pro from wellbore. 01:30 - 05:00 3.50 CASE COMP Circulate at min. rate and WO bleach. Getting 1:1 -- no losses. 05:00 - 05:45 0.75 CASE COMP Clean out to 11440°. Circulate out bleach to tiger tank. 05:45 - 08:00 2.25 CASE COMP TOH to 1 1/4" CSH tubing pumping at 1.2 bpm / 75 fpm. 08:00 - 09:00 1.00 CASE COMP Unstab. Finish filling coil with methanol. LD GS spear and MHA. 09:00 - 09:30 0.50 CASE COMP Safety meeting. 09:30 - 12:30 3.00 CASE COMP LD 75jts 1-1/4" CSH. 12:30 - 13:00 0.50 CASE COMP RU on IA and PT to 2100 psi with diesel. Bled to 2050 psi in 15 minutes. Bleed to zero. 13:00 - 15:00 2.00 RIGD COMP Bring inj to floor. Install nozzle. Blow down ROC with N2. Leaving methanol down to 100'. Bleed-off. 15:00 - 16:00 1.00 RIGD COMP Pull inj to deck. Unstab ROC. 16:00- 17:00 1.00 RIGD COMP Set BPV. 17:00 - 18:00 1.00 RIGD COMP Stab E-line coil in inj. = 18:00 - 22:00 4.00 RIGD COMP P,/D Dowell ROC unit and move off.. Clean 3S rig mud tanks. R/D Dowell unit ~ take to Deadhorse for routine maintainence. 22:00 - 23:30 1.50 RIGD COMP N/D BOP stack. Install wellhead cap and test to 3400 psi - okay. Nabors rig #3S released at 2300 hrs 4-20-01. Last report. Printed: 5/1/2001 10:29:37AM BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 512512001 Time: 12:19:45 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD) Reference: 18: 08 11812000 03:00 65.7 Well: . MPH-08 Section (VS) Reference: User (0.00N,0.00E,152.05Azi) ,_ ._Wel!p_ath_:.,...M_P__H.-_O8B.L:! s.u_~,e.y__Ca_lC.u!a_?.°n._M_et_h.°.d:_ .... M.!n_!..m_u.m. c_u.~a!u_r,e ........ Db-'._ 0..fa_cie_ .... 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: i Site: M pt H Pad ~ TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6008971.91 ft Latitude: 70 26 6.665 N From: Map Easting: 555404.91 ft Longitude: 149 32 53.895 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.43 deg MPH-08 Well Position: +N/-S 938.18 ft Northing: 6009918.79 ft Latitude: 70 26 15.891 N +E/-W 1186.61 ft Easting: 556584.40 ft Longitude: 149 32 19.068 W ] Po?!t?n_.U?e.rta_in!y: 0:00' ff. ............................................................................................................. Wellpath: MPH-08BL1 Drilled From: MPH-08A 500292280860 Tie-on Depth: 9063.00 ft Current Datum: 18: 08 1/8/2000 03:00 Height 65.68 ft Above System Datum: Mean Sea Level Magnetic Data: 4/12/2001 Declination: 26.30 deg Field Strength: 57442 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 152.05 ..'.::.:.' ::-..-.i:::.~::: :':": :. ::: :. Survey: MWD Start Date: 4/18/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation ft ..... :..~.:; ............... L:........ :~.:.: .......... : ...................... ... .::.......: ......... :~....:...:._...., ......... ....L..:..... ........... / 9063 00 4150 48 KOP "'''~ ;' ;'- !: '{; ?' ;'., ' '. 11510 00 4253 08 Projected to TD .... ' ' Survey ......... : MD: : lncl Azlm TVD : SSTVD :N!S: E/W' :, M'aPN' MapE DLS VS, : ft 'deg dog. ': :'ft .... : · ff.:: : ~;~,ttr~?~,,~dea/100ff:: ff . 9063.00 74.94 144.05 4150.48 4084.80 -3636.43 6038.57 6006328.63 562649.8J~C.~,~.~Q~ ~ 6042.~'55~ 9090.00 66.60 145.00 4159.36 4093.68 -3657.17 6053.36 6006308.01 562664.75~ '"~'~!:~ 6067.80 9210.00 66.60 136.50 4213.88 4148.20 -3738.82 6121.88 6006226.88 562733.88 15.38 6172.04 9240.00 70.60 137.50 4224.83 4159.15 -3759.24 6140.93 6006206.60 562753.08 13.69 6199.01 9272.00 75.10 139.70 4234.26 4168.58 -3782.18 6161.14 6006183.83 562773.46 15.52 6228.74 9300.00 78.80 138.90 4240.58 4174.90 -3802.85 6178.92 6006163.29 562791.40 13.50 6255.34 9330.00 84.00 139.90 4245.07 4179.39 -3825.37 6198.22 6006140.92 562810.86 17.64 6284.27 9360.00 89.50 138.75 4246.77 4181.09 -3848.07 6217.73 6006118.37 562830.55 18.73 6313.48 9390.00 92.20 134.30 4246.32 4180.64 -3869.83 6238.36 6006096.77 562851.34 17.35 6342.37 9421.00 94.10 134.95 4244.62 4178.94 -3891.58 6260.39 6006075.19 562873,53 6.48 6371.90 9450.00 92.80 130.05 4242.87 4177.19 -3911.13 6281.73 6006055.81 562895.01 17.45 6399.17 9480.00 90.45 125.10 4242.02 4176.34 -3929.41 6305.48 6006037.71 562918.91 18.26 6426.45 9511.00 89.90 120.30 4241.93 4176.25 -3946.15 6331.56 6006021.17 562945.11 15.59 6453.47 9541.00 89.50 115.70 4242.08 4176.40 -3960.23 6358.04 6006007.29 562971.70 15.39 6478.32 9570.00 89.50 112.40 4242.34 4176.66 -3972.04 6384.52 6005995.68 562998.26 11.38 6501.16 9120.00 63.00 145.50 4172.13 4106.45 -3679.47 6068.83 6006285.83 562680.38 12.09 6094.75 9150.00 60.30 136.70 4186.40 4120.72 -3700.00 6085.36 6006265.42 562697.07 27.33 6120.63 9180.00 62.00 136.90 4200.88 4135.20 -3719.15 6103.35 6006246.41 562715.20 5.70 6145.98 Obp BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 5/25/2001 Time: 12:19:45 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD)Reference: 18: 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: User (0.00N,0.00E,152.05Azi) We#path: MPH-08BL1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ft deg deg ff ff ft ft ft ff deg/lOOft ft 9600.00 89.60 108.45 4242.57 4176.89 -3982.51 6412.63 6005985.43 563026.44 13.17 6523.58 9630.00 89.10 102.80 4242.91 4177.23 -3990.59 6441.51 6005977.57 563055.38 18.91 6544.25 9660.00 88.10 104.00 4243.65 4177.97 -3997.54 6470.68 6005970.84 563084.60 5.21 6564.07 9690.00 88.90 109.20 4244.43 4178.75 -4006.10 6499.41 6005962.50 563113.39 17.53 6585.10 9720.00 90.80 112.30 4244.51 4178.83 -4016.73 6527.46 6005952.08 563141.52 12.12 6607.63 9750.00 90.20 116.30 4244.25 4178.57 -4029.07 6554.80 6005939.95 563168.94 13.48 6631.35 9780.00 89.30 120.30 4244.38 4178.70 -4043.29 6581.20 6005925.93 563195.46 13.67 6656.29 9810.00 89.70 125.00 4244.64 4178.96 -4059.47 6606.46 6005909.95 563220.83 15.72 6682.41 9840.00 89.50 127.90 4244.85 4179.17 -4077.29 6630.58 6005892.31 563245.09 9.69 6709.47 9870.00 90.00 131.50 4244.98 4179.30 -4096.45 6653.66 6005873.33 563268.31 12.12 6737.21 9900.00 90.00 136.20 4244.98 4179.30 -4117.23 6675.29 6005852.72 563290.09 15.67 6765.70 9930.00 89.70 138.50 4245.06 4179.38 -4139.29 6695.61 6005830.81 563310.58 7.73 6794.71 9960.00 88.20 143.70 4245.61 4179.93 -4162.63 6714.44 6005807.62 563329.59 18.04 6824.15 9990.00 88.40 148.20 4246.50 4180.82 -4187,47 6731.23 6005782.91 563346.56 15.01 6853.96 10020.00 88.00 151.60 4247.44 4181.76 -4213.40 6746.26 6005757.09 563361.79 11.41 6883.92 10050.00 87.90 154.00 4248.52 4182.84 -4240.07 6759.97 6005730.54 563375.69 8.00 6913.90 10080.00 89.40 159.80 4249.22 4183.54 -4267.64 6771.73 6005703.06 563387.66 19.96 6943.77 10120.00 91.20 167.50 4249.01 4183.33 -4305.99 6782.98 6005664.79 563399.20 19.77 6982.92 10150.00 90.75 170.30 4248.50 4182.82 -4335.43 6788.75 6005635.41 563405.20 9.45 7011.62 10172.00 90.50 173.80 4248.26 4182,58 -4357,21 6791.80 6005613.65 563408.41 15.95 7032.29 10200.00 91,10 177.60 4247.87 4182.19 -4385.12 6793.90 