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Home My WebLink About202-153 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0:1. - L ~ ð Well History File Identifier Organizing (done) 0 Two-sided IIIIII11I1111111111 ~can Needed 111111111111111111 R~AN ~ Color Items: 0 Greyscale Items: DI~TAL DATA VDiskettes, NO.~ 0 Other, NofType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation BY: Helen (Maria,.) :J-- X 30 = 107) 0 Other:: '1 DateJ6/Yf (}/f Isl w¡~ , 1111111111111111111 Date to ð9 0 If Isl JIl.1:f , 4 f + J = TOTAL PAGES ;')/ (Count do~s¡not,~nJ:..lude cover she~~Ap' Date: J 0 jiJ-1¡ /JiJ Isl V ,,~ \11111111111\ 11111 BY: Helen ~ Project Proofing BY: Helen ~Marìa ). Production Scanning Stage 1 Page Count from Scanned File: /P a... (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYE~ Helen S Date II. I tJ DLf , If NO in stage 1, page(s) discrepancies were found: YES NO NO Isl VVt. D Stage 1 BY: BY: Helen Maria Date: Is/ 111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: Is/ Comments about this file: Quality Checked IIIIIII1I1111111111 8/24/2004 Well History File Cover Page.doc STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMN~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ~ r~~;i"a 8 ^ Abandon ®Repair Wetl ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter ~uspen~ed Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time. Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 202-153 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23106-60-00 7. KB Elevation (ft): 62 5' ' 9. Well Name and Number: MPI-15L1 8. Property Designation: 10. Field /Pool(s): ADL 025906 - Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9000 - feet true vertical 4042 - feet Plugs (measured) None Effective depth: measured 9000 - feet Junk (measured) None true vertical 4042- feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 112' 112' 1490 470 Surface 3057' 9-5/8" 3085' 2761' 6870 4760 Intermediate Production 4824' 7" 4849' 3968' 7240 5410 Liner 3947' 4-1/2" 4840' - 8965' 3966' - 4042' 8430 7500 Perforation Depth MD (ft): Slotted Liner 4869' - 8922' Perforation Depth TVD (ft): Slotted Liner 3974' - 4042' - 2-7/8", 6.5# L-80 4319' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 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: 0 0 0 420 Subsequent to operation: 115 6 251 310 302 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 ~® Oit ^ Gas ^ WAG ^ GINJ ^ WINJ ^ 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 Howard West, 564-5471 N/q Printed Name Sondra Stewman Title Drilling Technologist ~c ~ Prepared By Name/Number: 'J t~~ ~ c Sig ature . Phone 564-4750 Dat ndra Stewman 564-4750 Form 10-404 Revised 04/2006 ~~G c IOft Submit Orig' al Only c~ Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M Gen 5 w/2~ EUE T&B Tubing Hanger with CIW "H" BPV profile 20°, 92 #/ft H-40 Welded 112' M P I ' ~ ~~ ~ ~ Orrr~ eeeev.= 28.50' Camco 2-7/8" x 1" sidepocket 167` KBMM GLM 9 5/8", 40#/ft BTC L-80 3085 2 7/8" 6.5 ppf, L-80, 8rd, EUE production tubing ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btc-mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) KOP ~ 470 ' Max well bore Angle: 47° C~3 4120' MD 60°+ past 4500' MD Hole angle trough perfs = 86°+ Camco 2-7/8" x 1" sidepocket 4071' KBMM GLM HES 2.313" `XN' Nipple 4223' ( 2.250 No-go ID) Tandem Pumps, 137P17 Stg. 4265` SXD Coated stages Tandem Gas Separator 4284, GRSTXBARH6 (513 Internals) Tandem Seal Section 42 ` Model GSB3DBUT SB/SB PFSA 90 FSA/CL5 Motor, 114 HP, 2330 volt, 4304' 30 amp, Model KMH Pumpmate Multi-Sensor 4319' w/6 fin Centralizer (6.25' long) Window in 7" Casing @ 4849' - 4861' Well Angle @ window = 72° Baker Tie Back Sleeve 5095` Baker ZXP Liner Top Packer 5102' Baker 7" x 5" HMC Liner Hanger 5108' 7" Halliburton Float Collar 5120' 7" Halliburton Float Shoe 5203' OB Lateral DATE REV. BY COMMENTS 9/01/02 Lee Hulme Multi-lat and complete Doyon 141 8/21/08 MOM 4-ES ESP RWO 96 jts - 4 1/2", 12.6#/ft. Slotted Liner 12.6# L-80 IBT (5200`-9041') Btm. Baker 4 1/2" Guide Shoe 9042 i0' MILNE POINT UNIT WELL 1-15 API NO: 50-029-23106 API NO: 50-029-23106-60 BP EXPLORATION SAKI Baker Hook Wall Hanger inside 7° Window (21') Top 4840' Baker Hook Wall Hanger outside 7" Window" (3') Baker Down Swivel-up lock sub 4864' 6 1 /8" Hole td @ 9000' OA Lateral 103 jts. - 41/2" Slotted Liner 12.6# L-80 IBT (4869' - 8922') Page 1 of 3 • . W~11: MPI-15 Well History Well Date Summary MPI-15 3/6/2008 Well Support Techs set BPV, pulled well house, production lines and foundation. Support Techs greased swab, wing, master, IA and OA valves. ***NOTE*** BPV left in hole MPI-15 4/22/2008 ***ARRIV ON LOC WELL S/I*** «« PULLED BACK PRESSURE VALVE »» MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory 2.25" JSN. RIH, attempt to dry tag, could not go deeper than 7837. PUH bring well Gama/CCL in carrier , on with N2 and let stabalize. RIH, could not run deeper than 7485'. PUH attempting different rate and speed. Wind direction changed blowing towards all equipment. shut down N2 unit and puh to log interval ® 5300- 4910 ~ 30 FPM. ***job in progress*** MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory Gama/CCL in carrier, 2.25" JSN ...Job in progress... MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory Gama/CCL in carrier, 2.25" JSN. Ran in hole to 7837' CT appears to go into lock up. PUH bring well on with N2 and let well stabilize. RIH and attempt to get to original tag/lock up depth getting no deeper than 7485' using different rates and speed. Wind direction changed 180 deg. blowing returned gas towards surface equipment. Shut down taking returns and PUH to log from 5300 to 4910. Continued to surface for Agitator Rigged up second return tank farm opposite side of CTU and continue with FCO ...Continue job on 4/25/2008... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator....Job in progress... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator & SafeLube. Log from 4900' to 5300' ~ 30fpm. Had problems with lock up around 7480' -7890' Lubed fluids and continued with clean ...Continue job on 4/26/2008... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator and safe tube. made another logging pass from 4900 to 5300 ~ 30fpm. clean out down to 8149'. ***job in progress*** MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator. Continue clean out left off at 7980' CTM at C/O ...Job in progress... MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Scope:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310' Made several attempts to clean OB lateral deeper than 8336 with no luck due to coil going into lock-up at various Depths. RIH w/PDS memory CCUGama inside carrier and Schlumberger MLT tools. Made logging reference between 5300' and 4900'. Made 10 of 12 positions and index/MLT tool across OA lateral window, on the tenth position noticed pressure change, RIH to investigate. Coil locked up ~ 7827, appeared to be in the OB lateral. PUH and made additional logging pass for reference. POOH and varify that MLT was working and down load data from PDS memory sub. Data confirmed that the tools never left the main bore. RIH w. new configuration on MLT. Start MLT process. ...Continue job on 4/27/2008... MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Scope:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean OB lateral deeper than 8336 with no luck due to coil going into lock-up at various RIH w/ PDS memory ccl/gr inside carrier and Schlumberger MLT tools. Made logging reference between 5300' and 4900'. Made 10 of 12 positions and index/MLT tool across OA lateral window, on the tenth position noticed pressure change, RIH to investigate. Coil locked up ~ 7827, appeared to be in the OB lateral. PUH and made additional logging pass for reference. ***job in progress*** MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Space:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean deeper than 8336 with no luck do to coil going into lock-up at various depths. ...Job in progress... MPI-15 4/26/2008 Continue job 4/25/2008. CTU #5 Job Scope: Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean deeper than 8336 with no luck do to coil going into lock-up at various depths. ...Job in progress... MPI-15 4/27/2008 Continue job from 4/26/2008 CTU #5 Job Scope: FCO with N2 of OA lateral section Continued with MLT process making 9 passes with each orientation being 30 deg. Saw a small indication of what might have been the window kept pump running and dropped down attempting to enter the OA lateral section. Drifted until CT went into lock up ~ 7689' Pulled into tubing tail to verify MLT working. Saw a positive indication that tool was functioning properly. Made three more passes to complete the full 360 deg. Orientation process with no apparent entry to the OA lateral. POOH and down loaded data from PDS CCUGama. Page 2 of 3 ~ Data indicated that ever left the main bore of the well. RD CTU left y~eeze protected to 2500' ' *'*Job Complete*** s MPI-15 4/29/2008 "*ARRIV ON LOC WELL S/I*** **'R/U EQUIPMENT CONTINUE ON 4/30/08'** MPI-15 4/30/2008 *'*CONT FROM 4/29/08*** DRIFT TAG FOR CALIPER u ~~ RIH W/ 10' 1 7/8 (2.6 ROLLER) KJ 5' 1 7/8 (2.6 ROLLER) HYD. SSS W/ 2' 1 7/8" ROLLER / 2.76 CENT. TEL / S-BAILER TAG E.O.T. ~ 4,699' SLM +13' CORRECTED MD. RAN DOWN TO 5,113' MD. STOP DUE TO DEV. NO RECOVERER IN S-BAILER **` TURN WELL OVER TO DSO **' (WELL TAGGED DONT POP ) ~' MPI-15 4/30/2008 ***ARRIV ON LOC WELL S/I '** CALIPER HELD SAFETY MEETING REV.JSA R/U EQUIPMENT ***CONTINUE ON 5/1/08*** MPI-15 4/30/2008 ***CONT FROM 4/29/08*** DRIFT TAG RIH W/ 10' 1 7/8 (2.6 ' ROLLER) KJ 5' 1 7/8 (2.6" ROLLER) HYD. SSS W/ 2' 1 7/8" ROLLER / 2.76 CENT. TEL / S-BAILER TAG E.O.T. ~ 4,699' SLM 10' CORRECTION RAN DOWN TO 5,110' CM STOP DUE TO DEV. NO RECOVERER IN S-BAILER *** TURN WELL OVER TO DSO **' (WELL TAGGED DONT POP ) MPI-15 4/30/2008 '**ARRIV ON LOC WELL S/I **' HELD SAFETY MEETING REV.JSA R/U EOUIPMENT ***CONTINUE ON 5/1/08*** MPI-15 5/1/2008 **'CONTINUE FROM 4/30/08*'* RIH W/ CALIPER TO 4,834' FT COULDNT GET BELOW THE TOP LATERAL WINDOW. '**JOB COMPLETED*** ~ MPI-15 5/1/2008 '"CONTINUE FROM 4/30/08*** RIH W/ CALIPER TO 4,834' FT COULDNT GET BELOW THE WINDOW *"JOB COMPLETED*** MPI-15 5/10/2008 "*ARRIV ON LOC WELL S/I *** CALIPER RAN PDS CALIPER FROM 4600' TO 5000' SLM. GOOD DATA **'TURN WELL OVER TO DSO **'* MPI-15 7/5/2008 T/I/O = 1220/1220/200. IA FL (Pre Coil). IA FL ~ -3500'. MPI-15 7/13/2008 CTU #5 1.75" CT Set IBP Interact Publishing Wait on weather ******** Job In Progress '******* MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1(Inte rAct is publishing) Set 3" IBP at 5150' .Walk pressure up in 500 pis increments to set. Ball sheared at 2950 psi. RIH w / PDS GR/CCL & R&R tool"""""""`Job in progress""""" MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1(Inte rAct is publishing) Set 3" IBP at 5150' .Walk pressure up in 500 pis increments to set. Ball sheared at 2950 psi. RIH w / PDS GR/CCL & R&R tool After racheting the tool two complete cycles we POOH to reconfigure the tool string. Cut 150' of coil and rehead. MU toolstring to run back in the well.*****'**Job In Progress******** MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1 Continued from 7/13/08 ******* Job In Progress *'*'****** MPI-15 7/15/2008 CTU #5 1.75' CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. RIH w /hydraulic indexing tool. Moved bent sub 6' closer to nozzle with a little extra bend and it went in the OA lateral the first try. Milne point has called a code 99 shut down all operations STBY. Released to go back to work.POOH change to DJN.Cut coil have X-over built to get from bent sub to DJN. ******* Job In Progress ********* MPI-15 7/15/2008 ~~ CTU #5 1.75 CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. RIH w /hydraulic indexing tool. Moved bent sub 6' closer to nozzle with a little extra bend and it went in the OA lateral the first try. Milne point has called a code 99 shut down all operations STBY. Released to go back to work. """""""Job in progress"""""""" MPI-15 7/15/2008 CTU #5 1.75" CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill. MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot ~ 5500' Broke thru ~ 5514' STBY for motor & mill Mu BHA RIH attempting to get out window no luck yet """'"`Job in progress'"""""` MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot ~ 5500' Broke thru ~ 5514' STBY for motor & mill """""Job in progress`"`"""" MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot ~ 5500' Broke thru ~ 5514' STBY for motor & mill Mu BHA RIH attempting to get out window no luck yet "'"""'Job in progress""""'"' Page 3 of 3 • • MPI-15 7/17/2008 CTU #5 1.75" CT Interact Publishing (FCO OA Lateral) RIH with 3.50" mill trying to exit window again. Tried to get in the window with no luck. POOH break off tools RDMO road to L-219. BOT building new bent sub then we will return. *******`***Job Incomplete *'******`* MPI-15 7/22/2008 CTU #5 1.75" CT (FCO/Pull IBP) Road from MPL-43 *******Job In Progress ******* MPI-15 7/22/2008 CTU #5 1.75" CT (FCO/Pull IBP) .Road from MPL-43 *******Job In Progress ***'*** MPI-15 7/22/2008 CTU #5 1.75" CT (FCO/Pull IBP) Road from MPL-43 RIH with WOT Bent motor and mill on BOT MHA with indexing tool. Work thru window milling ahead. Milled from 5546' to 7319' .*******Job In Progress ...*... MPI-15 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22108 WSR Milling at 7318'at midnight. Continued milling to 7506' using 1 % XS KCI and FloPro sweeps. CT began acting like it was stacking out weight up hole. Decision made to pump 15 bbl FloPro sweep and chase to surface. Makeup 3" JSN and cleanout down to IBP. Ran into well without pumpin and entered top lateral. At 5300', PUH to top of window at 4800'.. Jet down using 1 % XS KCI and tag top of IBP at 5141' ctmd. Pump 12 bbl FloPro sweep and chase from IBP to surface. Makeup Baker fishing tools and hydraulic overshot. RIH and tag at 4851' ctmd. Attempt to work fishing tools past upper lateral. *** Job in progress *** MPI-15 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22/08 WSR Milling at 7318'at midnight. ****** Job In Progress ******* MPI-15 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22/08 WSR Milling at 7318'at midnight. Continued milling to 7506' using 1 % XS KCI and FloPro sweeps. CT began acting like it was stacking out weight up hole. Decision made to pump 15 bbl FloPro sweep and chase to surface. Makeup 3" JSN and cleanout down to IBP. Ran into well without pumpin and entered top lateral. At 5300', PUH to top of window at 4800'.. Jet down using 1 % XS KCI and tag top of IBP at 5141' ctmd. Pump 12 bbl FloPro sweep and chase from IBP to surface. Makeup Baker fishing tools and hydraulic overshot. RIH and tag at 4851' ctmd. Couldn't get past the window area with several attempts with rate and WHP, POOH to inspect Mule Shoe for marks and wait on x-overs for indexing tool. Mule Shoe had a small rolled spot on the shoulder MU Indexing tool and RIH. RIH and tagged -13' high, index tools and try working down. Made it past 4836' after 10 indexes and tagged ~ the window depth again. Could not pass 4851', tried 2 click cycles for 360 deg and 1 click for 360 deg with no luck. POOH to change tools. ***Job continued on WSR 7/24/08*** MPI-15 7/24/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/23/08 WSR Continue POOH can't get past 4851' PU for smaller OD tools and bent sub and cut pipe. Cut off 150' of CT and rehead. PT to 20k and WO Tools. MU tools and tried to PT but had aleak /Ran down and found disconnect was washed out (this disconnect was from the FCO run). Called BTT shop to send out another one. MU BHA and RIH ***Job in Progress*** MPI-15 7/24/2008 CTU #5 1.75" CT Fish Pull IBP. *** Continued from 7/23/08 WSR *** InterACT publishing. Continue POOH to PU smaller OD fishing tools. Cut off 150' of CT and rehead. PT to 20k and WO Tools. MU tools. Disconnect leaked .Wait on Baker for tools. RIH with fishing string with Daily Jar and 1.75" overshot. RIH and saw 2k weight bobble going through upper lateral. Engage IBP at 5145' ctmd. Pull release IBP with 10k overpull. Allow element to relax then pull out of hole. Pulled 5k overpull at upper lateral, then jars hit and pulled through. POOH. At surface, IBP recovered with all rubber elements intact. Freeze protect well with 38 bbls of 50/50 meth. RDMO CTU. Final WHP = 400/1320/300. *** Job complete *** MPI-15 8/15/2008 Set BPV in Hole for rig to move onto I-15 well . MPI-15 8/17/2008 ** RWO Prep** INSTALL DPSOV IN STA #2 MANDREL. SET DUMMY GL IN STA#1 MANDREL. FLAGGED AND TAGGED MANDREL'S. MPI-15 8/18/2008 T/I/0=0/0/0. (Post RWO freeze protect). Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls crude. FWHP=O/0/400. MPI-15 8/22/2008 Well Support Techs Pressure tested Flow lines (PROD) and (TEST) to 1150 psi for 10 MIN with diesel. (passed) PT. Then bleed both lines down to 0 psi. MPI-15 8/24/2008 ASRC Test Unit #5, Complete 6 hour test, ***Job complete*** Print Date: 9/4/2008 Page 1 of 1 gp Page 1 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/21/2008 00:00 -06:00 6.00 MOB P PRE R/D and secure rig floor, load and secure pipeshed for move from MPH-19 to MPI-15. Prep to lay over derrick. Unable to lay derrick over. Ambient temperature -40 degrees. Maximum allowable temperature to lower derrick is -40 degrees. Perform general maintenance while waiting. 06:00 - 11:00 5.00 MOB P PRE Rig maintenance and prep for rig move. 11:00 - 13:00 2.00 MOB P PRE Ambient temperature to -38 deg F. Prep camp, shop and auxilliary equipment for move. Lower and scope down derrick. 13:00 - 15:00 2.00 MOB P PRE Blow down steam lines, unhook electrical lines, Jack up modules and prep to move. 15:00 - 16:00 1.00 MOB P PRE Move pit and pipeshed modules. 16:00 - 17:30 1.50 MOB P PRE Move carrier off of MPH-19. Move BOP stack and cradle and load on truck. Move carrier, pits, and pipeshed from MPH pad to MPI pad. 17:30 - 22:00 4.50 MOB P PRE Line up carrier to back over MPI-15. Spot BOP cradle and tree behind well. Lay mats and herculite and spot carrier over MPI-15. Jack and level carrier. 22:00 - 23:00 1.00 MOB P PRE Spot pipeshed, lay herculite and spot pits. 23:00 - 00:00 1.00 MOB P PRE Spot camp shop, generator building and partshouse. Inspect derrick before raising. 3/22/2008 00:00 - 01:00 1.00 MOB P PRE Raise and secure derrick. 01:00 - 04:00 3.00 MOB P PRE Berm rig, spot cuttings and slop tank. Hook up electrical lines, put steam around rig. Rig up floor and pipeshed. Spot tiger tank. 04:00 - 06:00 2.00 KILL P DECOMP R/U secondary annulus valve to IA, R/U lines to tree and hard line to tiger tank. ** Rig Accepted at 04:00 hours on 3/22/2008**. 06:00 - 07:00 1.00 KILL P DECOMP PUMU lubricator, Test lubricator to 500 psi. Pull TWC, T / IA / OA - 450 / 425 / 40 psi. Blow steam through all lines. Continue to finish RU for well kill. 07:00 - 08:00 1.00 KILL P DECOMP PJSM. Take on fluids Pressure test hardline to closed choke to 3500 psi. Test hardline to tiger tank to 500 psi. Bleed gas from IA to Tiger tank. Bleed from 425 psi to 150 psi. 08:00 - 12:00 4.00 KILL P DECOMP Pump 30 Bbls of SW down Tbg, taking gas returns from the IA. Pump rate of 3 BPM, Tbg pressure from 340 psi to 140 psi. Close choke and bullhead 100 Bbls into formatioin ~ 3 BPM, injection pressure of 1140 psi. IA to 940 psi. Open choke and circulate 200 Bbls down Tbg and returns from IA. Get fluid returns after pumping 95 Bbls. Circulate total of 230 Bbls w/ 199 Bbls returns. 12:00 - 13:00 1.00 KILL P DECOMP Shut down pumping. Monitor Tbg and IA. Pressure to 0 psi and then to vacuum on both sides. Blow down all lines. Monitor for 30 minutes (vacuum on both sides.) Dry rod TWC w/ FMC. Measure rod for 1 9/16" for engaging threads on 2 1/2" CIW "H" TWC. 13:00 - 14:30 1.50 WHSUR P DECOMP Test TWC to 3500 psi for 10 minutes from above. Test from below to 560 psi by purring in IA ~ 1/2 BPM for 15 minutes. Both tests charted. Drain tree, rig down kill lines and prep for ND Tree. 14:30 - 16:30 2.00 WHSUR P DECOMP ND 2 9/16" 5M Tree. Notify AOGCC of upcoming ROPE test. States right to witness BOPE test waived by Lou Grimaldi. 16:30 - 21:30 5.00 BOPSU P DECOMP NU BOPE. Install Koomey lines, choke and kill lines. Install flow riser. -- Printed: 9/2/2008 11:47:23 AM gp Page 2 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: .NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/22/2008 21:30 -22:00 0.50 BOPSU P DECOMP Function test ROPE, fill BOP stack and choke manifold with water. 22:00 - 00:00 2.00 BOPSU P DECOMP Test ROPE, choke manifold and floor valves. Test BOPE with 4-1/2 and 2-7/8" test joints. All were tested to 250 psi low and 3,500 psi high. All tests were held for 5 minutes each. Had to retighten body flanges on BOP stack. 3/23/2008 00:00 - 05:30 5.50 BOPSU P DECOMP Test BOPE, choke manifold and floor valves. Test ROPE with 4-1/2 and 2-7/8" test joints.. All were tested to 250 psi low and 3,500 psi high. All tests were held for 5 minutes each. State witness of BOP test was waived by Lou Grimaldi. 05:30 - 06:00 0.50 80PSU P DECOMP RID test assemblies, blow down lines and drain BOP stack. 06:00 - 07:30 1.50 PULL P DECOMP PUMU Opso-Lopso and screw into tubing hanger. PUMU lubricator with polish rod and pulling tool. Stab onto OL, MU Lo-Torq valve on PI sub of lubricator. Pressure test lubricator and OL to 500 psi w/diesel - OK. 07:30 - 08:30 1.00 PULL P DECOMP BOLD lubricator and OL. PUMU 2 7/8" landing joint and screw into hanger. MU kelly hose to head pin. BOLDS. 08:30 - 11:00 2.50 PULL P DECOMP Pull hanger up into stack w/ 38K PUW. Circulate SW down tubing, 12 Bbls to bring fluid into stack. Circulate 150 Bbls SW ~ 2 1/2 BPM, 180 psi. Flow check well (stable). RU elephant trunk and Centrilift equipment to floor for pulling completion. Circulate another 50 Bbls. Total volume circulated of 200 Bbls w/ 7 Bbls losses. 11:00 - 18:00 7.00 PULL P DECOMP BOLD tubing hanger. POH run ESP cable over shieve and to spooling unit. POH laying down 2 7/8" Tbg -ESP completion. Continuous hole fill by pumping across the top. 18:00 - 21:00 3.00 PULL P DECOMP UD ESP. 10' handling pup on top of ESP was punched with two 1"x 1/4" holes. Handling pup and ESP had light corrosion. ESP appeared to have a broken drive shaft. Recovered 131 joints of 2-7/8" tubing in good shape, 1 XN nipple, 2 GLMs, 70 Lassale clamps, 6 protectolizers, 3 flat guards and 1 buster clamp. 21:00 - 22:00 1.00 PULL P DECOMP R/D 2-7/8" handling equipment and remove from rig floor. Remove ESP from pipeshed. 22:00 - 23:00 1.00 PULL P DECOMP R/D ESP sheave and containment trunk. Place containment trunk in storage box, remove sheave from rig floor. 23:00 - 00:00 1.00 BUNCO RUNCMP R/U 4-1/2" tubing handling equipment. 