6005585.76 563410.72 13.74 7057.93 10234.00 91.40 182.50 4247.13 4181.45 -4419.10 6793.87 6005551.78 563410.94 14.44 7087.94 10258.00 93.10 185.30 4246.19 4180.51 -4443.03 6792.24 6005527.85 563409.50 13.64 7108.31 10290.00 96.65 189.50 4243.47 4177.79 -4474.63 6788.13 6005496.21 563405.63 17.15 7134.30 10321.00 95.80 192.60 4240.11 4174.43 -4504.88 6782.23 6005465.93 563399.96 10.31 7158.25 10350.00 95.35 197.45 4237.29 4171.61 -4532.74 6774.75 6005438.01 563392.69 16.72 7179.36 10380.00 94.15 201.30 4234.80 4169.12 -4560.94 6764.83 6005409.74 563382.99 13.40 7199.62 10410.00 93.15 199.90 4232.89 4167.21 -4588.96 6754.30 6005381.64 563372.67 5.73 7219.44 10445.00 93.30 195.80 4230.92 4165.24 -4622.22 6743.59 6005348.31 563362.21 11.70 7243.79 10471.00 93.50 190.70 4229.38 4163.70 -4647.47 6737.64 6005323.01 563356.46 19.60 7263.32 10500.00 92.10 185.25 4227.96 4162.28 -4676.15 6733.62 6005294.31 563352.66 19.38 7286.76 10531.00 91.60 181.75 4226.96 4161.28 -4707.07 6731.73 6005263.38 563351.00 11.40 7313.19 10559.00 93.80 178.30 4225.64 4159.96 -4735.03 6731.72 6005235.42 563351.20 14.60 7337.89 10590.00 95.10 174.80 4223.24 4157.56 -4765,88 6733.58 6005204.59 563353.30 12.01 7366.01 10621.00 95.35 168.15 4220.41 4154.73 -4796.39 6738.15 6005174,12 563358.10 21.38 7395.10 10650.00 94.80 162.75 4217.84 4152.16 -4824.34 6745.41 6005146.23 563365.57 18.64 7423.19 10679.00 91.95 157.10 4216,13 4150.45 -4851.52 6755.34 6005119.13 563375.70 21.79 7451.85 10710.00 90.80 153.45 4215.39 4149.71 -4.879.66 6768.30 6005091.09 563388.88 12.34 7482.79 10740.00 90.00 147.80 4215.18 4149.50 -4905.79 6783.01 6005065.07 563403.78 19.02 7512.77 10770.00 89.20 143.90 4215.39 4149.71 -4930.61 6799.85 6005040.38 563420.81 13.27 7542.59 10800.00 88.70 137.10 4215.94 4150.26 -4953.74 6818.91 6005017.40 563440.05 22.72 7571.96 10830.00 87.00 131.90 4217.07 4151.39 -4974.75 6840.29 6004996.56 563461.58 18.22 7600.53 10860.00 87.00 135.00 4218.64 4152.96 -4995.35 6862.04 6004976.12 563483.48 10.32 7628.92 10890.00 88.40 137.80 4219.84 4154.16 -5017.06 6882.70 6004954.58 563504.31 10.43 7657.78 10920.00 87.20 140.90 4220.99 4155.31 -5039.80 6902.23 6004931.99 563524.00 11.07 7687.02 10958.00 87.30 148.90 4222.82 4157.14 -5070.82 6924.04 6004901.13 563546.04 21.03 7724.65 10982.00 87.35 152.45 4223.94 4158.26 -5091.72 6935.78 6004880.32 563557.94 14.78 7748.61 11010.00 86.10 157.70 4225.54 4159.86 -5117.06 6947.55 6004855.07 563569.91 19.24 7776.52 11041.00 84.55 160.70 4228.07 4162.39 -5145.94 6958.53 6004826.28 563581.10 10.86 7807.17 11070.00 85.10 165.60 4230.68 4165.00 -5173.58 6966.89 6004798.72 563589,67 16.93 7835.50 11106.00 85.70 171.70 4233.57 4167.89 -5208.74 6973.95 6004763.61 563597.00 16.97 7869.88 11136.00 85.30 175.20 4235.93 4170.25 -5238.45 6977.36 6004733.93 563600.63 11.71 7897.72 ., Obp BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 5/25/2001 Time: 12:19:45 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVD) Reference: 18 ' 08 1/8/2000 03:00 65.7 Well: MPH-08 Section (VS) Reference: User (0.00N,0.00E,152.05Azi) Wellpath: MPH-08BL1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey ft deg deg ff ff ft ft ff ft deg/lOOft ff 11161.00 85.00 181.10 4238.04 4172.36 -5263.34 6978.17 6004709.05 563601.63 23.55 7920.08 11190.00 86.40 181.50 4240.22 4174.54 -5292.25 6977.51 6004680.14 563601.19 5.02 7945.31 11221.00 87,80 181.45 4241.79 4176.11 -5323.19 6976.71 6004649.19 563600.63 4.52 7972.27 11249.00 87.70 178.70 4242.89 4177.21 -5351.17 6976.68 6004621.22 563600.80 9.82 7996.97 11280.00 88,60 171.70 4243.89 4178.21 -5382.03 6979.27 6004590.39 563603.63 22.75 8025.44 11310.00 89.10 168.35 4244.49 4178.81 -5411.56 6984.46 6004560.89 563609.05 11.29 8053.97 11340.00 88.80 161.60 4245.04 4179.36 -6440.52 6992.24 6004532.00 563617.04 22.52 8083.18 11370.00 87.70 154.20 4245.96 4180.28 -5468.28 7003.51 6004504.33 563628.52 24.93 8112.99 11400.00 87.20 149.10 4247.29 4181.61 -5494.65 7017.73 6004478.07 563642.95 17.06 8142.95 11430.00 86.50 143.00 4248.94 4183.26 -5519.48 7034.45 6004453.37 563659.85 20.44 8172.73 11467.00 87.20 138.80 4250.98 4185.30 -5548.15 7057.75 6004424.88 563683.36 11.49 8208.97 11510.00 87.20 138.80 4253.08 4187.40 -5580.46 7086.04 6004392.79 563711.89 0.00 8250.77 BP Amoco Parent Wellpath: Tie on MD: Rig: Ref. Datum: V.Section Angle 152.05° WELLPATH DETAILS MPH-O8BLt 500292280660 MPH-08A 9063.00 18: 08 1/8/2000 03:00 65.68ff Origin Origin Starting +N/-S +FJ-W From TVD 0.00 0.00 0.09 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Welt Centre: MPH-08, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: User Defined (0.00N,0.00E) Measured Depth Reference: 18: 08 1/8/2000 03:00 65.68 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annotation 4084.80 9063.00 KOP 4187.40 11510.00 Projected to ~D 3100 3200d ~j~3300-~--- --{ ,~ 3700 ~ -- MPH-08 (MPH-08) [ /~. ~x Magnetic Nodh: 26.30° ~ Created By: Bdj Potnis Date: 5~25/2001 ~' ';-i_. ' MM,~i~B(LMIPH-08 1) Maonetic Field .... ,n' "n MPH-08 (MPH-08B)I I /- Stren '~ 57442nT / bomac~ mrmauo : ~ . .~ Dip ~'~le: 80.77° / Direct: (907)267-6613 ~ ~ ~.¢_~ i Date: 4,12,2001 ! E-mail: brij.potnis@inleq corn = .~..~; Model: / Baker Hughes INTEQ: (907) 267-6600 U ~ 3900-- 4000 --- 4100 _ '--...~. . -3200 2- . . ~ ---.~_ . : ........ '"'9;, "~. ~ '~.~ . . - . P~ to ~ ", -5~ -6~ .......... t, ' M PH~8 ~PH~A)' ~ , ~200 - - ............. ~00 46~ 4800 ~ 5200 ~ 5600 58~ 6~ 62~ ~00 ~ 68~ 7~ 7200 74~ 7600 7800 8~0 82~ ~00 86~ 88~ 9~ 9200 94~ ~00 West(-)lEast(+) [200~in] -- '- - :- ' - "'%...--. -- -- ~, KOP~ : MPH-08 (MPH-08BPBI~ , MPH-08 (MPH-OSAPB1) -; MPH-O8 (MPH-OSB): : Projected to TD~ ,. ~ MPH-O8 .... 4200 4300 4400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 Vertical Section at ~ 52,05° [t OOft/in] _ _ 5/25/2001 12:38 PM ALASKA OIL AN~D GAS CO~SERYATIO~I COMMISSIO~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPH-08BL1 BP Exploration (Alaska) Inc. Permit No: 201-048 Sur Loc: 2767'NSL, 4061'WEL, Sec. 34, T13N, R10E, UM Btmhole Loc. 987'NSL, 1987'WEL, Sec. 01, T12N, R10E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissioner BY ORDER OF THE COMMISSION DATED this ~// Y 7- day of March, 2001 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA{" _ AND GAS CONSERVATION COMNi" ~ION PERMIT TO DRILL 20 ~C 25.005 la. Type of work [] Ddll [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65.68' AMSL Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 380109 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2767' NSL, 4061' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 4404' NSL, 3301' WEL, SEC. 01, T12N, R10E, UM MPH-08BL1 Number 2S100302630-277 At total depth 9. Approximate spud date 987' NSL, 1987' WEL, SEC. 01, T12N, R10E, UM 03/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 380110, 