3/24/2008 00:00 - 06:00 6.00 BUNCO RUNCMP P/U 4-1/2" muleshoe assembly and RIH picking up 4-1/2",12.6#, L-80, IBT-M tubing from the pipeshed. Use Best-O-Life 2000 pipe dope. MIU torque 3,000 fVlbs. Run 93 jts of IBT, XO put joint to 31 joints of 4 1/2" NSCT Tbg. 06:00 - 07:00 1.00 BUNCO RUNCMP Running 4 1/2" NSCT, 112 jts in hole ®06:00. Crew change. Continue RIH total of 124 joints of 41/2" Tbg, 1 XO pup, 10' XO pups above and below 41/2" XN Nip (3.725" tD), WLEG. 07:00 - 08:00 1.00 WHSUR P TUBHGR PUMU 11" x 4 1/2" FMC Tbg hanger on 4 1/2" NSCT landing joint. PUW of 55K, SOW of 33K. Land tubing hanger RILDS 08:00 - 09:30 1.50 WHSUR P WHDTRE Dry rod TWC. Test from above to 3500 psi for 10 minutes, test from below pumping ~ 1 BPM, 560 psi 30 minutes. Chart both tests 09:30 - 14:30 5.00 WHSUR P WHDTRE Drain stack. ND BOPE 14:30 - 16:30 2.00 WHSUR P WHDTRE NU 4 1/16" Tree. Test hanger void to 5000 psi for 20 minutes - OK. Pressure test tree to 5000 psi with diesel for 10 minutes and chart. Printed: 9/2/2008 11:47:23 AM gp Page 3 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/24/2008 16:30 - 18:00 1.50 WHSUR P WHDTRE Pull TWC with lubricator. Run BPV. Normal up tree and cellar. Rig released at *** 18:00 hours*** 8/14/2008 14:00 - 00:00 10.00 MOB P PRE RD and LD derrick. Move rig from B-pad to MPI-15. 8/15/2008 00:00 - 16:00 16.00 MOB P PRE Move rig from GPB to MPI-15. Set herculite & rig mats. 16:00 - 19:00 3.00 RIGU P PRE Spot & berm. rig over MPI-15. Spot pits & pipe shed. AOGCC Chuck Scheive waived BOP test witness ~ 17:50 hrs. 19:00 - 21:00 2.00 RIGU P PRE Raise & scope derrick. RU lines to pits. ***Accept Rig ~ 21:00 hrs*** 21:00 - 00:00 3.00 KILL P DECOMP RU lines to tree & Tiger Tank. Take on fluid to pits - 8.45 ppg / 115 degree off truck. 8/16/2008 00:00 - 01:30 1.50 KILL P DECOMP PJSM. P!r lines to 250 psi low / 3500 psi high. Test lines to Tiger Tank to 500 psi. 01:30 - 02:30 1.00 KILL P DECOMP Bleed OA from 200 psi to 0 psi (fluid). Bled TBG from 600 psi to 100 psi thru choke to Tiger Tank all gas. Bled IA from 900 psi to 150 psi all gas. 02:30 - 04:00 1.50 KILL P DECOMP Pump 82 bbls down tubing taking retums thru choke to Tiger Tank. Circulated ~ 5 BPM / 650 psi -crude retums. Shut choke, bullhead 30 bbls ~ 3.5 BPM / 900 psi. Open well and circulate 175 bbls ~ 3.5 BPM / 600 psi -crude retums. 8.43 ppg in, getting 8.45 ppg out. Circulated a total of 286 bbls and lost 52 bbls to formation. 04:00 - 04:30 0.50 KILL P DECOMP TBG 50 psi, IA 50 psi after circulation. Monitor well for 20 min pressures fell to 0 psi on tubing & IA went on vacuum. 04:30 - 06:00 1.50 WHSUR P DECOMP RD lines from tree. Dry rod TWC. Pressure test to 3500 psi on top for 10 min -charted. Test TWC from bottom. Pump 2.5 BPM ~ 700 psi. for 10 min. Charted same. 06:00 - 06:30 0.50 BOPSU P DECOMP Crew change. Service rig. Inspect derrick Check PVT alarms. 06:30 - 08:00 1.50 WHSUR P DECOMP Bleed off hanger void & actuator valve. N/D tree & adapter flange. 08:00 - 10:00 2.00 BOPSU P DECOMP N/U BOPE. 10:00 - 16:30 6.50 BOPSU P DECOMP Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. Tested hydil, LP 250 psi, HP 3500 psi. Used 2 7/8" & 4 1/2" test joints. No failures. BOP test witnessing waived by Chuck Schieve w/ AOGCC. 16:30 - 19:30 3.00 PULL P DECOMP PU 7" lubricator extension. MU DSM lubricator & test to 500 psi. Pull TWC, tubing on vacuum. LD lubricator and lubricator extension. 19:30 - 21:00 1.50 PULL P DECOMP MU landing joint. Screw into hanger, BOLDS. Pull hanger to floor, PUW = 60K. Break out and LD hanger. MU circulating head to tubing. 21:00 - 22:30 1.50 PULL P DECOMP CBU ~ 6 BPM / 300 psi. Returned crude and gas to surface while circulating. Circulated 216 bbls and lost 6 bbls. Monitor well for 10 min. Well on Vac. 22:30 - 00:00 1.50 PULL P DECOMP Run continuous hole fill. LD 4-1/2" tubing. 8/17/2008 00:00 - 03:00 3.00 PULL P DECOMP Cont to LD 4-1/2" tubing wf continuous hole fiN. LD a total of 124 jts, 1 XN nipple ass'y, 1 mule shoe ass'y. Lost 17 bbls while pulling tubing. 03:00 - 04:30 1.50 BUNCO RUNCMP Clean & clear rig floor. Take out rest of tubing from shed. RU to run ESP. Bring pump & equipment to shed and rig floor. String ESP cable from spooler to rig floor. 04:30 - 08:30 4.00 BUNCO RUNCMP PJSM. MU ESP pump ass'y. 08:30 - 16:00 7.50 BUNCO RUNCMP Single in hole w/ 2-7/8" ESP completion. Check conductivity every -2000' -Flush pump w/ 10 bbls (.5 BPM / 650 psi). MU Printed: 9/2/2008 11:47:23 AM B P Page 4 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Cade NPT Phase Description of Operations 8/17/2008 08:30 - 16:00 7.50 BUNCO RUNCMP landing joint &HGR. Cut ESP cable & pull over sheave. -PUW = 41 K, SOW = 40 K. -Ran 133 joints, 1 XN ass't', 2 GLM ass't'. -Ran 74 LaSalle clamps, 3 Flat Guards & 5 Protectalizers. 16:00 - 17:00 1.00 BUNCO RUNCMP Safety stand down. Review YTD incidents & mitigations. 17:00 - 19:00 2.00 BUNCO RUNCMP Clear rig floor. Make field connector splice. Plug in penetrator & test. 19:00 -20:00 1.00 BUNCO RUNCMP Land HGR. LD landing jt. RILDS. Clear rig floor. 20:00 - 21:00 1.00 BUNCO RUNCMP Dry rod TWC. Test to 3500 psi from above and rolling test to 500 psi for 10 min. 21:00 - 23:00 2.00 BOPSU P RUNCMP ND BOPE. 23:00 - 00:00 1.00 WHSUR P RUNCMP NU Tree. 8/18/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP RU to test tree. Test TBG adapter to 3500 psi for 30 min. Test tree to 5000 psi with diesel. 01:00 - 02:00 1.00 WHSUR P RUNCMP P/T lubricator to 500 psi. Pull TWC. Set BPV. LD lubricator. Rolling test to 500 psi -charted. 02:00 - 03:00 1.00 WHSUR P RUNCMP Safety Standown. Review incidents & mitigations. ***Rig Release ®03:00""* Printed: 9/2/2008 11:47:23 AM . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc 1 t)~ ~~O~ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021530 Well Name/No. MILNE PT UNIT SB 1-15L 1 Operator BP EXPLORATION (ALASKA) INC MD 9000,~ TVD 4042 ~ Completion Date 9/1/2002 /' Completion Status 1-01L Current Status 1-01L ~--------~+--- --~---- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~----- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, ASI, IFR/CASANDRA Well Log Information: Sf? ¿ ;Z Ct ~ 21tt:L API No. 50-029-23106-60-00 UIC N (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name --~_._-~----~ Rpt Directional Survey o£ D vff'338 LIS Verification Interval Start Stop 4777 9000 Log Log Run Scale Media No 1 1 .--. OH/ CH Received, Comments Open 10/2/2002 MWD Case 1216/2002 Open 10/2/2002 42 8945 Rpt Directional Survey 4777 9000 Car- cD- CQirectional Survey 4777 9000 Open 10/2/2002 ~'4r L-Btnfëtlonal Survey 4777 9000 Open 10/2/2002 Rpt LIS Verification 1 42 8945 Case 12/6/2002 ~D C Asc ~961 LIS Verification 1,2,5,6 42 8952 Open 6/2/2003 ŒD C Pdf U1961 Induction/Resistivity 25 1,2,5,6 112 9000 Open 6/2/2003 \~ \ C Pdf kf1961 I ncluction/Resistivity 25 1,2,5,6 112 4042 Open 6/2/2003 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/23/2002. MWD MWD - ROP, DGR, EWR - MD MWD - DGR, EWR - TVD '- DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021530 Well Name/No. MILNE PT UNIT SB 1-15L 1 Operator BP EXPL.ORATION (ALASKA) INC API No. 50-029-23106-60-00 MD 9000 TVD 4042 Completion Date 9/1/2002 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION vfÐ Daily History Received? ~N Q/N Well Cored? Chips Received? -ytN"/ Formation Tops Analysis Received? ~ ----~--- Comments: '~' Compliance Reviewed By: ~ Date: 7c-r O~~ ----- ._~._-~~---- '- ) ) ,!jOd -- /53 #=!\9éol WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 15, 2003 RE: MWD Formation Evaluation Logs: MPI-15 L 1, AK-MW-22136 MPI-15 Ll: Digital Log Images: 50-029-23106-60 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE AITACBED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEtVED DaiWN 02 2003 Alaska Oil & Gas Cons. Commtuion :~~J~ Signed~,r\~~~ ~~'~ ~"" .. c' \-~ þ~ ~.\~ ) ) a oé9-J53 /133 '( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmn1. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 04, 2002 RE: MWDFormationEvaluationLogs MPI-15 LI, AK-MW-22136 1 LIS formatted Disc with verification listing. API#: 50-029-23105-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: æ~~- ~ Signed: Q <[ s: "- M ~ ;g I\J I\J "- .... "- <D '" ~ " ~ ~ If> "- s: L 0 u :> " c 0 u M ) I ASP GRID'" - Z-A \ 2'34'41" I I-PAD PLANT) ~o;).. - /53 . Îr> N t .14 .13 .12 .11 . 8 . 7 . 4 . 6 . 3 . 5 . 2 . 9 .1 .10 ~ 1-15 . EXISTING CONDUCTOR LEGEND + AS-BUILT CONDUCTOR :.---"...-.---- - _....'.._J MPU I-PAD NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.9999031 3. HORIZONTAL CONTROL IS BASED ON MPU I-PAD MONUMENTS 1-1 AND 1-2. 4. PLAN LOCATION OF MPI-15 WAS MOVED TO 25 FT. EAST OF MPI-10 DUE TO PIPING OBSTRUCTIONS. 5. DATE OF SURVEY: AUGUST 7, 2002. 6. REFERENCE FIELD BOOK: MP02-06 PGS. 45-46. , <" " .' . " PROJECt AREA ,;)r ::) VICINITY MAP SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 7, 2002. LOCATED WITHIN PROTRACTED SEC. 33, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPI-15 Y= 6,009,441.71 N 1,119.49 70"26'11.545" 70.4365404" 35.0' 2,326' FSL X= 551,729.59 E 1,435.00 149'34'41.664" 149.5782400" 3,641' FEL ~ I\J '" ... /' I\J I\J /' Q <[ "- ~ ~ 0 8/07/02 ISSUED FOR INFORMATION .;; NO. DA1E F. RObeÐt ORA....,..: JACOBS l -- t..~ CHECKED: AlliSON ij]-- ~~: ~~ :::NG: 7/17/02 - FRB02 !.API 01-03 ¡ å]~~illœo JOB NO: JJC LOH ENCINEERS ..., lAND SUR""""" SC ALE: "'" "ST nmoŒO lAN[ 1'=150' BY OiK ~ACE. AlASkA 99503 REVISION ObP MILNE POINT UNIT I-PAD AS-BUILT CONDUCTOR WELL MPI-15 SHEET: 1 OF 1 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2326' NSL, 3641' WEL, Sec. 33, T13N, R10E, UM At top of productive interval 1034' NSL, 1672' WEL, SEC. 33, T13N, R10E, UM At total depth 2801' NSL, 4626' WEL, SEC. 34, T13N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 62.5' ADL 025906 12. Date Spudded! 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8-26-2002 8-29-2002' 9-1-2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9000 4042 FT 9000 4042 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, ABI, IFRICASANDRA 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 92# 47# 26# 12.7# 4-1/2" ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 202-153 8. API Number 50- 029-23106-60 9. Unit or Lease Name Milne Point Unit 10. Well Number MPI.15L 1 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) -r//;v';;~{~ 1/$19 Áu> ~ 31{..,$' 1ÝJJ GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 28' 112' 42" 260 sx Arctic Set (Approx.) 28' 3085' 12-1/4" 919 sx Class 'L", 225 sx Class 'G' 25' 4849' 8-1/2" 84 sx AS Lite, 189 sx Class 'G' 4840' 89651 6-1/8" Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE MD 4869' - 8922' 3974' - 4042' 27. Date First Production September 1, 2002 Date of Test Hours Tested 9-11-2002 12 25. TUBING RECORD DEPTH SET (MD) 4262' SIZE 2-7/8", 6.5#, L-80 PACKER SET (MD) NIA TVD TVD MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 893 OIL-BBL GAs-McF 271 GAs-McF OIL GRAVITY-API (CORR) WATER-BBL 893 WATER-BBL CHOKE SIZE GAS-OIL RATIO 304 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 28. No core samples were taken. Form 10-407 Rev. 07-01-80 OCT I 4 2002 RBDMS BFL OCT 0 4 2002 Alaska OfJ& Gas GoDS. Commission ~ I~ l\nchorago Submit I n Duplicate ) ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF1-NB 4514' 3836' SBE4-NC 4581' 3868' SBE2-NE 4621' 3886' SBE1-NF 4736' 3931' TSBD-OA 4843' 3966' RECEIVED 31. List of Attachments: OCT 0 4 2002 AlasKa 01& Gas Gons. COmmission Summary of Daily Drilling Reports, Surveys, Post Rig Summary an~ a Leak-off~~9~~est Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed SOndra~~e Technical Assistant Date (O~O)--()'~ MPI-15L 1 202-153 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Matt Green, 564-5581 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 Well: Field: API: Permit: ) ) MPI-15/ L 1 Milne Point Unit 50-029-23106-00 / 50-029-23106-60 202-152 / 202-153 Rig Accept: 08/15/02 Rig Spud: 08/16/02 Rig Release: 09/01/02 Drilling Rig: Doyon 141 POST RIG WORK 09/03/02 Approx. 