1987' MDI No Close Approach 2560 13000' MD/4181' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9075' MD Maximum Hole Angle 91 o Maximum surface 1400 psig, At total depth (TVD) 4000'/1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade CouplinR Len,qth MD TVD MD TVD (include staqe data) 3-3/4" 2-7/8" 6,16# L-80 ST-L 4099' 9065' 4086' 13000' 4181' Uncemented Slotted Liner ~[r-L~ ~1 v I- lg. To be oompleted for Redrill, Re-entry, and Deepen Operations. Present well oondition summary Total depth: measured 12164 feet Plugs (measured) M,/~J~ 0: ~ Z00J true vertical 4235 feet Effective depth: measured 12164 feet Junk (measured) Alaska 0il & Gas Cons. Commission true vertical 4235 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 9222' 7" 2047 sx PF 'E', 263 sx 'G', 191 sx PF 'C' 9253' 4376' Intermediate Production Liner 981' 4-1/2" 46 sx Class 'G' 8436' - 9417' 3799' - 4183' Perforation depth: measured 4-1/2" Slotted Liner: 9047' - 9373' 6" Open Hole Completion: 9417' - 12164' true vertical 4-1/2" Slotted Liner: 4147' - 4184' 6" Open Hole Completion: 4183' - 4235' '20. Attachments [] Filing Fee [] Property Plat ' [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 'Prepared By Name/Number: Terrie Hubble, 564~4628 21. I hereby certify that the foregoing is tru~ correct to the best of my knowledge ' ~ ,, "' Signed Mark Johnson ~~ ~. x~,~,......_~., Title CT Drilling Engineer Date ~2__~o¢o/' Permit Number I APl Nq~r~r I., / Al:~roval Date I See cover letter o/- 5" S" 150-029-22808-60I, / Ifor other requirements Conditions of Apl~roval: Samples Required [] Yes '1~o Mull Lo~l'Required [] Yes ~1o Hydrogen Sulfide Measures [] Yes ~LNo Directional Survey Required 'l~Yes [] No Required Working Pressure for ROPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~i~.5K psi for CTU Other:'",) ,//"~ ////~ ORtGiNA;L. SIGNi:-'D S'/' by order of .,..~ /.., _Approved By D T,~vhm- ,~,Pr':lm©lll-],l Commissioner the commission Date ' / Form 10-401 Rev. 12-01-85 Sut' cate BPX Milne Point MPH-08B & L1 Sidetracks - Coiled Tubing Drilling Summary of Operations: MPH-08A will be sidetracked with two horizontal wellbores (MPH-08B and MPH-08B L1) to target Schrader Bluff OA and OB reserves respectively. Coiled Tubing Ddlling (CTD) will perform the sidetracks. Backqround In February 2001, Nabors 4ES was unable to regain access to the existing horizontal wellbore (MPH-08A) below 9126' DPM due to apparently collapsed 4 %" slotted liner. As such, the plan is to set a cement plug to abandon the MPH-08A (sundry form 10-403 submitted) and then CTD drill MPH-08B in the OA sand (replace MPH-08A) and MPH-08B L1 in the OB sand. Procedures P&A Procedure (sundry form 10-403 already submitted) a) Set whipstock at 9110' in 4 %" slotted liner. - service coil b) P&A MPH-08A by bullheading ~10 Bbls of 15.8 ppg class G cement from just above whipstock. (The cement serves to plug off MPH-08A in the heel area to reduce mud losses while drilling and to further anchor the whipstock). - service coil CTD Drill and Complete MPH-08B proqram: Planned for March 15, 2001 1) MIRU CTD rig. Mill window through 4 %" and mill 5' of openhole 2) Drill horizontal sidetrack MPH-08B from window to TD (13,000') targeting Schrader Bluff OA sand interval as per attached directional plan. 3) Complete with slotted liner from TD (13000') to ~10' inside of 4 %" casing at 9100'. CTD Drill and Complete MPH-08B L1 Lateral pro.qram: Planned for March 21, 2001 4) CTD set flowthrough whipstock at 9075' (in 4 %" casing at ~74° wellbore inclination) 5) Mill window through 4 %" and mill 5' of openhole 6) Drill horizontal lateral MPH-08B L1 from window to TD targeting Schrader Bluff OB sand interval as per attached directional plan. 7) Complete with slotted liner from TD (13000') to ~10' inside of 4 %" casing at 9065'. Mud Program: · Steps 1: Seawater · Steps 2-7: FIo-Pro (8.6-9.4 ppg) RECEIVED Disposal: · No annular injection on this well. · Class II liquids to KRU 1R Pad Class II disposal well · Class II drill solids to PBU DS-4 Grind & Inject · Class I wastes will go to Pad 3 for disposal. AJaska Oil 8, Gas Cons. Commission Anchorage Casing Program MPH-08B: · 2 7/8", 6.16~, L-80, STL slotted/pre perforated liner will be run from TD (13000') to approximately 9100'. Casing Program MPH-08B LI: · 2 7/8", 6.16#, L-80, STL slotted/pre perforated linerwill be run from TD (13000') to approximately 9065'. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. z/ Directional · See attached directional plans · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Resistivity logging in sections of the openhole Hazards Several small faults are expected to be crossed, but lost circulation risk is Iow based on MPH-08A drilling history. Res. pressure is 8.7 ppg. The latest H2S reading (April 2000) on MPH-08a was <2ppm. Highest H2S on the pad is 2.4 ppm (H-6i). Reservoir Pressure Res. pressure is approx. 1800psi @ 4000ss (8.7 ppg). Max. surface pressure with gas (0.1 psi/fi) to surface is 1400 psi. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage MPH-08B & L1 Potential Drilling Hazards Post on Rig . . . . . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut down the operation and discuss the situation before making the next operational move. SAFETY FIRST. H2S is not expected on this well. The latest H2S test on MPH-08a was <2ppm. Maximum H2S measured on the pad was from well H-6i at 2.4 ppm. MPH-08B sidetrack - BHP is expected to be less than 1788psi (8.6ppg) @ 4000'ss. The 4ES remedial work in 2/00 used 8.6 ppg fluid which maintained overbalance on the Schrader OA formation. As such, an 8.6 ppg FIo Pro system should be satisfactory for the MPH-08B horizontal (OA formation). MPH-08B sidetrack- close approach. As indicated in the directional plan, MPH-08B will come within 10' of intersecting MPH-08A at 10150' and MPH- 08APB1 at 10300' MD. Potential intersection is not expected to cause any problems. Both are barefoot holes (no steel) and will be at the same reservoir pressure. MPH-08B L1 sidetrack - BHP is expected to be approx. 1800psi (8.7ppg) @ 4000'ss as it has not been depleted in this area. Mud weight should be 9.2 ppg for this hole section based on the expected pressure. 