130 bbls of 10.8-11.0 brine recovered from the well. Calculated recoverable brine above the pump was::::: 140 bbls. Well is freeze protected and ready to flow back to a tank for clean out of the rest of the brine. ') ) ) MILNE POINT. ALASKA TO: FROM: WELL# Main Category: Sub Category: Sub Category: Operation Date: Bixby/Hefley Lee Hulme MPI-15 RWO Brine recovery Pump 9/3/02 Date: 19/3/02 Objective: Recover Brine after rig move. Operation: Arrived location, held pre-job safety meeting. MIRU, pressure tested to 3500 psi. Start down the tubing with source water pressure through the ESP, caught fluid @ 1 bbl. Pumped 7.5 bbls until returns to the surface from the annulus. Regulated back pressure to 50 psi for the tubing volume. Continue pumping @ .35 bpm wI 400 psi as the source water turned the corner (25 bbls) and adjusted back pressure to compensate the weight loss of the fluid. Pumped 134 bbls of source water @ .35-.66 bpm wI 400-800 psi max (100 bbls away). Used well assist once we ran out of water and flowed to the tank until the weight dropped to 9.6. between shakeouts. Recovered to the vac truck::::: 130 bbls of 10.8 - 11.0 brine which was taken to MI for clean up and future use on H-13. RD to get freeze protect fluids. MIRU, PT to 3500 psi. Pumped 15 bbls diesel down the tubing for freeze protection RU to IA. PT to 3500 psi. Freeze protected the annulus with 65 bbls of dead crude. Conclusion: Approx. 130 bbls of 10.8-11.0 brine recovered from the well. Calculated recoverable brine above the pump was::::: 140 bbls. Well is freeze protected and ready to flow back to a tank for clean out of the rest of the brine. MSU330752 811900 846800 IDiesel RWO / Brine Recover / Pump Fesco = $ 2600.00 = $ 630.00 Diesel Used 115 bbls Methanol Used I None Legal Name: MPI-15 Common Name: MPI-15 Test Date 8/18/2002 8/21/2002 FIT FIT Test Type TesfDepth(TMD) 3,112.0 (ft) (ft) BP l.J¡~ak-Off Test Summary Tøstpepth (TVD) 2,783.0 (ft) (ft) AMW 9.10 (ppg) (ppg) Surface Pressure 370 (psi) (psi) Leak Off Pressure (BHP) 1 ,686 (psi) (psi) Page 1 of 1 EMW 11.66 (ppg) 11.66 (ppg) .~ ~/ Printed: 9/4/2002 10:52:54 AM ) ) Legal Well Name: MPI-15 Com mon Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Hours. ..Tå$k CÓdë NPT Pháse 8/14/2002 20:00 - 21 :00 1.00 MOB P PRE MOVE UTILITY MODULES OFF WELL MPS-31 21 :00 - 21 :30 0.50 MOB P PRE MOVE PIPE SHEDS AND ROCK WASHER OFF WELL 21 :30 - 22:30 1.00 MOB P PRE MOVE SUB OFF WELL MPS-31 22:30 - 23:30 1.00 MOB P PRE MOVE SUB FROM S PAD TO TO MILNE PT ROAD 23:30 - 00:00 0.50 MOB P PRE MOVE PIPE SHEDS - PIT MODULE UP TO MILNE PT ROAD TO FOLLOW SUB TO I PAD 8/1512002 00:00 - 05:00 5.00 MOB P PRE MOVING SUB - PIPE SHED - PIT MODULES TO I PAD - MOVING PUMP - MOTOR MODULES TO I PAD - SPOT SUB - PIT MODULES - PIPE SHEDS 05:00 - 08:30 3.50 MOB P PRE MOVE AND SPOT PUMP - MOTOR - BOILER MODULES 08:30 - 10:30 2.00 MOB P PRE RIG UP UTILlTIY MODULES - PIPE SHED - PREPARE PITS FOR MUD 10:30 - 12:00 1.50 MOB P PRE NIPPLE UP DIVERTER SYSTEM 12:00 - 13:00 1.00 MOB P PRE SET - BERM ROCK WASHER 13:00 - 14:00 1.00 MOB P PRE CHANGE OUT SAVER SUB FROM 31/2" TO 5" - COMPLETE RIG ACCEPTENCE (ACCEPT RIG @ 14:00 HRS 8/15/2002) 14:00 - 15:30 1.50 RIGU P PRE FINISH NIPPLE UP DIVERTER - PANIC LINE AND HOOK UP TO FLOW LINE 15:30 - 18:00 2.50 RIGU P PRE LOAD - STRAP 4500' OF 5" DRILL PIPE IN PIPE SHED - MIXING SPUD MUD 18:00 - 18:30 0.50 RIGU P PRE FUNCTION TEST DIVERTER SYSTEM -ACCUMULATOR TEST - START 3000 END 1950 - 200 PSI 22 SEes - FULL PRESSURE 2 MINS 36 SEC -16 SEes TO CLOSE ANNULAR AND OPEN DIVERTER VALVE - 6 BOTTLES AVG PRESSURE 2125 PSI - RIGHT TO WITNESS OF DIVERTER FUNCTION TEST WAVIED BY CHUCK SCHEVE 18:30 - 19:30 1.00 RIGU P PRE CHANGE OUT TOP DRIVE PIPE GRABBERS FROM 3.5" TO 5" AND HANDLING TOOLS 19:30 - 23:30 4.00 DRILL P SURF PICK UP 5" DRILL PIPE FROM PIPE SHED - STANDING BACK IN DERRICK - 4500' 23:30 - 00:00 0.50 DRILL P SURF LOAD BHA IN PIPE SHED 8/16/2002 00:00 - 02:30 2.50 DRILL P SURF LOADING BHA ASSEMBLY IN PIPE SHED - STRAP SAME - PICK UP 5" HWDP - FLEX COLLARS - STAND IN DERRICK 02:30 - 03:30 1.00 DRILL P SURF PICK UP BHA - UP LOAD MWD - 03:30 - 04:00 0.50 DRILL P SURF PRE-SPUD MEETING WITH CREW - DD - MUD ENGINEER - MWD 04:00 - 04:30 0.50 DRILL P SURF RIG UP HOWCO SLICK LINE UNIT FOR RUNNING GYRO 04:30 - 05:00 0.50 DRILL P SURF FILL CONDUCTOR - CIRCULATE SURFACE SYSTEM TO CHECK FOR LEAKS 05:00 - 06:30 1.50 DRILL P SURF SPUD WELL IN - DRILL FROM 112' TO 261' - WOB 10K- GPM 400 - PP ON 1000 - OFF 900 - RPM 70 06:30 - 07:30 1.00 DRILL P SURF POH TO 84' - MAKE UP FLEX DC'S - RIH TO 261' 07:30 - 13:30 6.00 DRILL P SURF DIRECTIONAL DRILL FROM 261' TO 816' - WOB 35 - GPM 400 - PP ON 1100 - OFF 990 - STARTED BUILD AT 261'- DRILL TO 818' UNABLE TO ACHIEVE BUILD - CIRC HOLE CLEAN 13:30 - 15:00 1.50 DRILL N DPRB SURF POH - SET MOTOR TO 1.83 DEGREE FROM 1.5 DEGREE - TIH TO 816' 15:00 - 00:00 9.00 DRILL P SURF DIRECTIONAL DRILL FROM 816' TO 1650' - WOB 30K TO 35K - RPM 60 - TO 6K ON - OFF 2K - GPM 500 - PP 2140 ON - OFF 1880 - PU 82 - SO 74 - ROT 78 8/17/2002 00:00 - 08:00 8.00 DRILL P SURF DIRECTIONAL DRILL FROM 1650' TO 3092'. WOB 30 - 35K- 60 RPM - TO 6K ON 2K OFF - GPM 500 -PP 2140 ON - OFF Printed: 9/4/2002 10:53:07 AM ) Leg al Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Date Frdm~ To Hours TaSk Code NPT 8/1712002 00:00 - 08:00 8.00 DRILL P SURF 08:00 - 09:00 1.00 CASE P SURF 09:00 - 10:30 1.50 CASE P SURF 10:30 - 11 :30 1.00 CASE P SURF 11 :30 - 14:00 2.50 CASE P SURF 14:00 - 17:30 3.50 CASE P SURF 17:30 - 19:00 1.50 CASE P SURF 19:00 - 22:30 3.50 CASE P SURF 22:30 - 23:00 0.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 8/18/2002 00:00 - 01 :30 1.50 CASE P SURF 01 :30 -05:00 3.50 CASE P SURF 05:00 - 07:00 2.00 CASE P SURF 07:00 - 08:30 1.50 CASE P SURF 08:30 - 09:30 1.00 CASE P SURF 09:30 - 11 :30 2.00 CASE P SURF 11 :30 - 12:00 0.50 BOPSUR P SURF 12:00 - 14:00 2.00 BOPSUR N SFAL SURF 14:00 - 17:00 3.00 BOPSURP SURF 17:00 - 18:00 1.00 BOPSUR P SURF . O~scriþtiohþfOþeratiÖns 1880. PU 82 - SO 74 - ROT 78 (HYDRATES FROM 1880' TO 1980') CIRCULATE HOLE CLEAN AT 3092'.590 GPM AT 2400 PSI. PUMPED OUT OF HOLE TO 810' WITH FULL DRILL RATE. 550 GPM AT 2200 PSI. NO PROBLEMS. RUN BACK IN HOLE TO 3092' WITH NO PROBLEMS. CIRCULATED HOLE CLEAN. STOOD BACK ONE STAND EVERY 30 MINUTES. CIRCULATED BOTTOMS UP 4 TIMES. 590 GPM AT 2200 PSI. PUMPED OUT OF HOLE TO 810'. PULLED OUT HOLE TO SURFACE. LAID DOWN MWD AND MOTOR. RIG UP CASING CREW PJSM - PICK UP AND RUN 74 JOINTS L-80 40# 95/8" BTC CASING - LAND SAME - SHOE 3086' - FIe 3005' - GOOD RETURNS NO LOSSES WHILE RUNNING CASING RIG DOWN FRANK'S FILL UP TOOL - MAKE UP HOWCO CEMENTING HEAD AND CEMENTING LINES BREAK CIRC WITH 25 SPM - STAGING UP TO 77 SPM MAX RATE - CIRCULATE AND CONDITION MUD FOR CEMENT JOB CIRCULATE AND CONDITION MUD FOR CEMENT JOB PUMP 10 BBLS WATER - TEST LINES TO 3500 PSI - DROP BOTTOM PLUG - PUMP 40 BBLS WATER - PUMP 50 BBLS ALPHA WEIGHTED SPACER - START LEAD CEMENT @ 1 :50 AM - PUMPED 919 SXS (680 BBLS) PERMAFROST L CEMENT MIXED AT 10.7 PPG - 20 BBLS GOOD LEAD CEMENT TO SURFACE - PUMPED 225 SXS (46 BBLS) PREMIUM CEMENT + 1 % CALCIUM CHLORIDE + .3% HALAD 344 + .2% CFR-3 MIXED IN A 15.8 PPG SLURRY - DISPLACE WITH 30 BBLS WATER HOWCO - 198 BBLS MUD WITH RIG - BUMP PLUG WITH 1650 PSI - BLEED PRESSURE BACK - FLOATS HELD - CIP 05:00 HRS - TOTAL CEMENT TO SURFACE 294 BBLS LAND DOWN LANDING JOINT - FLUSH OUT DIVERTER AND RISER - RIG DOWN CASING CREWS NIPPLE DOWN DIVERTER ORIENT - NIPPLE UP WELL HEAD - TEST TO 1000 PSI FOR 10 MIN - GOOD NIPPLE UP BOP'S RIG UP TEST EQUIPMENT PULL LOWER TEST PLUG - WILL NOT HOLD - PICK UP UPPER TEST PLUG TEST BOP'S - ANNULAR 250 LOW 2500 HIGH - PIPE RAMS UPER / LOWER 250 LOW 4000 HIGH - MANIFOLD 250 LOW 4000 HIGH - HYD CHOKE - KILL HYD 250 LOW 4000 HIGH MANUAL CHOKE - MANUAL KILL 250 LOW 4000 HIGH - UPPER IBOP LOWER IBOP - FLOOR SAFETY VALVES 250 LOW 4000 HIGH - ALL TEST HELD FOR 3 MINS EACH PULL UPPER TEST PLUG - INSTALL NEW LOWER TEST PLUG TEST 250 LOW - 4000 HIGH FOR 3 MINS EACH TEST - PULL LOWER TEST PLUG AND INSTALL LONG BOWL WEAR RING - RIGHT TO WITNESS TEST WAIVED BY CHUCK SCHEVE WITH AOGCC Printed: 9/4/2002 10:53:07 AM ') ) Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Date FromJTö Höurs TaSk Code NPT D~$(jr'iptiÖn..ofQperations 8/18/2002 18:00 - 18:30 0.50 CASE P SURF PU BHA AND UP LOAD MWD 18:30 - 19:30 1.00 CASE P SURF TIH - SHALLOW TEST MWD - CON'T RIH TO 2990' TAG UP 19:30 - 20:00 0.50 CASE P SURF BREAK CIRC - CIRCULATE CONDITION MUD FOR CASG TEST 20:00 - 20:30 0.50 CASE P SURF TEST 9 5/8" CASING FOR 15 MINS RECORD ON CHART PRESSURE 1500 PSI - DEPTH 2970' 20:30 - 22:30 2.00 CASE P SURF DRILL 14' CEMENT - FLOAT COLLAR @ 3004' -79' CEMENT - SHOE @ 3084' - 22:30 - 23:30 1.00 CASE P SURF DRILL 20' NEW HOLE @ 3112' - CIRCULATE BALANCE MUD WEIGHT TO 9.1 IN AND OUT 23:30 - 00:00 0.50 CASE P SURF PERFORM FIT - DEPTH 3112' MD - 2783 TVD - MUD WEIGHT IN HOLE 9.1 - SURFACE PRESSURE 370 PSI = 11.67 FIT 8/19/2002 00:00 - 15:00 15.00 DRILL P INT1 DIRECTIONAL DRILL FROM 3112' TO 5216' - WOB 20K TO 30K - RPM 80 - TQ ON 9K - OFF 8K - PP 1950' ON - OFF 1700 - GPM 450 - PU 145 - SO 87 - ROT 105 15:00 - 20:00 5.00 CASE N FLUD INT1 CIRCULATE HOLE - RAISE MUD WEIGHT FROM 10.2 TO 10.8 - (GAS CUT FROM 10.1 TO 9.1) ON BTMS UP 20:00 - 20:30 0.50 CASE P INT1 FLOW CHECK WELL - WELL STABLE - CHECK 30 MINS 20:30 - 21 :30 1.00 CASE P INT1 CBU 2 X - LOTS OF OIL COMING OUT - 6% OIL IN MUD - GAS CUT FROM 10.9 TO 10.7 21 :30 - 00:00 2.50 CASE P INT1 PUMP OUT TO 3350' - TIGHT SPOT AT 4368' TO 4345' - WORK PIPE WITHOUT BACK REAMING NO SUCCESS - BACK REAM TIGHT SPOT FROM 4370 TO 4340' - CON'T PUMP OUT HOLE - FLOW CHECK WELL AT 4000' - WELL STABLE - CON'T PUMP OUT HOLE - GPM 400 - PP 1190 PSI 8/20/2002 00:00 - 00:30 0.50 CASE P INT1 CON'T PUMP OUT TO 3000' - MONITOR WELL 15 MINS - WELL STABLE 00:30 - 01 :30 1.00 CASE P INT1 RIH - BREAK CIRC @ 4167' - CON'T RIH - NO TIGHT SPOTS SEEN ON TRIP IN - HOLE IN GOOD SHAPE 01 :30 - 03:30 2.00 CASE P INT1 CIRCULATE I CONDITION MUD - CBU 3.5 X - GPM 450 - RPM 100 - PP 1850 - MUD WEIGHT CUT TO 10.5 FROM 10.9 ON FIRST BOTTOMS UP - MUD WEIGHT WAS STEADY AT 10.8 ON NEXT TWO BOTTOMS UP - MONITOR WELL- WELL STABLE 03:30 - 08:30 5.00 CASE P INT1 PUMP OUT TO SHOE - GPM 400 - PP 1550 PSI 08:30 - 09:00 0.50 CASE P INT1 MONITOR WELL, SLUG PIPE 09:00 - 11 :30 2.50 CASE P INT1 TRIP OUT WITH BHA, LAY DOWN MWD,MOTOR,STABS 11 :30 - 13:00 1.50 CASE P INT1 CHANGE RAMS IN BOPS TO 7", TEST TO 250-4,000 PSI 13:00 -14:30 1.50 CASE P INT1 RIG UP CSG TOOLS, PJSM 14:30 - 17:00 2.50 CASE P INT1 RUN 7" 26# L-80 BTC CSG TO 1900' 17:00 - 17:30 0.50 CASE P INT1 CHANGE OUT RUBBER ON FRANKS FILL UP TOOL 17:30 - 19:00 1.50 CASE P INT1 PICK UP CSG TO 3,000 FT 19:00 - 19:30 0.50 CASE P INT1 CIRC @ 3,000' 47 STIMIN 250 PSI PUMPED 1400 PUMP STKS 19:30 - 20:00 0.50 CASE P INT1 PICKING UP CSG 3,000 TO 5,206 STRING WT 90,000 DOWN 150,000 UP TOTAL JTS RUN 128, SHOE @ 5206, FLOAT@ 5122 20:00 - 22:30 2.50 CASE P INT1 RIG DOWN FRANKS TOOL, RIG UP CEMENT HEAD 22:30 - 00:00 1.50 CASE P INT1 CIRC TO THIN MUD FOR CEMENT JOB, CIR WITH 47 ST/MIN 350 PSI FOR TWO CSG VOLUMES 5,000 PUMP ST. (BOTTOMS UP MUD WAS CUT FROM 10.8 TO 10.6) 8/2112002 00:00 - 00:30 0.50 CASE P INT1 CIRC. TO THIN MUD FOR CEMENT JOB, VIS 48 YP 15 Printed: 9/4/2002 10:53:07 AM ) ) Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Date From;';Tö HOUfS >Task Code NPT Phase 8/21/2002 00:30 - 01 :30 1.00 CEMT P INT1 TEST LINES TO 3500 PSI, CEMENT WITH 5 BBlS WATER AHEAD, 20 BBlS ALPHA SPACER 11.0#, 33 BBlS 84 SX CLASS E 12.0#, TAil WITH 39 BBlS 189SX. CLASS G 15.8# MIXED AND PUMP @ 4 BBlS MIN. 450 PSI, KICKED OUT TOP PLUG WITH 5 BBlS WATER. 