6. Maximum anticipated well head pressure w/full column of gas is 1400psi. . Several faults (<15' throw) are expected to be crossed in the horizontal sections. However, lost circulation was not a problem when several similar faults were crossed during the drilling of MPH-08A (January 2000). However, be aware of the potential for lost circulation and maintain at least 600 lbs of Liquid Casing on location. RECEIVED UAR 0'1 Alaska Oil & Gas Cons. Commission Anchorage BP Amoco WELLPATH DETAILS Plan#8 MPH-08BL1 500292280860 Parent Wellpath: MPH-08A Tie on MD: 9075.00 Vertical Section Origin: User Defined (0.00,0.00) Vertical Section Angle: 152.05° Rig: Depth Reference: 18: 08 1/8/2000 03:00 65.68ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: MPH-08, True North Vertical ('I-VD) Reference: System: Mean Sea Level Section (VS) Reference: User Defined (0.00,0.00) Measured Depth Reference: 18:081/8/200003:00 65.7 Calculation Method: Minimum Curvature ANNOTATIONS No. TVDMD Annotatio~ 1~4077.07 9030.00 T~e-h Point 4088.01 9075.00 Ki~-off Poklt 3 4117.40 9155.00 4160.87 9339.00 ~ 4157.06 10539.00 7 4158.88 11109.00 5 984161.11 11409.00 76 4165.20 11809.00 10 4172-23 12373.00 8 11 4181.04 13000.40 TD T~C~-r c~T~cs wo ~s ~w ~ I MPH-08BL1) Azimuths to True North I Magnetic North: 26.34° I Created By. Brij PoU~s Da~e: 2rz8/2001 i Magnetic Field! r,:o,m~ct [nfolm.:qion: Strength: 57441nT DipAngle: 80.77°1 D~,;,; :~90;/) 2g7.6613 Date: 2_.f28/2001 Model: BGGM20001 Ba~el ~-I~,,ItL¢;$ h'Jl ECl; (907} :~6Y.§6rJ0 !::i .....~ .:.. · i-'i": "': ~:. :' ' -40o0-'!:'TN".'"" "'~ '!' i' _,,,~ L:i. ~ ........ .', ........ 4 !.'.i!."::.':':i.T:'.i':i'"f ; '' : ..... ( ........ , ?r"'rx';h'":","rT'"!':'"'~ ...... ~' · '~' i : ,."~ , , , R.,'.". i ; , / ........ ' ' ' ' ' ~! 1~- ¢' -~-- : " ': I :. ~~~~%"~ ''b · -~:-~':-i-;-:--i-.-'-.!-.:-..:.--:~ ':. [] ~. % ..-'~ .:- ~:-;-~-i:i----~-:~-::,:;-..-:,!---.!:-~--.-i-:-:-..='i-:~-.+-....-...,.-~ ............ '~ ...... i.:.:'.:..!~.¢ ..... '~ · · ; .".. '':''' IMPlI.8IRI1TIJ' ~:~ ~ : ~, :; ; : ; ',' & ~':¥.~?~' xix: .. :.: ~ :.:. ;: : · · · · · :::::::::::::::::::::::::::: ! ~ .... ?, .... ~- /Ii~' 4300.::1 '%. ' '!'¢"~' ~ h'~'"'".'" "-';'!'~': ', ....... · · ' : · :' · : '::::~:h:;i::":'!::i::i:;i::!::f:?::'+':?:''''':'':':¢' :'" '" "!' ""' ::'"!'"':':"'~'N ~P~'-,~.,, .~.e~,i -'1'! ..... ~ ...... ! .... q ~ · : . : ::::-i..'.i:'i:i'i: : ' : . :'. : ':.ii:i':~::!: i ii:i ! i,~4, ..... ~,',,: ! :. 44oe--1 . . ?:.. i · .'- :-::!:?::--:-~.-hi.:: ..... . -.' ' . -.: · -'.-:i-!:!:-i:!-.:-:-:-:i--!:--:::.-:.:.!-:--.-.!-:,-i-.!¢-:--h~.-..i ............ ! ....... ;-.! ...... ! ......... ! - , -{ · ;~ i' ;:i:: .... · i~i ¢ iii: : ~: ( [: ~ i ! t ~ ! 4 --; --:-~--.i - - . :----..:i-~:---~:!: - -- .- : - : · · : · - · !:.!~!i!:~F~!!:~.-~:i-~,r:!i.:r:!::-::?:-!:::~--~.-~: :i .......... ! ........... t-; ....... i ....... : ....... ! ......... ! ........ · .'..-i..'.. · · -'..~.'.'.,:;,,. · . · i;;ii [ ii i [ ~:: :i: ': i ; ~ ; ; ', 4 ".,.','r .T,,, r,~4~-r'..--..F..-..'rr, ,m',.,-F?'. ;~-m~, ,'?rp~~i-m~-..?i- ?'rri,~,'..';'T . rtT ~~~'rrTT~.~,i , i"" .... 61'00 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 77O0 7800 7900 8000 8100 82~ 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900 Vertical Section at t52.05° [tOOft/in] 2/28/2001 12:14 PM BP Amoco Baker Hughes INTEQ Planning Report Company: :BP Am°co Field: Milne Point M Pt H pad Well: MPH-08 WellPath: Plardf8 MPH-08BL1 Date: 2J28/200;I': T~me: 1I:49:43 Page: 1 Co-ordinate(NE) Reference:. Well: MPH-08, True Not~ Verlical (TVD)Reference: SYstem:Mean :~a Eevel Section (VS) Reference: User (0.00E,0.OON,152.05A2i) Survey CalcUlation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ff 6008971.91 ft 555404.91 ft Latitude: 70 26 6.665 N 149 32 53.895 W r~ Longitude: North Reference: True Grid Convergence: 0.43 deg ~ Well: MPH-08 Slot Name: 08 MPH-08 Well Position: +N/-S 938.18 ft Northing: 6009918.79 ft Latitude: 70 26 15.891 N +E/-W 1186.61 ft Easting: 556584.40 ft Longitude: 149 32 19.068 W Position Uncertainty: 0.00 ft u Wellpath: Plan#8 MPH-08BL1 Drilled From: MPH-08A 500292280860 Tie-on Depth: 9075.00 ft Current Datum: 18:08 11812000 03:00 Height 65.68 ft Above System Datum: Mean Sea Level Magnetic Data: 2/28/2001 Declination: 26.34 de9 Field Strength: 57441 nT Mag Dip Angle: 80.77 de9 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ft ft deg 0.00 0.00 0.00 152.05 Plan: Plan ~8 Date Composed: 2/2812001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets · 'Map ' Map <-- Lalitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Dog Mtn Sec Dog Min. Sec ff ff .ft ft ft MPH-08BL1 Polygon 8.1 0.00 -3325.19 5787.62 6006637.92 562396.52 70 25 43.166 N 149 29 29.278 W -Polygon 1 0.00 -3325.19 5787.62 6006637.92 562396,52 70 25 43.166 N 149 29 29.278 W -Polygon 2 0.00 -3303.40 6220.64 6006663.00 562829.32 70 25 43.377 N 149 29 16.574 W -Polygon 3 0.00 -4206.76 7060.63 6005766.12 563676.06 70 25 34.486 N 149 28 51.956 W -Polygon 4 0.00 -5093.15 7367.78 6004882.17 563989.90 70 25 25.765 N 149 28 42.972 W -Polygon 5 0.00 -6219.63 7817.27 6003759.25 564447.88 70 25 14.682 N 149 28 29.823 W -Polygon 6 0.00 -7082.57 7794.96 6002896.24 564432.12 70 25 6.195 N 149 28 30.503 W -Polygon 7 0,00 -7282.71 7137.39 6002691.14 563776.15 70 25 4.234 N 149 28 49.790 W -Polygon 8 0.00 -4754.46 6473.29 6005214.04 563092.95 70 25 29.104 N 149 29 9.198 W -Polygon 9 0.00 -3549.76 5591.53 6006411.90 562202.16 70 25 40.959 N 149 29 35.035 W MPH-08BL1 T8.1 4154.00 -3642.13 6044.30 6006322.97 562655.57 70 25 40.047 N 149 29 21.755 W MPH-08BL1 T8.2 4161.00 -3830.28 6195.92 6006135.99 562808.60 70 25 38.196 N 149 29 17.312 W MPH-08BL1 T8.3 4157.00 -4763.99 6814,06 6005207.09 563433.75 70 25 29.008 N 149 28 59.203 W MPH-08BL1 T8.4@TD 4181.00 -6906.15 7567.61 6003070.91 564203.46 70 25 7.933 N 149 28 37.165 W Annotation MD TVD 9030.00 4077.07 Tie-in Point 9075.00 4088.01 Kick-off Point 9155.00 4117.40 1 9339.00 4160.87 2 BP Amoco Baker Hughes INTEQ Planning Report ii'~:i:i'i;~ ........................ Company: BP Amoco Field: Milne Point site: M Pt H Pad Well: MPH-0~ Wellpath: Piarff~ MPH-08BL1 Date: 2/28t2001 Time:' 11:49:43 Page: 2 Co-ordinate(NE)Reference: Well:: MPH-0O. Tree North verlicai (TVD)Reference: System! Mean sea LeVel Section (VS) Reference: User (0.00E,0.00N,152.05Azi) Survey CalcUlation Method: Minimum Curvature Db: Oracle Annotation MD TVD i 9639.00 4160.05 3 10539.00 4157.05 4 11109.00 4158.82 5 11409.00 4161.07 6 11809.00 4165.13 7 12373.00 4172.16 8 13000.40 4181.00 TD Plan Section Information MD incl A~m TVD +N~S +E/-W DLS Build Turn TFO Target ff de9 deg ft fl ff deg/100ff deg/100ff deg/100~ deg 9030.00 77.98 145.67 4077.07 -3610.19 6020.11 0.00 0.00 0.00 0.00 9070.92 74.21 143.66 4086.90 -3642.59 6043.07 10.37 -9.21 -4.91 207.13 9075.00 74.40 143.41 4088.01 -3645.75 6045.41 7.52 4.66 -6.13 308.25 9155.00 62.40 143.41 4117.40 -3705.36 6089.66 15.00 -15.00 0.00 180.00 9339,00 90.00 143.41 4160.87 -3847.45 6195.15 15.00 15.00 0,00 0.00 9639.00 90.30 113.41 4160.05 -4031.72 6427.55 10.00 0.10 -10.00 -89.39 10539.00 90.00 203.41 4157.00 -4785.16 6725.68 10.00 -0.03 10.00 90.00 11109.00 89.66 146.41 4158.83 -5329.79 6774.17 10.00 -0.06 -10.00 -90.40 11409.00 89.51 176.41 4161.04 -5610.89 6868.70 10.00 -0.05 10,00 90.40 11809.00 89.37 136.41 4165.13 -5970.05 7025.53 10.00 -0.04 -10.00 -90.40 12373.00 89.32 192.81 