01 :30 - 02:30 1.00 CEMT P INT1 DISPLACE WITH RIG PUMP AT THE RATE OF (FIRST 1844 STKS 59 SPM, NEXT 296 PUMP STKS 23 SPM, LAST 120 PUMP STKS 12 SPM), FUll RETURNS THRU OUT JOB, BUMP PLUG WITH 1400 PSI @ 0215, FLOAT HELD 02:30 - 03:30 1.00 CEMT P INT1 LAY DOWN CEMENT HEAD AND LANDING JT. CHANGE OUT BAilS 03:30 - 04:30 1.00 BOPSUR P INT1 INSTAll 7" PACK OFF AND TEST TO 5,000 04:30 - 05:00 0.50 CASE P INT1 FREEZE PROTECT 7' BY 9 5/8 ANNlUS WITH HB&R WITH 60 BBlS DIESEL PUMPED @ 2.5 BBlS MIN 1200 PSI 05:00 - 10:00 5.00 CASE P INT1 LAYING DOWN 5" DRill PIPE OUT OF DERRICK 10:00 -12:00 2.00 CASE P INT1 CHANGE OUT RAMS IN BOPS TOP 3.5X6 BTM 3.5 12:00 - 13:30 1.50 CASE P INT1 CHANGE OUT SAVER SUB AND GRABBERS ON TOPDRIVE TO 3.5 13:30 -14:30 1.00 CASE P INT1 CUT DRilLING LINE 14:30 - 15:30 1.00 CASE P INT1 TEST 3.5 RAMS TO 250/4000 PSI FOR 5 MIN. EACH INSTAll WEAR RING 15:30 - 19:00 3.50 CASE P INT1 PICK UP 3.5 MULE SHOE AND 3.5 S-135 13.3# DRill PIPE 135 JTS 19:00 - 19:30 0.50 CASE P INT1 CIRC DRill PIPE VOLUME 19:30 - 20:30 1.00 CASE P INT1 TRIP OUT AND STAND IN DERRICK 20:30 - 00:00 3.50 CASE P INT1 PICKING UP 3.5 MULE SHOE AND 3.5 S-135 15.5# DRill PIPE 8/22/2002 00:00 - 00:30 0.50 CASE P INT1 eiRe, DRill PIPE VOLUME 00:30 - 02:00 1.50 CASE P INT1 TRIP OUT AND STAND IN DERRICK 02:00 - 04:00 2.00 CASE P INT1 PICK UP BHA, 6.125 2643 PDC, 4 3/4 SPERRY DRill 1.5 BEND MOTOR, FLOAT SUB, 4 3/4 GRAMMA/RES, 4 3/4 DM, HANG OFF SUB,3 FLEX COlLAR,JAR 04:00 - 06:00 2.00 CASE P INT1 TRIPPING IN TO 5,125 06:00 - 07:00 1.00 CASE P INT1 CIRC, DRill PIPE VOLUME, TEST CSG WITH 3,500 PSI FOR 30 MIN. 07:00 - 08:00 1.00 CASE P INT1 DRill CEMENT FROM 5125 TO 5204 08:00 - 09:00 1.00 CASE P INT1 DISPLACE HOLE WITH 9.5 MUD, MONITOR WEll 09:00 - 10:00 1.00 CASE P INT1 DRill SHOE AND CEMENT AND 30 FT OF NEW HOLE TO 5,246', MONITOR WEll 10:00 - 11 :00 1.00 CASE P INT1 FIT TEST WITH 9.5 MUD 4037 TVD, 490 PSI = 11.8 MUD WT. 11 :00 - 13:30 2.50 CASE P INT1 DISPLACE WEll WITH 9.5 FLOW-PRO MUD 13:30 - 00:00 10.50 DRill P PROD1 DIRECTIONAL DRill 5246' TO 6000' WITH 70 RPM 250 GALS PER MIN., 1,800 PSI 5/10 BIT WT, TQ 4,000, AST 5 ART 2.75 (ANGLE DROPPING AND CASANDRA CaRR. SHOWING US 60 TO THE SOUTH) 8/23/2002 00:00 - 02:30 2.50 DRilL N RREP PROD1 WORKING ON TOP DRIVE, CIRC. 02:30 - 03:30 1.00 DRill N RREP PROD1 PUMPING OUT TO SHOE @ 5204, TO FINISH REPAIRS ON TOP DRIVE 03:30 - 06:00 2.50 DRill N RREP PROD1 WORKING ON TOP DRIVE 06:00 - 07:00 1.00 DRill P PROD1 TRIP TO BOTTOM Printed: 9/4/2002 10:53:07 AM ) ) BP QperatiØn~..,.,$lImma.ry.',..~ep()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From'" To HÒurs.. .' Task Códè NPT 8/2312002 07:00 - 08:30 1.50 DRILL P PROD1 DIRECTIONAL DRILL 6000' TO 6095' TVD 4088 WITH 70 RPM 250 GALS PER MIN., 1,800 PSI 5/10 BIT WT, TO 4,000, 08:30 - 09:00 0.50 DRILL N DFAL PROD1 09:00 - 10:00 1.00 DRILL N DFAL PROD1 10:00 - 10:30 0.50 DRILL N DFAL PROD1 10:30 - 12:00 1.50 DRILL N DFAL PROD1 12:00 - 14:00 2.00 DRILL N DFAL PROD1 14:00 - 18:00 4.00 DRILL P PROD1 18:00 - 21 :00 3.00 DRILL N 21 :00 - 22:30 1.50 DRILL N 22:30 - 00:00 1.50 DRILL P 8/24/2002 00:00 - 00:00 24.00 DRILL P DFAL PROD1 DFAL PROD1 PROD1 PROD1 8/25/2002 00:00 - 10:00 10.00 DRILL P 10:00 - 12:00 2.00 CASE P 12:00 - 15:30 3.50 CASE P 15:30 - 17:30 2.00 CASE P 17:30 - 19:00 1.50 CASE P 19:00 - 22:00 3.00 CASE P 22:00 - 00:00 2.00 CASE P 00:00 - 01 :00 1.00 CASE P 01 :00 - 05:00 4.00 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 08:00 2.50 CASE P 08:00 - 10:30 2.50 CASE P 10:30 - 11 :30 1.00 CASE P 11 :30 - 12:00 0.50 CASE P 12:00 - 13:00 1.00 CASE P 13:00 - 14:00 1.00 CASE P 14:00 - 18:00 4.00 CASE P 18:00 - 20:00 2.00 CASE P 20:00 - 20:30 0.50 CASE P PROD1 COMP COMP COMP COMP COMP COMP 8/26/2002 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP (MOTOR NOT BUILDING OR TURNING RIGHT) CIRC PUMPING OUT TO SHOE, WITH FULL DRILLING RATE, CIRC BOTTOMS UP, MONITOR WELL, SLUG PIPE TRIP OUT TO BHA UD JARS PULL BHA FOUND SLEEVE ON MOTOR HAD BACKED OFF, LAY DOWN MOTOR PULL WEAR RING, TEST BOPS 250-4,000 PSI FOR 5 MIN. TEST ANNULAR 250-2,500, ACCUM TEST, INSTALL WEAR RING, THE RIGHT TO WITNESS BOP TEST WAS WAVIER BY JOHN SPAULDING AOGCC. PICK UP NEW MOTOR, TRIPPING IN TO 5,500 TO SIDE TRACK WELL ORIENT 150 TO LEFT AND SIDETRACKING WELL DIRECTIONAL DRILL 5510' TO 5700' WITH 70 RPM 250 GALS PER MIN., 1,900 PSI 5/10 BIT WT, TO 4,OOO,AST 1.25 ART .5 DIRECTIONAL DRILL 5700' TO 8138' WITH 85 RPM 250 GALS PER MIN., 2600 PSI 5/10 BIT WT, TO 6,000 AST 6.75 ART 7.5 DIRECTIONAL DRILL 8138' TO 9050' WITH 85 RPM 250 GALS PER MIN., 2800 PSI 5/10 BITWT, TO 6,000 eiRe, THREE BOTTOMS PUMP OUT TO SHOE FULL DRILLING RATE TRIPPING TO BOTTOM, SET DOWN @ 5540 KICK OFF@ 5510, REAM AND WORKED KICK OFF, FROM 5443 TO 5630 TRIPPING TO BOTTOM, HOLE TAKING MUD ON TRIP IN LOSS APP. 20 BBLS ON TRIP CIRC 4 BOTTOMS UP, WITH 2900 PSI 250 GALS MIN. 100 RPMS, FULL RETURNS PUMP OUT TO SHOE WITH FULL DRILLING RATE, DISPLACE HOLE WITH NEW MUD. PUMP OUT TO SHOE WITH FULL DRILLING RATE, DISPLACE HOLE WITH NEW MUD. TRIP OUT AND LAY DOWN BHA RIG UP TO PICK UP 4.5 12.6# L-80 IBT SLOTTED LINER, PJSM PICKING UP 98 JTS OF 4.5 LINER AND BAKER HMC LINER HANGER, AND BAKER ZXP LINER TOP PACKER TRIPPING IN WITH LINER DROP BALL ,PRESSURE UP TO 2300PSI,SET HANGER, AND LINER TOP PACKER, LINER TOP 5,094 LINER SHOE 9,042 CIRC AND DISPLACE HOLE WITH NEW MUD CUT DRILL LINE TRIP OUT WITH LINER RUNNING TOOLS PICK UP 3.5 SPACE OUT JTS, WHIPSTOCK AND MWD TOOLS TRIP IN WITH WHIPSTOCK ORIENT WHIPSTOCK 3 DEGREES TO LEFT, AND SET Printed: 9/4/2002 10:53:07 AM ) ) Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 HOurs ..,Task Code NPT DéscriptionÖfQp~råtiÖn$ 8/26/2002 20:00 - 20:30 0.50 CASE P COMP WHIPSTOCK @ 4849 20:30 - 00:00 3.50 CASE P COMP CUTTING WINDOW@ 4849 TO 4867 WITH 250 GALS MIN. 1200 PSI 1 OORPMS TOP OF WINDOW 4849 BOTTOM 4861 ..; 8/27/2002 00:00 - 00:30 0.50 CASE P COMP CUTTING WINDOW @ 4867 TO 4879 WITH 250 GALS MIN. 1200 PSI 1 OORPMS TOP OF WINDOW 4849 BOTTOM 4861 00:30 - 01 :30 1.00 CASE P COMP eiRe, WORK WINDOW, PUMP SWEEPS 01 :30 - 03:30 2.00 CASE P COMP TRIPPING OUT WITH MILLS 03:30 - 04:00 0.50 CASE P COMP LAYING DOWN BHA 04:00 - 04:30 0.50 CASE P COMP WASH OUT BOPS 04:30 - 06:30 2.00 CASE P COMP PICK UP BHA, 6.125 2643 PDC, 4 3/4 SPERRY DRILL 1.5 BEND MOTOR, FLOAT SUB, 4 3/4 GRAMMAIRES, 4 3/4 OM, HANG OFF SUB,3 FLEX COLLAR,JAR 06:30 - 08:30 2.00 CASE P COMP TRIP IN TO WINDOW, WENT THRU WINDOW NO PROBLEM 08:30 - 00:00 15.50 DRILL P PROD2 DIRECTIONAL DRILL 4861' TO 6559' WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000 AST 3.25, ART 6.25 CROSS FAULT @ 5820 8/28/2002 00:00 - 03:30 3.50 DRILL P PROD2 DIRECTIONAL DRILL 6559' TO 6909' WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000 , MUD WI. CUT TO 8.5 03:30 - 04:00 0.50 DRILL P PROD2 CIRC BOTTOMS, TO REMOVE CUTTING GAS MUD WENT 8.5 TO 9.0, RAISING MUD WT TO 9.6 04:00 - 04:30 0.50 DRILL P PROD2 DIRECTIONAL DRILL 6909' TO 6930 WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000, 04:30 - 05:00 0.50 DRILL P PROD2 CIRC. TILL WE GET 9.6 AROUND 05:00 - 00:00 19.00 DRILL P PROD2 DIRECTIONAL DRILL 6930 TO 8470' WITH 85 RPM 250 GALS PER MIN., 2600 PSI 5/10 BIT WT, TO 5,000, AST 7, ART 9.5 8/29/2002 00:00 - 04:30 4.50 DRILL P PROD2 DIRECTIONAL DRILL 8470' TO 9000' TO TVD 4042 WITH 85 RPM 250 GALS PER MIN., 2800 PSI 5/10 BITWT, TO 6,000 ART 3 04:30 - 07:30 3.00 DRILL P PROD2 CIRC, FOUR BOTTOMS UP WITH 3200 PSI WITH 280 GALS MIN 100 RPMS 07:30 - 10:30 3.00 CASE P COMP PUMP OUT TO WINDOW,@ 4849, DISPLACING HOLE WITH NEW 10# MUD 10:30 - 11 :30 1.00 CASE N DPRB COMP eiRe, AND RAISE MUD WT IN CSG TO 10# 11 :30 - 12:00 0.50 CASE N DPRB COMP MONITOR WELL, WELL FLOWING 12:00 - 15:00 3.00 CASE N DPRB COMP CIRC @ 4849 AND RAISE MUD WT TO 10.5 15:00 - 17:00 2.00 CASE N DPRB COMP TRIP BACK TO BOTTOM, TIGHT SPOTS FROM 8000 TO 8800 17:00 - 21 :00 4.00 CASE N DPRB COMP CIRC ON BOTTOM AND RAISE MUD WT TO 10.7, MONITOR WELL, STILL HAD SMALL FLOW, CIRC AND RAISE MUD WT. TO 10.8+ 21 :00 - 00:00 3.00 CASE N DPRB COMP PUMPING OUT TO WINDOW,@ 4849 8/30/2002 00:00 - 00:30 0.50 CASE N DPRB COMP PUMPING OUT TO WINDOW,@ 4849 00:30 - 01 :00 0.50 CASE N DPRB COMP MONITOR WELL, WELL DEAD 01 :00 - 03:00 2.00 CASE P COMP TRIPPING OUT 03:00 - 04:00 1.00 CASE P COMP LAYING DOWN BHA 04:00 - 05:30 1.50 CASE P COMP PICKING UP BHA,#8 WHIPSTOCK HOOK, Printed: 9/4/2002 10:53:07 AM ') ) Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Date From'" To Hours .,Task COdè NPT DesÞriþtion.of. ()þ~ratiöm) 8/30/2002 04:00 - 05:30 1.50 CASE P COMP 1 HWP,MWD,BUMPER SUB,JAR, 12 DC,15 HWP 05:30 - 06:30 1.00 CASE P COMP TRIP IN TO TOP OF WHIPSTOCK 06:30 - 07:00 0.50 CASE P COMP LATCH AND PULL WHIPSTOCK FREE 07:00 - 09:00 2.00 CASE P COMP eiRe, CHECK FOR GAS CUT MUD, NONE 09:00 - 11 :30 2.50 CASE N DPRB COMP TRY TO PULL WHIPSTOCK WITH OUT SWABBING IN WELL, HOLE NOT TAKING PROPER MUD 11 :30 - 12:30 1.00 CASE N DPRB COMP TRIP BACK TO 4759 12:30 - 13:00 0.50 CASE N DPRB COMP eiRe, AND WORKING PIPE TRYING TO WEAR OUT RUBBER CUP SEAL ON WHIPSTOCK 13:00 - 16:30 3.50 CASE P COMP TRIPPING OUT WITH WHIPSTOCK, SLOW 16:30 - 18:00 1.50 CASE P COMP BHAAND LAY DOWN WHIPSTOCK 18:00 - 19:30 1.50 CASE N DPRB COMP TRIP BACK IN WITH DC AND DRILL PIPE TO 4788 19:30 - 20:30 1.00 CASE N DPRB COMP CIRC AND CHECK FOR GAS CUT MUD, NONE 20:30 - 21 :30 1.00 CASE N DPRB COMP TRIPPING OUT, HOLE TAKING PROPER AMOUNT OF MUD 21 :30 - 23:00 1.50 CASE P COMP LAYING DOWN BHA 23:00 - 23:30 0.50 CASE P COMP RIG UP TO RUN 4.512.6# L-80 IBT SLOTTED LINER, PJSM 23:30 - 00:00 0.50 CASE P COMP PICKING UP, 4.5 12.6# L-80 IBT SLOTTED LINER 8/31/2002 00:00 - 02:30 2.50 CASE P COMP PICKING UP, 4.512.6# L-80 IBT SLOTTED LINER, TOTAL 104 JTS, 4093 FT 02:30 - 04:30 2.00 CASE P COMP TRIPPING IN WITH LINER, WENT IN WINDOW NO PROBLEM SHOE @ 8964.66 DOWN WT 60,000 PICKUP WT 110,000 TOP LINER 4839 04:30 - 05:00 0.50 CASE P COMP DROP BALL AND RELEASE FROM LINER WITH 2500 PSI, SHEAR BALL WITH 3500 PSI 05:00 - 05:30 0.50 CASE P COMP CIRC BOTTOMS UP 05:30 - 06:00 0.50 CASE P COMP MONITOR WELL 06:00 - 07:00 1.00 CASE P COMP CUT DRILLING LINE 07:00 - 10:30 3.50 CASE P COMP LAY DOWN EXCESS 3.5 DRILL PIPE 10:30 - 15:00 4.50 CASE P COMP PULL WEAR RING, TEST BOPS TO 250-4000 PSI FOR 5 MIN. ANNULAR 250-2500 PSI FOR 5 MIN. AND ALL VALVES 250-4000 PSI, NO FAILURES, THE RIGHT TO WITNESS TEST WAS WAIVED BY LOU GRIMALDI AOOGC 15:00 - 16:00 1.00 CASE P COMP FLUSH ALL MUD LINES AND PUMPS WITH WATER, SERVICE TOP DRIVE 16:00 - 18:00 2.00 CASE P COMP TRIP IN HOLE WITH MULE SHOE AND 3.5 DRILL PIPE TO 4800 FT 18:00 - 20:00 2.00 CASE P COMP CIRC AND DISPLACE WELL TO 11.0 NABR. PUMPED 100 BBLS NABR. FOLLOWED BY 30 BBLS 11.0 SPACER, FOLLOW BY 11.0 NABR. WHEN WE GOT SPACER AND CLEAN NABR. BACK ,SHUT DOWN. 20:00 - 00:00 4.00 CASE P COMP RIG UP FILTRATION UNIT, CIRC, FILTER BRINE TO 33 NTU 9/1/2002 00:00 - 03:00 3.00 CASE P COMP LAYING DOWN 3.5 DRILL PIPE 03:00 - 05:00 2.00 CASE P CaMP PULL WEAR RING AND INSTALL TEST PLUG, CHANGE TOP RAMS TO 2 7/8 AND TEST TO 4,000 05:00 - 11 :00 6.00 RUNCOM=> COMP RIGGING UP TO RUN 2 7/8 TUBING AND ESP COMPLETION PICK UP CENTRILlFT MOTOR AND PUMPS 165 HP KME-1 2230 VOLTS 11 :00 - 17:00 6.00 RUNCOM=> COMP PICKING UP TUBING AND PUMPS SET @ 4262, XN NIPPLE 4147,GLM 2821,GLM 168, TOTAL 131 JTS 17:00 - 19:30 2.50 RUNCOM=> COMP PICK UP HANGER, AND TIE IN ESP LINE TO HANGER Printed: 9/4/2002 10:53:07 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/1/2002 19:30 - 20:00 20:00 - 22:00 22:00 - 23:30 23:30 - 00:00 MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Hours ',' ,.,'.TáSk Code NPT Phase 0.50 RUNCOIVP LAY DOWN LANDING JT., TEST TWO WAY CHECK TO 1000 PSI CHANGE RAMS IN BOPS, NIPPLE DOWN NIPPLE UP, CIW 29/165,000# TREE AND TEST TO 5,000 PSI PULL TO WAY CHECK WITH DRY ROD AND INSTALL BACK PRESURE VALVE, SECURE TREE, RELEASE RIG FOR RIG MOVE @ 2400 HRS 9/1/2002 COMP 2.00 RUNCOIVP 1.50 RUNCOIVP COMP COMP 0.50 RUNCOIVP COMP Printed: 9f4f2002 10:53:07 AM ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 4,777.56' MD Window / Kickoff Survey 4,849.00 I MD (if applicable) Projected Survey: 9,000.