4172.19 -6492.10 7169.20 10.00 -0.01 10.00 90.40 13000.40 89.24 129.86 4181.00 -7057.00 7360.00 10.03 -0.01 -10.03 -90.51 Survey MD lncl Azim SSTVD NtS EIW MapN MapE DLS VS TFO Tool ~ deg deg ff ff fl ~ ft deg/100ff ft deg 9030.00 77.98 145.67 4077.07 -3610.19 6020.11 6006354.72 562631.15 0.00 6010.72 0.00 Tie-in 9050.00 76.14 144.70 4081,55 -3626,19 6031.24 6006338.81 562642.40 10.37 6030.07 207.13 MWD 9070.92 74.21 143.66 4086.90 -3642.59 6043.07 6006322.50 562654.35 10.38 6050.10 207.34 MWD 9075.00 74.40 143.41 4088.01 -3645.75 6045.41 6006319.36 562656.71 7.52 6053.99 308.25 Kick-o 9100,00 70.65 143.41 4095.52 -3664.89 6059.62 6006300.33 562671.07 15,00 6077.56 180.00 MWD 9125.00 66.90 143.41 4104.57 -3683.60 6073.51 6006281.73 562685,10 15.00 6100.59 180.00 MWD 9150.00 63.15 143,41 4115,12 -3701.79 6087.02 6006263.64 562698.74 15.00 6123.00 180.00 MWD 9155.00 62.40 143.41 4117.40 -3705.36 6089.66 6006260.09 562701.41 15.00 6127.38 180.00 1 9175.00 65.40 143.41 4126.20 -3719.78 6100.36 6006245.76 562712.22 15.00 6145.14 0.00 MWD 9200.00 69,15 143.41 4135.85 -3738.29 6114.11 6006227.35 562726.11 15.00 6167.93 0.00 MWD 9225.00 72.90 143,41 4143.98 -3757.27 6128.20 6006208.48 562740.34 15.00 6191.30 0.00 MWD 9250.00 76.65 143.41 4150.55 -3776.63 6142.57 6006189.23 562754.86 15.00 6215,15 0.00 MWD 9275.00 80.40 143.41 4155.52 -3796.30 6157.18 6006169.67 562769.61 15.00 6239.36 0.00 MWD 9300.00 84.15 143.41 4158,88 -3816.19 6171.94 6006149.90 562764.52 15.00 6263.85 0.00 MWD 9325.00 87.90 143.41 4160.61 -3836.21 6186.80 6006129.99 562799.54 15.00 6288.50 0.00 MWD 9339.00 90.00 143.41 4160.87 -3847.45 6195.15 6006118.82 562807.97 15.00 6302.34 0.00 2 9350.00 90.01 142.31 4160.87 -3856,22 6201.79 6006110.10 562814.67 10.00 6313.20 270.61 MWD 9375.00 90.04 139.81 4160.86 -3875.66 6217.50 6006090.78 562830.53 10.00 6337,74 270.61 MWD 9400.00 90.06 137.31 4160.84 -3894.40 6234.05 6006072.17 562847.21 10.00 6362.05 270.61 MWD 9425.00 90.09 134.81 4160.80 -3912.40 6251.39 6006054.30 562864.70 10.00 6386.08 270.61 MWD 9450.00 90.12 132.31 4160.76 -3929.63 6269.51 6006037.22 562882.94 10.00 6409.79 270.60 MWD 9475.00 90.14 129.81 4160.70 -3946.05 6288.36 6006020.94 562901.91 10.00 6433.13 270.60 MWD 9500.00 90.17 127.31 4160.63 -3961.63 6307.90 6006005.51 562921.57 10.00 6456.05 270.59 MWD 9525.00 90.19 124.81 4160.55 -3976.35 6328.11 6005990.95 562941.89 10.00 6478.52 270.59 MWD 9550.00 90.22 122.31 4160.46 -3990.17 6348.94 6005977.29 562962.82 10.00 6500.50 270.58 MWD 9575.00 90.24 119.81 4160.36 -4003.06 6370.36 6005964.56 562984.33 10.00 6521.93 270.57 MWD 9600.00 90.27 117.31 4160.25 -4015.01 6392.31 6005952.77 563006,37 10.00 6542,77 270.56 MWD 9625.00 90.29 114,81 4160.13 -4026.00 6414.77 6005941.96 563028.91 10.00 6563.00 270.47 MWD 9639.00 90.30 113.41 4160.05 -4031.72 6427,55 6005936.34 563041.74 10.00 6574,05 270.46 3 9650.00 90,30 114.51 4159.99 -4036.19 6437.60 6005931.95 563051.82 10.00 6582.70 90.00 MWD BP Amoco Baker Hughes INTEQ Planning Report 'i~:ii'i;~ ...................... Company: BP Amoco Date: 2/28/2001 Time: 11:49:43 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-08, True North Site: M Pt H Pad Vertical (TVI)) Reference: System: Mean Sea Level Well: MPH~08 Section (%rS) Reference: User (0,00E,0.OON,152.05Azi) Welipath: Plan~B MPH-08BL1 Survey Calculatien Method: Minimum Curvature Db: Oracle Survey MI) Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg dog ft ft ff ft ft deg/100ft ff deg 9675.00 90.30 117.01 4159.86 -4047.05 6460.12 6005921.26 563074.41 10.00 6602.85 90.01 MWD 9700.00 90.30 119.51 4159.73 -4058.89 6482.13 6005909.59 563096.52 10.00 6623.63 90.02 MWD 9725.00 90.30 122.01 4159.60 .4071.67 6503.61 6005896.97 563118.09 10.00 6644,99 90.03 MWD 9750.00 90.29 124.51 4159.47 -4085.38 6524.52 6005883.42 563139.10 10.00 6666.90 90.04 MWD 9775.00 90.29 127.01 4159.34 -4099.99 6544.80 6005868.97 563159.49 10.00 6689.31 90.06 MWD 9800.00 90.29 129.51 4159.22 -4115.47 6564.43 6005853.64 563179.23 10.00 6712.18 90.07 MWD 9825.00 90.28 132.01 4159.09 .4131.79 6583.36 6005837.46 563198.29 10.00 6735.47 90.08 MWD 9850.00 90.28 134.51 4158.97 -4148.92 6601.57 6005820.47 563216.62 10.00 6759.14 90.10 MWD 9875.00 90.27 137.01 4158.85 -4166.83 6619.01 6005802.70 563234.20 10.00 6783.13 90.11 MWD 9900.00 90.27 139.51 4158.73 -4185.48 6635.65 6008784.17 563250.98 10.00 6807.41 90.12 MWD 9925.00 90.26 142.01 4158.61 4204.84 6651.46 6005764.93 563266.93 10.00 6831.93 90.13 MWD 9950.00 90.26 144.51 4158.50 -4224.88 6666.42 6005745.02 563282.04 10.00 6856.63 90.14 MWD 9975.00 90.25 147.01 4158.39 .-4245.54 6680.48 6005724.46 563296.26 10.00 6881.48 90.15 MWD 10000.00 90.24 149.51 4158.28 -4266.80 6693,63 6005703.30 563309.57 10.00 6906.42 90.17 MWD 10025.00 90.23 152.01 4158.18 -4288.61 6705.84 6005681.59 563321.94 10.00 6931.41 90.18 MWD 10050.00 90.23 154.51 4158.08 -4310.94 6717.09 6005659.35 563333.36 10.00 6956.40 90.19 MWD 10075.00 90.22 157.01 4157.98 -4333.73 6727.35 6005636.64 563343.79 10.00 6981.35 90.20 MWD 10100.00 90.21 159.51 4157.89 -4356.95 6736.61 6005613.49 563353.23 10.00 7006.20 90.21 MWD 10125.00 90.20 162.01 4157.80 .4380.55 6744.85 6005589.95 563361.64 10.00 7030,91 90.22 MWD 10150.00 90.19 164.51 4157.72 .-4404.49 6752.05 6005566.07 563369.02 10.00 7055.43 90.23 MWD 10175.00 90.18 167.01 4157.64 -4428.72 6758.20 6005541.89 563375.35 10.00 7079.72 90.23 MWD 10200.00 90.17 169.51 4157.56 -4453.20 6763.29 6005517.46 563380.63 10.00 7103.72 90.24 MWD 10225.00 90.16 172.01 4157.49 4477.87 6767.30 6005492.82 563384.83 10.00 7127.40 90.25 MWD 10250.00 90.14 174.51 4157.42 -4502.70 6770.23 6005468.02 563387.95 10.00 7150.70 90.26 MWD 10275.00 90.13 177.01 4157.36 -4527.63 6772.08 6005443.11 563389.99 10.00 7173.59 90.26 MWD 10300.00 90.12 179.51 4157.31 .4552.61 6772.84 6005418.13 563390.93 10.00 7196.02 90.27 MWD 10325.00 90.11 182.01 4157.26 .4577.61 6772.51 6005393.13 563390.79 10.00 7217.94 90.27 MWD 10350.00 90.10 184.51 4157.21 .4602.57 6771.09 6005368.17 563389.56 10.00 7239.32 90.28 MWD 10375.00 90.08 187.0I 4157.17 -4627.44 6768.58 6005343.28 563387,24 10.00 7260.12 90.28 MWD 10400.00 90.07 189.51 4157.14 -4652.18 6764.99 6005318.52 563383.84 10.00 7280.29 90.29 MWD 10425.00 90.06 192,01 4157.11 -4676.73 6760.32 6005293.93 563379.36 10.00 7299.79 90.29 MWD 10450.00 90.05 194,51 4157.09 -4701.07 6754.58 6005269,56 563373.81 10.00 7318.60 90.29 MWD 10475.00 90.03 197.01 4157.07 -4725.12 6747.80 6005245.45 563367.20 10.00 7336.67 90.30 MWD 10500.00 90.02 199.51 4157.06 -4748.86 6739.96 6005221.65 563359.55 10.00 7353.97 90.30 MWD 10525.00 90.01 202.01 4157.05 -4772.24 6731.10 6005198.21 563350.87 10.00 7370.46 90.30 MWD 10539.00 90.00 203,41 4157.00 -4785.16 6725,68 6005185.25 563345.54 10.00 7379.34 90.30 4 10550.00 89.99 202.31 4157.00 -4795.30 