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) ðÔd~ 15~ 30-Sep-02 OCT C 2 :~::"'.. '..'10 Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPI MPI-15L 1 ~ Job No. AKZZ22136, Surveyed: 29 August, 2002 Survey Report 26 September, 2002 Your Ref: API 500292310660 Surface Coordinates: 6009441.71 N, 551729.59 E (70026' 11.5455" N, 149034'41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '-" Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62.50ft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevation relative to Structure Reference: 62.50ft 5,.,pa""'''''Y~5U'' fn:{TL.-Cl"l\n:~f:=~'5rÊ 'Ft,'YJc; e,~ A Halliburton Company Survey Ref: svy10174 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L1 Your Ref: AP/500292310660 Job No. AKZZ22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 4777.56 71.160 114.310 3883.49 3945.99 1266.768 1915.33 E 6008188.27 N 553653.66 E 1760.13 Tie On Point 4849.00 72.340 113.840 3905.86 3968.36 - 1294.438 1977.27 E 6008161.02 N 553715.79 E 1.766 1818.55 Window Point 4865.82 74.350 113.840 3910.68 3973.18 1300.95 8 1992.01 E 6008154.61 N 553730.57 E 11.950 1832.46 4910.40 81.220 113.840 3920.11 3982.61 1318.558 2031.84 E 6008137.29 N 553770.52 E 15.410 1870.05 4961.88 89.570 113.850 3924.24 3986.74 1339.278 2078.73 E 6008116.89 N 553817.56 E 16.220 1914.30 .~ 5003.46 90.120 113.850 3924.35 3986.85 1356.09 S 2116.76 E 6008100.34 N 553855.70 E 1.323 1950.19 5053.90 88.210 113.860 3925.09 3987.59 1376.48 S 2162.88 E 6008080.26 N 553901.97 E 3.787 1993.72 5097.54 87.850 113.880 3926.59 3989.09 1394.138 2202.77 E 6008062.89 N 553941.97 E 0.826 2031.36 5147.36 88.950 106.170 3927.98 3990.48 1411.178 2249.52 E 6008046.18 N 553988.84 E 15.626 2075.89 5190.77 86.180 105.150 3929.82 3992.32 1422.88 S 2291.28 E 6008034.76 N 554030.68 E 6.799 2116.06 5239.68 86.240 105.600 3933.06 3995.56 1435.828 2338.33 E 6008022.15 N 554077.83 E 0.926 2161.35 5284.07 87.420 105.530 3935.51 3998.01 1447.71 S 2381.03 E 6008010.55 N 554120.60 E 2.663 2202.43 5330.99 87.350 105.980 3937.65 4000.15 1460.448 2426.14 E 6007998.14 N 554165.80 E 0.970 2245.82 5379.06 86.060 105.630 3940.41 4002.91 1473.51 8 2472.31 E 6007985.39 N 554212.06 E 2.780 2290.22 5427.44 86.980 105.350 3943.35 4005.85 1486.408 2518.85 E 6007972.81 N 554258.69 E 1.987 2335.01 5471.97 87.100 105.760 3945.65 4008.15 1498.33 S 2561.69 E 6007961.19 N 554301.61 E 0.958 2376.23 5524.77 87.100 106.100 3948.32 4010.82 1512.808 2612.40 E 6007947.07 N 554352.42 E 0.643 2424.98 5565.45 87.230 106.070 3950.33 4012.83 1524.06 8 2651.44 E 6007936.08 N 554391.54 E 0.328 2462.50 5614.73 89.380 107.790 3951.79 4014.29 1538.40 8 2698.56 E 6007922.06 N 554438.75 E 5.586 2507.70 5659.31 88.890 107.880 3952.46 4014.96 1552.05 8 2740.99 E 6007908.71 N 554481.28 E 1.118 2548.32 5707.78 89.820 109.020 3953.01 4015.51 1567.398 2786.96 E 6007893.69 N 554527.36 E 3.035 2592.27 5751.32 89.450 108.200 3953.29 4015.79 1581.298 2828.23 E 6007880.08 N 554568.72 E 2.066 2631.70 5799.80 92.090 106.150 3952.64 4015.14 1595.608 2874.53 E 6007866.09 N 554615.12 E 6.894 2676.10 ~ 5843.77 88.460 100.710 3952.42 4014.92 1605.81 8 2917.28 E 6007856.18 N 554657.94 E 14.872 2717.41 5892.72 88.650 98.900 3953.66 4016.16 1614.148 2965.50 E 6007848.18 N 554706.21 E 3.717 2764.38 5935.77 86.860 97.750 3955.35 4017.85 1620.378 3008.06 E 6007842.25 N 554748.81 E 4.941 2805.97 5985.02 86.550 96.050 3958.18 4020.68 1626.27 8 3056.87 E 6007836.68 N 554797.66 E 3.503 2853.80 6028.99 88.950 93.720 3959.90 4022.40 1630.01 8 3100.64 E 6007833.24 N 554841.46 E 7.604 2896.87 6078.76 88.710 89.200 3960.92 4023.42 1631.288 3150.37 E 6007832.32 N 554891.20 E 9.093 2946.14 6121.66 87.350 87.580 3962.39 4024.89 1630.088 3193.22 E 6007833.82 N 554934.04 E 4.929 2988.86 6171.12 92.090 91.740 3962.64 4025.14 1629.788 3242.66 E 6007834.46 N 554983.47 E 12.749 3038.01 6214.62 93.080 91 .250 3960.67 4023.17 1630.92 8 3286.10 E 6007833.62 N 555026.92 E 2.539 3081.04 6264.47 93.140 89.930 3957.97 4020.47 1631.43S 3335.87 E 6007833.46 N 555076.70 E 2.647 3130.44 6308.31 92.340 84.590 3955.87 4018.37 1629.34 8 3379.59 E 6007835.85 N 555120.40 E 12.303 3174.12 6356.15 92.460 81 .720 3953.87 4016.37 1623.64 S 3427.05 E 6007841.88 N 555167.82 E 5.999 3221.91 26 September, 2002 - 9:41 Page2of5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L 1 Your Ref: API 500292310660 Job No. AKZZ22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6398.99 93.820 80.710 3951.52 4014.02 1617.11 S 3469.32 E 6007848.70 N 555210.04 E 3.952 3264.65 6446.29 93.200 75.750 3948.62 4011.12 1607.48 S 3515.52 E 6007858.65 N 555256.18 E 10.548 3311.65 6491.28 91.480 73.940 3946.79 4009.29 1595.73 S 3558.91 E 6007870.70 N 555299.48 E 5.547 3356.08 6542.56 91.290 74.090 3945.55 4008.05 1581.61 S 3608.19 E 6007885.16 N 555348.66 E 0.472 3406.64 6583.65 87.170 70.040 3946.10 4008.60 1568.97 S 3647.26 E 6007898.08 N 555387.65 E 14.058 3446.89 ~ 6633.35 80.780 67.870 3951.31 4013.81 1551 .23 S 3693.37 E 6007916.13 N 555433.63 E 13.570 3494.71 6676.11 85.620 67.280 3956.38 4018.88 1535.04 S 3732.60 E 6007932.60 N 555472.75 E 11 .402 3535.52 6726.58 87.540 67.880 3959.39 4021.89 1515.83 S 3779.17 E 6007952.13 N 555519.19 E 3.985 3583.96 6769.64 89.320 63.250 3960.57 4023.07 1498.02 S 3818.35 E 6007970.21 N 555558.24 E 11.516 3624.89 6819.77 89.140 59.390 3961.24 4023.74 1473.97 S 3862.32 E 6007994.56 N 555602.04 E 7.708 3671.29 6862.32 89.510 59.510 3961.74 4024.24 1452.35 S 3898.96 E 6008016.44 N 555638.53 E 0.914 3710.14 6912.70 89.880 60.030 3962.01 4024.51 1426.98 S 3942.49 E 6008042.11 N 555681.88 E 1.267 3756.25 6956.52 90.120 55.410 3962.01 4024.51 1403.59 S 3979.52 E 6008065.76 N 555718.75 E 10.557 3795.70 7008.86 89.750 51.210 3962.07 4024.57 1372.32 S 4021.48 E 6008097.32 N 555760.50 E 8.056 3840.92 7049.04 89.750 51 .480 3962.25 4024.75 1347.22 S 4052.86 E 6008122.63 N 555791.70 E 0.672 3874.93 7099.63 86.860 48.420 3963.74 4026.24 1314.69 S 4091.56 E 6008155.43 N 555830.17 E 8.317 3917.05 7143.19 86.800 48.040 3966.15 4028.65 1285.72 S 4124.00 E 6008184.62 N 555862.41 E 0.882 3952.55 7192.30 89.380 45.220 3967.79 4030.29 1252.02 S 4159.67 E 6008218.57 N 555897.85 E 7.780 3991.80 7236.12 87.170 43.130 3969.11 4031.61 1220.61 S 4190.19 E 6008250.19 N 555928.15 E 6.940 4025.67 7284.65 89.570 39.570 3970.49 4032.99 1184.20 S 4222.23 E 6008286.82 N 555959.93 E 8.844 4061.61 7329.19 89.690 34.500 3970.78 4033.28 1148.66 S 4249.05 E 6008322.55 N 555986.50 E 11.386 4092.27 7377.90 87.910 33.300 3971.80 4034.30 1108.24 S 4276.21 E 6008363.16 N 556013.38 E 4.407 4123.82 7422.43 89.880 29.450 3972.65 4035.15 1070.24 S 4299.38 E 6008401.32 N 556036.29 E 9.710 4151.13 '~' 7470.68 90.060 29.060 3972.68 4035.18 1028.14 S 4322.96 E 6008443.58 N 556059.58 E 0.890 4179.31 7514.66 92.220 23.570 3971.80 4034.30 988.75 S 4342.45 E 6008483.11 N 556078.79 E 13.411 4203.12 7564.25 88.770 18.750 3971.38 4033.88 942.52 S 4360.34 E 6008529.45 N 556096.36 E 11.951 4226.11 7608.43 86.860 16.630 3973.06 4035.56 900.47 S 4373.75 E 6008571.60 N 556109.48 E 6.456 4244.19 7657.59 88.340 16.430 3975.12 4037.62 853.38 S 4387.73 E 6008618.78 N 556123.13 E 3.038 4263.39 7700.79 90.250 15.470 3975.65 4038.15 811.85 S 4399.60 E 6008660.40 N 556134.71 E 4.948 4279.87 7750.13 89.020 12.230 3975.96 4038.46 763.95 S 4411.41 E 6008708.37 N 556146.19 E 7.024 4297.01 7792.86 87.290 6.890 3977.34 4039.84 721.85 S 4418.50 E 6008750.52 N 556152.99 E 13.130 4308.80 7842.46 88.220 3.980 3979.28 4041.78 672.52 S 4423.19 E 6008799.88 N 556157.34 E 6.155 4319.03 7885.65 88.340 3.340 3980.58 4043.08 629.44 S 4425.95 E 6008842.99 N 556159.80 E 1.507 4326.63 7934.25 89.260 357.790 3981.60 4044.10 580.87 S 4426.43 E 6008891.55 N 556159.94 E 11.573 4332.59 7979.55 91.170 356.000 3981.43 4043.93 535.64 S 4423.97 E 6008936.77 N 556157.17 E 5.778 4335.26 26 September, 2002 - 9:41 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L 1 Your Ref: API 500292310660 Job No. AKZZ22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8028.84 92.090 356.780 3980.03 4042.53 486.47 S 4420.87 E 6008985.91 N 556153.73 E 2.447 4337.73 8072.20 92.090 357.250 3978.45 4040.95 443.20 S 4418.61 E 6009029.17 N 556151.17 E 1.083 4340.37 8121.87 90.490 355.870 3977.33 4039.83 393.63 S 4415.63 E 6009078.71 N 556147.85 E 4.253 4343.00 8166.66 88.770 355.480 3977.62 4040.12 348.97 S 4412.26 E 6009123.35 N 556144.16 E 3.938 4344.68 8215.46 91.230 355.860 3977.62 4040.12 300.32 S 4408.57 E 6009171.98 N 556140.14 E 5.101 4346.51 ~. 8259.35 91.850 355.640 3976.44 4038.94 256.56 S 4405.32 E 6009215.71 N 556136.58 E 1 .499 4348.22 8308.51 90.310 354.250 3975.51 4038.01 207.61 S 4400.99 E 6009264.63 N 556131.91 E 4.220 4349.44 8351.87 90.180 353.690 3975.33 4037.83 164.49 S 4396.44 E 6009307.72 N 556127.06 E 1.326 4349.78 8401.08 89.940 352.910 3975.27 4037.77 115.61 S 4390.69 E 6009356.55 N 556120.98 E 1.658 4349.60 8444.72 88.710 350.890 3975.79 4038.29 72.41 S 4384.55 E 6009399.71 N 556114.53 E 5.419 4348.36 8494.88 89.010 350.600 3976.79 4039.29 22.92 S 4376.48 E 6009449.15 N 556106.12 E 0.832 4345.93 8536.94 89.320 349.400 3977.40 4039.90 18.50 N 4369.18 E 6009490.51 N 556098.53 E 2.946 4343.35 8588.11 89.200 349.360 3978.06 4040.56 68.79 N 4359.75 E 6009540.74 N 556088.76 E 0.247 4339.66 8630.23 89.630 350.090 3978.49 4040.99 110.23 N 4352.24 E 6009582.12 N 556080.96 E 2.011 4336.87 8680.91 89.510 350.870 3978.87 4041.37 160.21 N 4343.85 E 6009632.05 N 556072.23 E 1.557 4334.18 8723.11 89.080 350.090 3979.39 4041.89 201.83 N 4336.87 E 6009673.61 N 556064.96 E 2.110 4331.95 8772.57 89.570 350.730 3979.97 4042.47 250.59 N 4328.64 E 6009722.32 N 556056.38 E 1.630 4329.26 8815.65 90.180 350.410 3980.07 4042.57 293.09 N 4321.58 E 6009764.77 N 556049.03 E 1.599 4327.04 8864.49 89.750 351 .160 3980.10 4042.60 341.30 N 4313.76 E 6009812.92 N 556040.88 E 1.770 4324.71 8908.90 90.860 351.740 3979.86 4042.36 385.21 N 4307.15 E 6009856.79 N 556033.97 E 2.820 4323.11 8932.84 90.180 351.390 3979.64 4042.14 408.89 N 4303.64 E 6009880.44 N 556030.29 E 3.195 4322.29 9000.00 90.180 351.390 3979.43 4041.93 475.29 N 4293.59 E 6009946.77 N 556019.78 E 0.000 4319.80 Projected Survey ~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.520° (True). Magnetic Declination at Surface is 25.733°(15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9000.00ft., The Bottom Hole Displacement is 4319.82ft., in the Direction of 83.683° (True). 26 September, 2002 - 9:41 Page 4 of 5 DrillQuest 3.03.02.002 Milne Point Unit Comments Measured Depth (ft) 4777.56 4849.00 9000.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MP/-15L1 Your Ref: AP/500292310660 Job No. AKZZ22136, Surveyed: 29 August, 2002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3945.99 3968.36 4041.93 1266.76 S 1294.43 S 475.29 N Survey tool program for MPI-15L 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 172.00 26 September, 2002 - 9:41 0.00 172.00 To Measured Vertical Depth Depth (ft) (ft) 172.00 9000.00 Comment 1915.33 E 1977.27 E 4293.59 E Tie On Point Window Point Projected Survey ~' Survey Tool Description 172.00 Tolerable Gyro(MPI-15 PB1) 4041.93 AK-6 BP _IFR-AK(MPI-15 PB1) ~ Page 5 of 5 DrillQuest 3.03.02.002 ~ò~-/53 ) 30-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15L 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 4,777.56' MD Window / Kickoff Survey 4,849.00' MD (if applicable) Projected Survey: 9,000.OQ'MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) OCT C :-, L,:~ lV) \() -- \ , ~ Sperry-Sun Drilling Services - Milne Point Unit BPXA Milne Point MPI MPI-15L 1MWD Job No. AKMW22136, Surveyed: 29 August, 2002 Survey Report 26 September, 2002 ,- Your Ref: API 500292310660 Surface Coordinates: 6009441.71 N, 551729.59 E (70026' 11.5455" N, 149034'41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62.50ft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevation relative to Structure Reference: 62.50ft !fIpeIr'raY"8UI! OÞtILLING slàAvlt:es A Halliburton Company Survey Ref: 5vy10191 Sperry-Sun Drilling Services Survey Report for Milne Point MPI * MPI*15L 1 MWD Your Ref: API 500292310660 Job No. AKMW22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4777.56 71.160 111 .680 3883.53 3946.03 1266.86 S 1912.76 E 6008188.15 N 553651.09 E 1757.56 Tie On Point 4849.00 72.340 113.840 3905.91 3968.41 1293.11 5 1975.31 E 6008162.33 N 553713.83 E 3.313 1816.76 Window Point 4865.82 74.350 290.550 3918.44 3980.94 1294.145 1974.66 E 6008161.30 N 553713.17 E 871.180 1815.99 4910.40 81.220 298.150 3927.88 3990.38 1276.175 1935.03 E 6008178.99 N 553673.43 E 22.687 1778.65 .-- 4961.88 89.570 101.170 3945.20 4007.70 1246.705 1946.89 E 6008208.55 N 553685.08 E 312.236 1793.75 5003.46 90.120 117.640 3945.32 4007.82 1260.465 1985.97 E 6008195.05 N 553724.26 E 39.632 1831.03 5053.90 88.210 114.740 3946.05 4008.55 1282.725 2031.22 E 6008173.11 N 553769.66 E 6.884 1873.48 5097.54 87.850 113.710 3947.55 4010.05 1300.61 5 2071.00 E 6008155.49 N 553809.56 E 2.499 1910.98 5147.36 88.950 106.000 3948.94 4011.44 1317.51 5 2117.80 E 6008138.92 N 553856.48 E 15.626 1955.58 5190.77 86.180 105.040 3950.79 4013.29 1329.125 2159.58 E 6008127.60 N 553898.34 E 6.753 1995.79 5239.68 86.240 105.250 3954.02 4016.52 1341.875 2206.69 E 6008115.18 N 553945.54 E 0.446 2041 .16 5284.07 87.420 105.530 3956.48 4018.98 1353.63 5 2249.42 E 6008103.71 N 553988.35 E 2.732 2082.29 5330.99 87.350 105.780 3958.62 4021.12 1366.28 S 2294.56 E 6008091.38 N 554033.57 E 0.553 2125.70 5379.06 86.060 105.620 3961.38 4023.88 1379.275 2340.76 E 6008078.71 N 554079.86 E 2.704 2170.14 5427.44 86.980 105.150 3964.32 4026.82 1392.08 5 2387.32 E 6008066.23 N 554126.50 E 2.135 2214.96 5471.97 87.100 105.840 3966.62 4029.12 1403.965 2430.17 E 6008054.64 N 554169.44 E 1.571 2256.20 5524.77 87.100 105.870 3969,29 4031.79 1418.365 2480.90 E 6008040.59 N 554220.26 E 0.057 2304.97 5565.45 87.230 105.770 3971.30 4033.80 1429.445 2519.99 E 6008029.78 N 554259.43 E 0.403 2342.57 5614.73 89.380 107.910 3972.76 4035.26 1443.71 S 2567.13 E 6008015.84 N 554306.67 E 6.154 2387.79 5659.31 88.890 108.110 3973.43 4035.93 1457.495 2609.52 E 6008002.35 N 554349.15 E 1.187 2428.36 5707.78 89.820 109.240 3973.97 4036.47 1473.01 5 2655.43 E 6007987.15 N 554395.17 E 3.019 2472.23 /-. 5751.32 89.450 108.300 3974.25 4036.75 1487.025 2696.65 E 6007973.43 N 554436.49 E 2.320 2511.61 5799.80 92.090 106.330 3973.60 4036.10 1501.445 2742.93 E 6007959.33 N 554482.87 E 6.794 2555.96 5843.77 88.460 101.050 3973.39 4035.89 1511.85S 2785.63 E 6007949.22 N 554525.63 E 14.571 2597.21 5892.72 88.650 99.050 3974.62 4037.12 1520.38 5 2833.81 E 6007941.02 N 554573.87 E 4.103 2644.12 5935.77 86.860 97.880 3976.31 4038.81 1526.725 2876.35 E 6007934.98 N 554616.46 E 4.966 2685.68 5985.02 86.550 96.140 3979.14 4041.64 1532.725 2925.15 E 6007929.32 N 554665.30 E 3.583 2733.49 6028.99 88.950 93.810 3980.87 4043.37 15:36.53 5 2968.92 E 6007925.81 N 554709.09 E 7.604 2776.54 6078.76 88.710 89.300 3981.88 4044.38 1537.88 S 3018.64 E 6007924.81 N 554758.83 E 9.073 2825.80 6121.66 87.350 87.690 3983.36 4045.86 1536.75 S 3061.50 E 6007926.23 N 554801.68 E 4.911 2868.51 6171.12 92.090 91.890 3983.60 4046.10 15:36.57 S 3110.94 E 6007926.76 N 554851.11 E 12.803 2917.65 6214.62 93.080 91.420 3981.64 4044.14 1537.825 3154.37 E 6007925.80 N 554894.55 E 2.519 2960.67 6264.47 93.140 89.960 3978.93 4041.43 15:38.425 3204.14 E 6007925.55 N 554944.33 E 2.927 3010.05 6308.31 92.340 84.660 3976.84 4039.34 1536.37 S 3247.87 E 6007927.91 N 554988.04 E 12.213 3053.73 6356.15 92.460 81.860 3974.83 4037.33 1530.76 S 3295.33 E 6007933.84 N 555035.46 E 5.853 3101.52 -~_.._._~-----._---~------ 26 September, 2002 - 10:11 Page 20f5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L 1 MWD Your Ref: API 500292310660 Job No. AKMW22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6398.99 93.820 80.810 3972.49 4034.99 1524.32 S 3337.62 E 6007940.58 N 555077.70 E 4.008 3144.27 6446.29 93.200 75.850 3969.59 4032.09 1514.77 S 3383.84 E 6007950.45 N 555123.85 E 10.548 3191.27 6491.28 91.480 74.170 3967.75 4030.25 1503.14 S 3427.26 E 6007962.38 N 555167.19 E 5.342 3235.72 6542.56 91.290 74.280 3966.51 4029.01 1489.21 S 3476.59 E 6007976.65 N 555216.43 E 0.428 3286.32 6583.65 87.170 70.330 3967.07 4029.57 1476.72 S 3515.72 E 6007989.41 N 555255.47 E 13.888 3326.60 ~ 6633.35 80.780 68.080 3972.28 4034.78 1459.19 S 3561.90 E 6008007.26 N 555301.53 E 13.622 3374.47 6676.11 85.620 67.410 3977.34 4039.84 1443.11 S 3601.18 E 6008023.61 N 555340.70 E 11.425 3415.31 6726.58 87.540 67.940 3980.35 4042.85 1423.98 S 3647.79 E 6008043.07 N 555387.16 E 3.946 3463.78 6769.64 89.320 63.310 3981.53 4044.03 1406.22 S 3686.98 E 6008061.10 N 555426.23 E 11.516 3504.72 6819.77 89.140 59.390 3982.21 4044.71 1382.19 S 3730.96 E 6008085.43 N 555470.05 E 7.827 3551.13 6862.32 89.510 59.550 3982.71 4045.21 1360.58 S 3767.61 E 6008107.30 N 555506.54 E 0.947 3589.99 6912.70 89.880 59.990 3982.98 4045.48 1335.21 S 3811.14 E 6008132.96 N 555549.90 E 1.141 3636.10 6956.52 90.120 55.400 3982.98 4045.48 1311.80 S 3848.16 E 6008156.63 N 555586.76 E 10.489 3675.53 7008.86 89.750 50.970 3983.04 4045.54 1280.44 S 3890.06 E 6008188.28 N 555628.43 E 8.493 3720.70 7049.04 89.750 51.270 3983.21 4045.71 1255.22 S 3921.33 E 6008213.72 N 555659.54 E 0.747 3754.62 7099.63 86.860 48.250 3984.71 4047.21 1222.57 S 3959.93 E 6008246.64 N 555697.90 E 8.260 3796.65 7143.19 86.800 47.790 3987.12 4049.62 1193.47 S 3992.26 E 6008275.96 N 555730.03 E 1.063 3832.06 7192.30 89.380 44.980 3988.75 4051.25 1159.62 S 4027.79 E 6008310.05 N 555765.32 E 7.765 3871.18 7236.12 87.170 42.920 3990.07 4052.57 1128.09 S 4058.18 E 6008341.79 N 555795.50 E 6.893 3904.94 7284.65 89.570 39.600 3991.45 4053.95 1091.63 S 4090.17 E 6008378.47 N 555827.23 E 8.439 3940.84 7329.19 89.690 34.450 3991.74 4054.24 1056.09 S 4116.98 E 6008414.21 N 555853.79 E 11.566 3971.49 7377.90 87.910 33.290 3992.76 4055.26 1015.65 S 4144.12 E 6008454.83 N 555880.65 E 4.361 4003.02 /~ 7422.43 89.880 29.370 3993.62 4056.12 977.63 S 4167.26 E 6008493.01 N 555903.53 E 9.850 4030.30 7470.68 90.060 28.990 3993.64 4056.14 935.51 S 4190.78 E 6008535.29 N 555926.76 E 0.871 4058.43 7514.66 92.220 23.670 3992.77 4055.27 896.11 S 4210.28 E 6008574.82 N 555945.98 E 13.053 4082.25 7564.25 88.770 18.830 3992.34 4054.84 849.92 S 4228.24 E 6008621.14 N 555963.63 E 11 .984 4105.31 7608.43 86.860 16.720 3994.03 4056.53 807.88 S 4241.72 E 6008663.27 N 555976.81 E 6.439 4123.45 7657.59 88.340 16.300 3996.08 4058.58 760.79 S 4255.68 E 6008710.46 N 555990.44 E 3.129 4142.63 7700.79 90.250 15.390 3996.62 4059.12 719.24 S 4267.47 E 6008752.09 N 556001.95 E 4.897 4159.04 7750.13 89.020 12.250 3996.93 4059.43 671.33 S 4279.26 E 6008800.07 N 556013.40 E 6.835 4176.15 7792.86 87.290 7.010 3998.31 4060.81 629.24 S 4286.40 E 6008842.21 N 556020.25 E 12.908 4188.00 7842.46 88.220 4.090 4000.25 4062.75 579.92 S 4291.19 E 6008891.57 N 556024.70 E 6.174 4198.33 7885.65 88.340 3.440 4001.55 4064.05 536.84 S 4294.03 E 6008934.66 N 556027.24 E 1.530 4206.01 7934.25 89.260 357.880 4002.56 4065.06 488.28 S 4294.58 E 6008983.23 N 556027.46 E 11.593 4212.04 7979.55 91.170 356.120 4002.39 4064.89 443.04 S 4292.21 E 6009028.45 N 556024.77 E 5.733 4214.79 . _.__..-<--------------~-_._- 26 September, 2002 - 10:11 Page 3 of5 DrillQLlest 3.03.02.002 . Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L 1 MWD Your Ref: API 500292310660 Job No. AKMW22136, Surveyed: 29 August, 2002 BPXA Milne Point Unit Measured Sub.Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8028.84 92.090 356.890 4000.99 4063.49 393.87 S 4289.21 E 6009077.60 N 556021.43 E 2.434 4217.36 8072.20 92.090 357.330 3999.41 4061.91 350.59 S 4281.03 E 6009120.86 N 556018.94 E 1.014 4220.07 8121.87 90.490 355.970 3998.29 4060.79 301.02 S 4284.12 E 6009170.41 N 556015.70 E 4.227 4222.78 8166.66 88.770 355.530 3998.58 4061.08 256.36 S 4280.80 E 6009215.05 N 556012.07 E 3.964 4224.52 8215.46 91.230 355.910 3998.58 4061.08 207.70 S 4277.16 E 6009263.69 N 556008.09 E 5.101 4226.40 ~. 8259.35 91.850 355.740 3997.40 4059.90 163.94 S 4273.97 E 6009307.42 N 556004.59 E 1.465 4228.16 8308.51 90.310 354.360 3996.48 4058.98 114.97 S 4269.73 E 6009356.36 N 556000.01 E 4.206 4229.47 8351.87 90.180 353.770 3996.29 4058.79 71.85 S 4265.24 E 6009399.45 N 555995.23 E 1.393 4229.89 8401.08 89.940 353.010 3996.24 4058.74 22.96 S 4259.58 E 6009448.29 N 555989.23 E 1.620 4229.78 8444.72 88.710 351.100 3996.75 4059.25 20.25 N 4253.55 E 6009491.46 N 555982.90 E 5.205 4228.66 8494.88 89.010 350.760 3997.75 4060.25 69.77 N 4245.64 E 6009540.93 N 555974.65 E 0.904 4226.39 8536.94 89.320 349.560 3998.36 4060.86 111.21 N 4238.46 E 6009582.32 N 555967.17 E 2.946 4223.93 8588.11 89.200 349.510 3999.03 4061.53 161.53 N 4229.16 E 6009632.57 N 555957.53 E 0.254 4220.37 8630.23 89.630 350.260 3999.46 4061.96 202.99 N 4221.77 E 6009673.98 N 555949.85 E 2.052 4217.70 8680.91 89.510 350.960 3999.84 4062.34 252.99 N 4213.50 E 6009123.92 N 555941.23 E 1.401 4215.13 8723.11 89.080 350.260 4000.35 4062.85 294.62 N 4206.61 E 6009765.50 N 555934.06 E 1.947 4212.99 8772.57 89.570 350.950 4000.94 4063.44 343.41 N 4198.54 E 6009814.23 N 555925.65 E 1.711 4210.47 8815.65 90.180 350.600 4001.03 4063.53 385.93 N 4191.63 E 6009856.71 N 555918.45 E 1.632 4208.41 8864.49 89.750 351.170 4001.06 4063.56 434.16 N 4183.90 E 6009904.88 N 555910.37 E 1 .462 4206.16 8908.90 90.860 351.650 4000.82 4063.32 478.07 N 4177.26 E 6009948.14 N 555903.44 E 2.723 4204.53 8932.84 90.180 351.270 4000.61 4063.11 501.74 N 4113.71 E 6009972.39 N 555899.72 E 3.254 4203.67 9000.00 90.180 351.270 4000.40 4062.90 568.12 N 4163.52 E 6010038.10 N 555889.06 E 0.000 4201.03 Projected Survey /~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.5200 (True). Magnetic Declination at Surface is 25.733°(15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9000.00ft., The Bottom Hole Displacement is 4202.1 Oft., in the Direction of 82.230° (True). --.--..- ~-_.__._..---_.__.~._.. .----.