6721.41 6005175.09 563341.35 10.00 7386,29 269.60 MWD 10575.00 89.97 199.81 4157.01 -4818.62 6712.42 6005151.69 563332.54 10.00 7402.68 269.60 MWD 10600.00 89.96 197.31 4157.02 .4842.32 6704.47 6005127.94 563324.77 10.00 7419.89 269.60 MWD 10625,00 89.94 194.81 4157.04 -4866.34 6697.55 6005103.87 563318.04 10.00 7437.87 269.60 MWD 10650.00 89.92 192.31 4157.07 .4890.65 6691.69 6005079.52 563312.36 10.00 7456.59 269.60 MWD 10675.00 89.91 189.81 4157.11 .4915.18 6686.89 6005054.96 563307.75 10.00 7476.01 269.61 MWD 10700.00 89.89 187.31 4157.16 .4939.90 6683.17 6005030.21 563304.22 10.00 7496.10 269.61 MWD 10725.00 89.87 184.81 4157.21 .4964.76 6680.53 6005005.34 563301.77 10.00 7516.82 269.62 MWD 10750.00 89.86 182.31 4157.27 -4989.71 6678.98 6004980.38 563300.40 10.00 7538.14 269.62 MWD 10775.00 89.84 179.81 4157.33 -5014.70 6678.52 6004955.38 563300.13 10.00 7560.00 269.63 MWD 10800.00 89.82 177.31 4157.41 -5039.69 6679.15 6004930.40 563300.95 10.00 7582.37 269.63 MWD 10825.00 89.81 174.81 4157.49 -5064.63 6680.86 6004905.48 563302.85 10.00 7605.20 269.64 MWD 10850.00 89.79 172.31 4157.57 -5089.47 6683.67 6004880.66 563305.85 10.00 7628.46 269.65 MWD 10875.00 89.78 169.81 4157.67 -5114.16 6687.55 6004856.00 563309.92 10.00 7652.09 269.66 MWD 10900.00 89.76 167.31 4157.77 -5138.66 6692.51 6004831.54 563315.06 10.00 7676.06 269.67 MWD 10925.00 89.75 164.81 4157.87 -5162.93 6698.53 6004807.33 563321.27 10.00 7700.31 269.68 MWD MAR 0 1 ; 001 Alaska 0il & Gas Cons. Commission Anchorage BP Amoco Baker Hughes INTEQ Planning Report Company: BP'Amoco Field: Milne. Point .... Si~e: M pt H Pad Well: MPH-08 Wellpath: Plan08 MPH~08BL1 Da~: 2/28/2001 Time: 11:49:43 =' Page: =4 Co-erdi~ate(NE).Refercace: Well: :MPH,~;: Tree No~ Ver~a! (~) Refe.ren~: System: Mean Sea L~el S~fion ~ Reference: USer (0.00E,0.~N,152.05~i) Survey Calcu~t~n Me~: Minimum Cu~atum Db: ·Oracle Survey MD : ln¢l Azim: SSTVD N/S~ E/W MapN: MapE DLS :~ VS TFO: :Tool.. · ft deg ::: deg' : : :: fi: : ~ ft fi::' ft..degJl00ft: ft.::. : :: deg ~ · · . : 10950.00 89.74 162.31 4157.99 -5186.90 6705.61 6004783.41 563328.52 10.00 7724.81 269.69 MWD 10975.00 89.72 159.81 4158.10 -5210.55 6713.72 6004759.83 563336.81 10.00 7749.50 269.70 MWD 11000.00 89.71 157.31 4158.23 -5233.81 6722.86 6004736.63 563346.13 10.00 7774.34 269.71 MWD 11025.00 89.70 154.81 4158.35 -5256.66 6733.00 6004713.87 563356.44 10.00 7799.27 269.72 MWD 11050.00 89.69 152.31 4158.49 -5279.05 6744.13 6004691.57 563367.74 10.00 7824.26 269.74 MWD 11075.00 89.68 149.81 4158.63 -5300.92 6756.23 6004669.79 563380.00 10.00 7849.25 269.75 MWD 11100.00 89.67 147.31 4158.77 -5322.25 6769.27 6004648.56 563393.20 10.00 7874.21 269.76 MWD 11109.00 89.66 146.41 4158.83 -5329.79 6774.17 6004641.06 563398.16 10.01 7883.17 269.49 5 11125.00 89.65 148.01 4158.93 -5343.24 6782.83 6004627.68 563406.93 10.00 7899.11 90.40 MWD 11150.00 89.63 150.51 4159.08 -5364.73 6795.61 6004606.29 563419.86 10.00 7924.08 90.39 MWD 11175.00 89.62 153.01 4159.25 -5386.75 6807.44 6004584.36 563431.86 10.00 7949.07 90.37 MWD 11200.00 89.60 155.51 4159.42 -5409.26 6818.30 6004561.93 563442.88 10.00 7974.05 90.36 MWD 11225.00 89.59 158.01 4159.60 -5432.23 .6828.16 6004539.04 563452.92 10.00 7998.97 90.34 MWD 11250.00 89.57 160.51 4159.78 -5455.61 6837.01 6004515.73 563461.95 10.00 8023.77 90.32 MWD 11275.00 89.56 163.01 4159.97 -5479.35 6844.84 6004492.05 563469.95 10.00 8048.40 90.31 MWD 11300.00 89.55 165.51 4160.16 -5503.41 6851.62 6004468.05 563476.91 10.00 8072.84 90.29 MWD 11325.00 89.54 168.01 4160.36 -5527.74 6857.34 6004443.76 563482.82 10.00 8097.01 90.27 MWD 11350.00 89.53 170.51 4160.57 -5552.30 6862.00 6004419.24 563487.67 10.00 8120.89 90.25 MWD 11375.00 89.52 173.01 4160.78 -5577.04 6865.58 6004394.53 563491.44 10.00 8144.42 90.23 MWD 11400.00 89.51 175.51 4160.99 -5601.92 6868.08 6004369.68 563494.13 10,00 8167.57 90.21 MWD 11409.00 89.51 176.41 4161.04 -5610.89 6868.70 6004360.71 563494.81 10.00 8175.78 89.90 6 11425.00 89.50 174.81 4161.18 -5626.84 6869.92 6004344.77 563496.16 10.00 8190.45 269.60 MWD 11450.00 89.48 172.31 4161.40 -5651.68 6872.73 6004319.96 563499.15 10.00 8213.71 269.61 MWD 11475.00 89.47 169.81 4161.63 -5676.37 6876.61 6004295.30 563503.22 10.00 8237.34 269.64 MWD 11500.00 89.45 167.31 4161.87 -5700.87 6881.57 6004270.84 563508.36 10.00 8261.31 269.66 MWD 11525.00 89.44 164.81 4162.11 -5725.14 6887.59 6004246.62 563514.57 10.00 8285.56 269.68 MWD 11550.00 89.43 162.31 4162.35 -5749.11 6894.67 6004222.71 563521.82 10.00 8310.05 269.71 MWD 11575.00 89.42 159.81 4162.61 -5772.75 6902.78 6004199.13 563530.12 10.00 8334.74 269.73 MWD 11600.00 89.41 157.31 4162.86 -5796.02 6911.92 6004175.93 563539.43 10.00 8359.58 269.76 MWD 11625.00 89.40 154.81 4163.12 -5818.87 6922.06 6004153.17 563549.74 10.00 8384.51 269.78 MWD 11650.00 89.39 152.31 4163.39 -5841.25 6933.19 6004130.87 563561.04 10.00 8409.50 269.81 MWD 11675.00 89.38 149.81 4163.66 -5863.12 6945.29 6004109.09 563573.30 10.00 8434.49 269.83 MWD 11700.00 89.38 147.31 4163.93 -5884.45 6958.33 6004087.87 563586.50 10.00 8459.44 269.86 MWD 11725.00 89.37 144.81 4164.20 -5905.19 6972.28 6004067.24 563600.61 10.00 8484.30 269.89 MWD 11750.00 89.37 142.31 4164.47 -5925.30 6987.13 6004047.24 563615.61 10.00 8509.03 269.92 MWD 11775.00 89.37 139.81 4164.75 -5944.74 7002.84 6004027.92 563631.47 10.00 8533.56 269.94 MWD 11800.00 89.37 137.31 4165.03 -5963.48 7019.39 6004009.31 563648.15 10.00 8557.87 269.97 MWD 11809.00 89.37 136.41 4165.13 -5970.05 7025.53 6004002.79 563654.35 9.98 8566.56 270.16 7 11825.00 89.36 138.01 4165.31 -5981.79 7036.40 6003991.13 563665.30 10.00 8582.02 90.40 MWD 11850.00 89.34 140.51 4165.59 -6000.73 7052.71 6003972.32 563681.76 10.00 8606.40 90.38 MWD 11875.00 89.33 143.01 4165.88 -6020.36 7068.18 6003952.80 563697.38 10.00 8630.99 90.35 MWD 11900.00 89.31 145.51 4166.18 -6040.65 7082.78 6003932.63 563712.13 10.00 8655.76 90.32 MWD 11925.00 89.30 148.01 4166.48 -6061.56 7096.48 6003911.83 563725.99 10.00 8680.65 90.30 MWD 11950.00 89.29 150.51 4166.79 -6083.04 7109.26 6003890.44 563738.92 10.00 8705.61 90.27 MWD 11975.00 89.28 153.01 4167.10 -6105.06 7121.09 6003868.52 563750.92 10.00 8730.61 90.23 MWD 12000.00 89.27 155.51 4167.41 -6127.58 7131.94 6003846.08 563761.94 10.00 8755.59 90.20 MWD 12025.00 89.27 158.01 4167.73 -6150.55 7141.81 6003823.19 563771.98 10.00 8780.50 90.17 MWD 12050.00 89.26 160.51 4168.05 -6173.92 7150.66 6003799.89 563781.00 10.00 8805.30 90.14 MWD 12075.00 89.26 163.01 4168.37 -6197.66 7158.48 6003776.21 563789.01 10.00 8829.94 90.11 MWD 12100.00 89.25 165.51 4168.70 -6221.72 7165.26 6003752.21 563795.97 10.00 8854.37 90.08 MWD 12125.00 89.25 168.01 4169.02 -6246.05 7170.98 6003727.92 563801.88 10.00 8878.54 90.04 MWD 12150.00 89.25 170.51 4169.35 -6270.61 7175.64 6003703.40 563806.72 10.00 8902.42 90.01 MWD 12175.00 89.26 173.01 4169.67 -6295.35 7179.22 6003678.69 563810.49 10.00 8925.95 89.98 MWD RECEIVED MAR 0:1 2001 Alaska 0il & Gas Cons. Commission Anchoraoe BP Amoco Baker Hughes INTEQ Planning Report BAK~K ComPany: ~ BP Amoco Field: Mi!ne Point si~e: M Pt H Pad Well: MPH-08 Wellpath: Plarh~ MPH-08BL1 Date: 2/28/2001: Tune: 11:49:43 page: S Co-oral. ate(NE) Reference: . Well: MPH,08, Tree N°rth Vertical (TVD) Reference.- System: Mean Sea Level Section (VS) Reference: User (0.00E,0.00N,152.05Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD >lncl ~ Azim ~ SSTVD : N/S ~ E/~' MapN ' MapE DLS .VS · TFO Tool · deg deg ft ft~ ft ft deg 12200.00 89.26 175.51 4170.00 -6320.22 7181.72 6003653.84 563813.17 10.00 8949.09 89.95 MWD 12225.00 89.26 178.01 4170.32 -6345.18 7183.13 6003628.90 563814.78 10.00 8971.80 89.91 MWD 12250.00 89.27 180.51 4170.64 -6370.17 7183.45 6003603.91 563815.29 10.00 8994.03 89.88 MWD 12275.00 89.28 183.01 4170.96 -6395.16 7182.68 6003578.93 563814.71 10.00 9015.74 89.85 MWD 12300.00 89.29 185.51 4171.27 -6420.08 7180.83 6003553.99 563813.04 10.00 9036.88 89.82 MWD 12325.00 89.30 188.01 4171.58 -6444.90 7177.88 6003529.15 563810.28 10.00 9057.43 89.79 MWD 12350.00 89.31 190.51 4171.89 -6469.57 7173.86 6003504.45 563806.45 10.00 9077.34 89.75 MWD 12373.00 89.32 192.81 4172.19 -6492.10 7169.20 6003481.89 563801.96 9.98 9095.05 89.68 8 12375.00 89.32 192.61 4172.21 -6494.05 7168.76 6003479.94 563801.53 10.03 9096.57 269.49 MWD 12400.00 89.30 190.10 4172.52 -6518.56 7163.84 6003455.40 563796.80 10.03 9115.91 269.49 MWD 12425.00 89.28 187.59 4172.83 -6543.26 7159.99 6003430.67 563793.14 10.03 9135.93 269.52 MWD 12450.00 89.26 185.09 4173.15 -6568.10 7157.23 6003405.81 563790.57 10.03 9156.58 269.55 MWD 12475.00 89.24 182.58 4173.47 -6593.04 7155.56 6003380.86 563789.09 10.03 9177.83 269.59 MWD 12500.00 89.22 180.07 4173.81 -6618.03 7154.98 6003355.87 563788.70 10.03 9199.63 269.62 MWD 12525.00 89.21 177.56 4174.15 -6643.02 7155.50 6003330.89 563789.41 10.03 9221.95 269.65 MWD 12550.00 89.20 175.06 4174.50 -6667.96 7157.11 6003305.96 563791.20 10.03 9244.73 269.69 MWD 12575.00 89.19 172.55 4174.85 -6692.81 7159.81 6003281.13 563794.09 10.03 9267.95 269.72 MWD 12600.00 89.18 170.04 4175.21 -6717.52 7163.59 6003256.46 563798.06 10.03 9291.55 269.76 MWD 12625.00 89.17 167.53 4175.57 -6742.04 7168.45 6003231.98 563803.11 10.03 9315.49 269.79 MWD 12650.00 89.16 165.02 4175.94 -6766.32 7174.38 6003207.75 563809.22 10.03 9339.71 269.83 MWD 12675.00 89.16 162.52 4176.30 -6790.32 7181.37 6003183.80 563816.39 10.03 9364.19 269.87 MWD 12700.00 89.15 160.01 4176,67 -6813.99 7189.40 6003160.20 563824,59 10.03 9388.86 269.90 MWD 12725.00 89,15 157.50 4177.04 -6837.29 7198.45 6003136.97 563833.83 10.03 9413.69 269.94 MWD 12750.00 89.15 154.99 4177.41 -6860.16 7208.52 6003114.17 563844.07 10.03 9438.61 269.98 MWD 12775.00 89.15 152.49 4177.78 -6882.58 7219.58 6003091.84 563855.29 10.03 9463.60 270.01 MWD 12800.00 89.15 149.98 4178.15 -6904.49 7231.61 6003070.03 563867.49 10.03 9488.59 270.05 MWD 12825.00 89.16 147.47 4178.52 -6925.85 7244.58 6003048.77 563880.63 10.03 9513.54 270.09 MWD 12850.00 89.17 144.96 4178,89 -6946.63 7258.48 6003028.10 563894.68 10.03 9538.41 270.13 MWD 12875.00 89.17 142.45 4179.25 -6966.77 7273,28 6003008.07 563909.63 10.03 9563.14 270.16 MWD 12900,00 89.18 139.95 4179.61 -6986.25 7288,94 6002988,71 563925.43 10.03 9587.69 270.20 MWD 12925.00 89.19 137.44 4179.96 -7005.03 7305.44 6002970.06 563942.07 10.03 9612.01 270.23 MWD 12950.00 89.21 134.93 4180.31 -7023.07 7322.74 6002952.16 563959.51 10.03 9636.05 270.27 MWD 12975.00 89.22 132.42 4180.65 -7040.33 7340.82 6002935.03 563977.72 10.06 9659.77 270.34 MWD 13000.00 89.24 129.90 4180.99 -7056.78 7359.64 6002918.73 563996.66 10.06 9683.13 270.38 MWD RECEIVED MAR 0' 1 Z001 Alaska 0il & Gas Cons. Commission Anchorage i i Tree: 4.5" 5M Wellhead: 11" 5M FMC Gen 6 4.5" 8rd. EUE bottom and top, 4.5" CIW BPV profile. 20" 91.1 ppf, H-40 KOP @ 300' Max. hole angle = 78 to 80 deg. f/3600' to 7450' Hole angle thru' perle -- Horizontal MPU H-08a Orig. KB Elev. = 64.9' (N 22E) Odg. GL Elev. = 36.0' RT To Tbg. Spool = 30.6' (N 22E) Proposed and Ll (Post CTD) 4.5" 12.6 ppf, L-80 IBT mod tubing ( ddff ID = 3.958", cap = 0.0152 bpf ) 7" 26 ppf, L~80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Milled 6-1/8" window at 8588'-8600' (12') 4.5" HES 'XD' sliding sleeve I I 833O' 3.813"1D shifts down to open I I 4.5" 12.6#, L-80 IBT Slotted liner from 9047'-9373' 3B CTD sidetrack Sand TD 13000' ~i 3.75" Openhole CoilCADE estimated TD &~¢O~e -11800' both horizontals DATE 10-01-97 REV. BY ,, JBF COMMENTS Drilled and Cased by Nabors 22E 6/20/98 M. Linder Frac and completion by Nabors 4-ES M. Under M. Linder MOJ 12/19/99 2/25/01 P&A well for sidetrack 4-ES Sidetrack completion for let pump Proposed H-08B & L1 (Post CTD) 4.5" Baker S-3 packer I 8398' 4.5" HES XN nipple 3.725" id I 8421' WLEG I 8433' Baker ZXP Liner top packer w/6' tie back (5.25" ID) I 8421' Baker 5"x7" HMC liner I 8436' hanger (4.375" ID) Baker HMCV cement valve I 8961' BakerCTC 20' PZP ECP I 8979' lB L1 Second CTD sidetrack OB Sand 3.75" Openhole. TD 13000' 4.5" Baker drillable guide shoe ~ Open hole to 12164' MILNE POINT UNIT WELL No · H-08A APl: 50-029-22808-01 Bp EXPLORATION IAKI RECEIVi MAR 0'1 ZO Alaska Oil & Gas Cons. Cor Anchora§e Tree: 4.5" 5M Wellhead: 11" 5M FMC Gen 6 4.5" 8rd. EUE bottom and top, 4.5" ClW BPV profile. 20" 91.1 ppf, H-40 I 115' I KOP @ 300' Max. hole angle = 78 to 80 deg. f/3600' to 7450' Hole angle thru' perfs = Horizontal MPU H-08a IIII I I I I __ Odg. KB Elev. = 64.9' (N 22E) Odg. GL Elev. = 36.0' RT To Tbg. Spool -- 30.6' (N 22E) 4.5" 12.6 ppf, L-80 IBT mod tubing ( drift ID = 3.958", cap = 0.0152 bpf) 7" 26 ppf, L-80, BTC mod production csg. ( drift ID = 6.276", cap. = 0.0383 bpf ) Stimulation Summary Milled 6-1/8" window at 8588'-8600' (12') 4.5" HES 'XD' sliding sleeve I 833O' 3.813"1D shifts down to open I 4.5" BakerS-3 packer I 8398' 4.5" HES XN nipple 3.725' id I 8421' Baker ZXP Liner top packer wi6' tie back (5.25' ID) I 8421' Baker5"x7' HMC liner I 8436' ID) Baker HMCV cement valve I 8981' Baker CTC 20' PZP ECP I ~' 14its of 4.5", 12.6# L-801BT Solid liner. D 8jts of 4.5" 12.6~, L-80 IBT Slotted liner from 9047'-9373' 1 mission 4.5" Baker ddllable pack off bushing [ 9373' 4.5" Baker drillable guide shoe I 9417' i i i DATE 10-01-97 REV. BY JBF COMMENTS Drilled and Cased by Nabors 22E Open hole to 12164' 6/20/98 M. Linder Frac and completion by Nabors 4-ES 12/19/99 M. Linder P&A well for sidetrack 4-ES M. Linder 1/19/00 Sidetrack completion for jet pump MILNE POINT UNIT WELL No: H-08A APl: 50-029-22808-01 BP EXPLORATION {AK) 3S CTD BOP Detail ~ CT Injector Head ®~~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~1 I -- 7" Riser I Otis 7" WLA Quick Connect ~ I Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TO 2" Side outlets IBlindlShear ,] 2 318" Combi PipelSli~ Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold _ I I 2 718" Combi Pipe/Slip 2 318" Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve 2 flanged gate valves MOJ 12/29/00 Tubing Spool 7" Annulus 9 5/8" Annulus RECEIVED MAR 0 ~ ?nn~ Alaska Oil & Gas Cons. Commission Anchorage H ~ 8 2 8 5 3 oz,':~o,,oz VENDOR AEASI4,AO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 012c201 CKO12c~OiD 100. O0 100. O0 PYMT (iOMMENTS: Pert it To Drill i ee HANDL NO INST: S/H - Terrie Hubl ie X4628 HE AI'rACHED CHECK IS I. PAYMENT FOR ri'EMS DESCRIBED ABOV~ 1 OO. OO 1OO. OO 412 WELL PERMIT CHECKLIST COMPANY ~'/~'/ INIT CLASS WELL NAME/~_ ~.,~-z:~2~ PROGRAM: exp ~ / -,,~,,'j/ GEOL AREA ,N Y N Y N FIELD & POOL .'5"-~.,._~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... _.Y.. N 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... .,.... ~..... 26. BOPE press rating appropriate; test to :z.,_~ psigl 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... Y N_,//Y N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory only] Y N / dev ,~C redril '~' serv__ wellbore seg ann. disposal para req __ UNIT# .//' ~' ~._'~ ON/OFF SHORE d"3,v'tJ N Y N\ ---' Y NJ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N Y N Y N GEOLQGY: ENGINEERING: UIC/Annular COMMISSION: ~., ~)MTH ~ ~ - ,_,. Comments/Instructions: I§ Z -I rrl c:\msoffice\wordian\diana\checklist (rev. 11/011/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this. nature is accumulated at the end of the file under APPENDIXi No'special'effort has been made to chronologically ". · organize this category of information. **** REEL HEADER **** MWD 01/09/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/09/14 131661 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WP~P. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 8685.0000: STOP FT 11500.0000: STEP FT 0.5000: NULL -999.2500: COMP COMPANY: WELL WELL: FLD FIELD: LOC LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. MPH-08B-L1 Prudhoe Bay Unit 2767' NSL, 4061' WEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 18-Apr-00 500292280860 #MNEM.UNIT Value Description SECT. 34 : Section TOWN.N TI 3N : Township RANG. R1 0E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 65.68 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 65.68 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -COMMENTS (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) and Resistivity data (RACLX, RPCMX,RACHX,RPCLX) presented is realtime data. (4) Baker Hughes INTEQ Runs 1-3 utilized the Orient Express service to mill the casing window from 9061' MD (4083' SSTVD) to 9068' MD (4086' SSTVD) and to drill formation from 9068' to 9078' MD (4090' SSTVD). (5) Baker Hughes INTEQ Runs 4-5 utilized the Orient Express with Ultra Slim Multiple Propagation Resistivity (USMPR) services from 9078' MD (4090' SSTVD) to 11500' MD (4187' SSTIrD) . (6) Well MPH-08B-L1 was drilled as a sidetrack of Well MPH-08A. (7) Well MPH-08B-L1 was drilled to TD ® 11500' MD (8147' SSTVD) on Run 5. After a final Tie-In, bottom was tagged at 11500' MD (4187' SSTVD) . (8)The interval from 11472' (4186' SSTIrD) to 11500' MD (4187' SSTVD) was not logged due to sensor to bit offset at well TD. (9) The data presented here is final. Gamma Ray MWD is the PDC (Primary Depth Control) curve for this borehole, as per BPX instructions. (10) A Magnetic Declination correction of 26.30 degrees has been applied to the Directional Surveys. MNEMONICS: GPJtX ROPS TVD RACLX RPCLX RACHX RPCHX = Gamma Ray MWD-API [MWD] (MWD-API units) = Rate of Penetration, feet/hour = Subsea True Vertical Depth (SSTVD), (feet) = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A N/A N/A N/A CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT N/A, N/A, ! N/A NO Depth Shift applied. Gamma Ray MWD is the PDC for borehole of MPH-08B-L1. Tape Subfile: 1 85 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN MPH-08B-L1 FN Milne Point Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 0.0 2 ROP ROPS 0.0 3 RACH RACHX 0.0 4 RACL RACLX 0.0 5 RPCH RPCHX 0.0 6 RPCL RPCLX 0.0 * 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: IF ] 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 2 ROP MWD 68 1 3 PJtCH COMP 68 1 4 R3tCL COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 API ~/HR Total Data Records: 157 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 ....... 24 Tape File Start Depth = 8685.000000 Tape File End Depth = 11500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 170 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD Ol/O9/14 131661 01 **** REEL TRAILER **** MWD 01/09/14 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL 8685.0000 -999.2500 50.3750 -999.2500 8685.5000 -999.2500 50.4890 -999.2500 8700.0000 -999.2500 53.5320 -999.2500 8800.0000 -999.2500 -999.2500 -999.2500 8900.0000 -999.2500 -999.2500 =999.2500 9000.0000 -999.2500 -999.2500 -999.2500 9100.0000 7.1790 85.0970 8.3130 9200.0000 21.8930 69.6570 1.0050 9300.0000 7.0400 77.1870 0.4030 9400.0000 9.2790 97.4960 0.4020 9500.0000 13.2230 74.3240 1.0050 9600.0000 20.8070 68.6410 1.0050 9700.0000 18.4180 74.7040 1.0050 9800.0000 14.3360 74.9810 1.0050 9900.0000 18.5480 73.9460 1.0050 10000.0000 25.5010 68.7930 1.0050 10100.0000 23.5240 70.7250 1.0050 10200.0000 15.4940 82.9630 1.0050 10300.0000 16.5620 73.7180 1.0050 10400.0000 19.2280 55.3790 1.0050 10500.0000 13.7850 77.8700 1.0050 10600.0000 19.1590 79.2510 1.0050 10700.0000 52.3300 59.7970 1.0050 10800.0000 99.7870 ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 77 7040 76 2000 158 1830 56 2430 110 7280 118 1100 71 5820 49 9030 101 3820 81.1750 59.6820 98.4250 110.3830 111.7760 123.4600 118.0450 3.76.5560 27.6350 RACH -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 9 4870 21 7500 7 5890 9 4570 17 0730 21 7610 21.1820 17.6870 21.5100 23.9470 20.0360 18.4290 20 5280 17 1880 16 9590 21 6360 22 5130 21 9230 RACL =999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 11 9980 16 2680 9 0380 9 9430 17 5380 20 7180 20 9070 21 5940 20 0960 20 4590 19 7320 20 0620 20 7190 17 7360 19 4350 20 5780 14 7170 14 2220 40.6320 1.0050 10900.0000 96.8320 52.8230 1.0050 11000.0000 70.0800 27.2920 1.0050 11100.0000 81.2960 15.7420 1.0050 11200.0000 75.1560 19.9280 1.0050 11300.0000 72.6570 34.4860 1.0050 11400.0000 79.5540 29.1530 1.0050 11500.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = 106 8870 138 1410 130 7490 70 3100 119 3030 124 3270 -999 2500 8685.000000 11500.000000 0.500000 feet 23.2210 24.5570 22.3900 21.2890 23.3840 24.3010 -999.2500 14 2160 18 0190 22 6940 19 2440 19 0230 20 1060 -999 2500 Tape Subfile 3 is type: LIS