-- 26 September, 2002 - 10:11 Page 4 of5 DrillQup.st 3.03.02.002 Milne Point Unit Comments Measured Depth (ft) /--- 4777.56 4849.00 9000.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15L1 MWD Your Ref: API 500292310660 Job No. AKMW22136, Surveyed: 29 August, 2002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3946.03 3968.41 4062.90 1266.86 S 1293.11 S 568.12 N Comment 1912.76 E 1975.31 E 4163.52 E Tie On Point Window Point Projected Survey Survey tool program for MPI-15L 1 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 172.00 0.00 172.00 26 September, 2002 - 10:11 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 172.00 9000.00 172.00 Tolerable Gyro(MPI-15 PB1 MWD) 4062.90 MWD Magnetic(MPI-15 PB1 MWD) --_.-_._~._--,-_..._-_.-.. -.--..,-_.__.-0 . Page 50f5 DrillQuest 3.03.02.002 ) ~i~1f TONY KNOWLES, GOVERNOR AI~ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7ft! AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99510 Re: Milne Point Unit MPI -15L 1 BP Exploration (Alaska), Inc. Permit No: 202-153 Surface Location: 2959 FNL, 3621 FEL, Sec. 33, T13N, R10E, UM Bottomhole Location: 2813' NSL, 4555' WEL, Sec. 34, T13N, RIOE, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The permit is for a new wellbore segment of existing well MPI-15, Permit No 202-152, API 50- 029-23106. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, G {lJwL~ ~~./ C~chsli Tayior1J' Chair BY ORDER OF THE COMMISSION DATED this M day of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~, :J.2J! WCl, SEC. 33, T13N, R10, E, UM (Approximate) .z.~:rto~ of þroâJátive ~t~ / '¡:-E ¿. ~ ~ 928' NSL, 1429' WEL, SEC. 33, T13N, R10E, UM At total depth 28131 NSL, 45551 WEL, SEC. 34, T13N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well / . ADL 380109,28131 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 48711 MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Hole CasinQ WeiQht Grade CouDlina 6-1/8" 4-1/2" 12.7# L-80 BTC " STATE OF ALASKA-, ALAS~,JIL AND GAS CONSERVATION COM~..ßSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 62.1' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 025906 7. Unit or Property Name Milne Point Unit 8. Well Number / MPI.15L 1 9. Approximate spud date 08/06/02 7 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 90731 MD / 4072' TVD 17. Anticipated pressure {se, 20 AAC 25.035 (e) (2)} 91 0 Maximum surface 1543 .psig, At total depth (TVD) 3934' / 1943 psig Setting Depth TQD Bot:om Qu~ntity of Cement Lenath MD TVD MD TVD (include staae data)..,/ 42011 48721 3993' 90731 40721 Uncemented Slotted Liner / iJ-f6A- 7/14/" L ~ 'lfu.1D'V 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9080 feet 4127 feet 9080 feet 4127 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 260 sx Arctic Set (Approx.) 112' 112' 559 sx Class 'L', 190 sx Class 'GI 3067' 2762' 172 sx Class 'G' 5100' 4057' 80' 3067' 5100' 20" 9-5/8" 7" Perforation depth: measured true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Matt Green, 564-5581 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Date 7 /" :) >~ / PI -., Signed Pat Archey fs 0-.. l1e ' Title Senior Drilling Engineer t' (., / G/ 0( :;'; "',' '~;,:. '.,~.l~;:.'t-",< :,~iî¡trt\~_i~0\;;¡;~ßl}~:;\:>:;: . ',', " . Permit Number API Number App~1A~te' See cover letter Co:;~~ of ~-;:!aI: Samp: ~~~ - ¿ 3/cJ~ ;e: ~ No Mud Log ~~;:~;2- fo~~~~ ,,;;u~~ments Hydrogen Sulfide Measures 0 Yes 0 No Directional Survey Required 13 Yes 0 No Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K 0 3.5K psi for CTU Other: T'é-s 1- E:J j> E t' tJ~OO r?Sl . Qnglnal Stgn~ Yf,,<, "''', by order of Approved By Cammy Qechsll Taytor !; ~°!nfn~~oP~J' l' I the commission Form 10-401 Rev. 12-01-85 V G " i L) II " li L 20. Attachments Date 7 ~tþ?ø,;;-- ~~t 1~~Plicate ) WeIlName: MPI-15L1 Drill and Complete Plan Summary 're Point MPI-15 Well Permit I Type of Well (service I producer I injector): I Multi Lateral Producer "OA" & "OB" I Surface Location: ~ FNL, (12821 FSL), ~EL, (1451 FWL), SEC. 33, T13N, R10E E=550245.83 N=6008388.01 Target Location: 4352' FNL, (9281 FSL), 1429' FEL, (38501 FWL), SEC. 33, T13N,R1 OE TOP "OA" E=553955.00 N=6008060.00 Z=4002' TVD Target Location: 2467' FNL, (28131 FSL), 4555' FEL, (7241 FWL), SEC. 34, T13N,R1 OE BHL "OA" Well TD E=556090.00 N=6009960.00 Z=4072' TVD Target Location: 4352' FNL, (9281 FSL), 1429' FEL, (38501 FWL), SEC. 33, T13N,R10E TOP "OB" E=553955.00 N=6008060.00 Z=4057' TVD Target Location: 2461' FNL, (2813' FSL), 4555' FEL, (7241 FWL), SEC. 34, T13N,R1 OE BHL "OB" Well TD E=556090.00 N=6009960.00 Z=4127' TVD I AFE Number: I MSD337294 I Rig: I Doyon 141/ I I Estimated Start Date: 16 Aug 2002 I Operating days to complete: 120.4 1 I MD: 19073 I I TVD: 14072 1 I Max Inc: 191 I I KOP: 14871/ I KBE: 162.1 I I Well Design (conventional, slimhole, etc.): 1 Conventional Grass Roots ML Producer I I I Objective: I Schrader OA Sand Mud Program: 12.25-in Surface Hole Mud Properties: Density (ppg) Funnel visc YP 8.6 - 9.0 75 - 150 25 - 60 HTHP N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 6.5 9.875-in Intermediate Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 9.0 - 9.3 75 - 150 25 - 60 N/A LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 6.5 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density (ppg) funnel visc YP HTHP pH API Filtrate LG Solids 8.6-9.3 / 40-55 22-27 <10 8.0-8.5 4-6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 Cement Program: ') re Point MPI-15 Well Permit Casin~ Size 19.625-in 47-lb/ft L-80 BTC Surface Casing Basis 1250% excess over gauge hole in permafrost interval 40% excess over gauge hole below permafrost Total Cement Wash 50 bbl t Volume: 453-bbl - wa er Spacer Lead Tail Temp \ 50-bbl Viscosified Spacer (Alpha) weighted to 10.5-lb/gal 559-sx (414-bbl) 10.7 Ib/gal Class L - 4.15 cuft/sx (cement to surface) 190-sx (39-bbl) 15.8 Ib/gal Prem G - 1.15 cuft/sx (top of tail at BHST ~ 80°F from SOR, BHCT 85°F estimated by Halliburton Casing Size l.O-in 26-lb/ft L-80 BTC Intermediate Casing Basis 140% excess over gauge hole. Tail 500-ft MD above top of N-sand. Total Cement Volume: 35-bbl Wash 50-bbl water Space r Tail Temp Evaluation Program: 12.25-in Section Open Hole: Cased Hole: 8.5-in Section Open Hole: Cased Hole: 6.125-in Section Open Hole: 50-bbl Viscosified Spacer (Alpha) weighted to 10.50 ppg 172-sx (35-bbl) 15.8 Ib/gal Prem G - 1.15 cuft/sx (top of tail at 4046' BHST ~ 80°F from SOR, BHCT 85°F estimated by Halliburton MWD/GRlRES IFR/CASANDRA N/A MWD/GRlRES IFRlCASANDRA N/A MWD/GRlRES ABI/IFRlCASANDRA 2 ) Formation Markers: MOrkb (ft) 1,888 3,673 4,265 4,454 4,513 4,577 4,623 4,768 4,871 4,962 5,100 Formation Tops Base Permafrost Top Ugnu Bottom Ugnu NA NB NC NE NF Top OA Base OA Top OB Base OB TO 9,080 *Based on sub-surface depths. TVDrkb (ft) 1,787 3,262 3,712 3,822 3,852 3,882 3,902 3,957 3,992 4,022 4,057 4,077 4,127 CasinglTubing Program: Pore Pressure (psi) 852 1,581 1,803 1,857 1,872 1,887 1,897 1,924 1,941 1,956 1,974 1,983 Hole Csg/ WtlFt Grade Conn Length Size Tbg O.D. 42-in 20-in* 92# H-40 Weld 82-ft 12.25-in 9.625-in 47# L-80 BTC 3,037 -ft 8.5-in 7.0-in 26# L-80 BTC 5,070-ft 6.125-in 4.5-in 12.7# L-80 BTC 4,080-ft OB 6.125-in 4.5-in 12.7# L-80 BTC 4,201-ft OA *The 20" casing is insulated Recommended Bit Program: Depth (MD) 0 - 3,067-ft 3,067 - 5,1 OO-ft 5,1 OO-ft - TO BHA Hole Size 1 2 3 12.25-in 8.5-in 6.125-in )ne Point MPI-15 Well Permit Estimated EMW (Ib/gal)* 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 Top Bottom MD / TVDrkb M D / TVDrkb 30- ft 112-ft / 112-ft 30- ft 3,067-ft / 2, 762-ft 30- ft 5,1 OO-ft / 4,057-ft 5,000-ft / 9,080-ft / 4,033-ft 4,127-ft 4,872-ft / 9,073-ft / / 3,993-ft 4,072-ft Nozzle/Flow rate Hughes MXC-1 3-15 & 1-10 Smith ER6050 3-15 & 1-10 Security 3 - 12 FM2643 Bit Type 3 , -) )"e Point MPI-15 Well Permit Well Control: Surface Interval . The surface hole will be drilled with a diverter. Intermediate and Production Intervals . Maximum anticipated BHP: 1,943-psi @ 3,934-ft T)pSS - Top of OA-sand . Maximum surface pressure: 1,543-psi @ surface (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) . Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 4,000-psi high. An FIT to 11.5-lb/gal will be made on the 7.0-in casing shoe. 25.5-bbl with 10.0-lb/gal mud and FIT of 11.4-lb/gal @ 9.625-in casing shoe. 9.2-lb/gal NaCI / 6.8-lb/gal Diesel . Integrity test: . Kick tolerance: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates . Minor hydrates have been observed on 1-05 @ 1 ,773-ft TVD and 1-10 at 2,390-ft TVD. Hydrates have also been observed on H-03, H-06 and H-07. Hydrates generally occur just below the permafrost (+/- 1 ,800-ft TVDss), but may be present in shallower SV sands and also as deep as 3,000-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates; maintain cool mud « 60°F); limit ROP and reduce pump rate while drilling hydrates; circulate connections thoroughly. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . We do not expect losses while drilling this well. . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures . Reservoir pressure is expected to be 9.5-lb/gal EMW. In this well, the Schrader Bluff formation will be drilled with 10.0-lb/gal mud. 4 ) ')"e Point MPI-15 Well Permit Pad Data Sheet . Please read the I-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults . N/A Hydrogen Sulfide . MPI Pad is not designated as an H2S Pad. Anti-collision Issues . MPI-15 will pass 127-ft from MPI-01 at 6,295-ft MD. Based on 1/200 Minor Risk Criteria, this wellbore passes the BP anti-collision requirements. 5 ') DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1 . Install 20-in insulated conductor. re Point MPI-15 Well Permit Procedure 1. MIRU. NU divert¡on 20-in conductor and function test. 2. Drill 12.25-in surface hole as per directional plan. 3. Case and cement 9.625-in surface casing. 4. NO diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 8.5-in hole to top OB-sand as per directional plan. 7. Case and cement 7.0-in intermediate casing. 8. Perform FIT. 9. Drill 6.125-in OB-sand lateral as per directional plan. 10. Run 4.5-in uncemented slotted liner and hang off 100-ft inside 7.0-in casing. 11. Set whipstock and mill window at top of OA-sand. 12. Drill 6.125-in OA-sand lateral as per directional plan. 13. Pull whipstock. 14. Run 4.5-in uncemented slotted liner with Baker Hookwall Hanger and hang off in 7.0- in casing. 15. Displace drilling mud to brine. 16. Run 2.875-in ESP completion as per schematic. 17. Land tubing hanger and test. 18. Set BPV. 19. NO BOP. 20. Install and test tree. 21. Pull BPV. 23. Test 7.0-in x 2.875-in annulus 24. Freeze protect thru GLM. 25. Install BPV and secure well. 26. RD/MO. 6 TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 5 11",5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger '~HUPUSI::U c.;UMPL~ IIUI\I',) ~JPI-1 PI:-tfi L ~ KB. ELEV = 62.1' Cellar Box ELEV = 34.5' 1128 ~. 20" 92 Iblft, H-40 Welded .. Insulated Diesel freeze protect to 750' MD ,I ;I ~ ,I I I ,I ;I I ;I ;I I ;I ;I ;I I I ;I ;I I I I I ;I ;I ;I ;I ;I ;I I I ;I ;I ;I ;I I.. 9.62511, 47-lb/ft, L-80, BTC Coupling aD: 10.625" Casing Drift: 8.525" Casing 10: 8.681" 3,0671 .. 2.875", 6.4-lb/ft, L-80, EUE 8rd Coupling aD: 3.500" Tubing Drift: 2.347" Tubing I D: 2.441" Window in 711 casing @ 4,872' MD Well Inclination @ Window = 70 Degrees .. 42" Hole 2.875" x 1.0" Gas Lift Mandrel @ 2,000' MD , 2,000' TVD, RPshear valve open position ~ Centrilift NO.2 Cable wI cable clamps 2.875" HES XN nipple, 2.205" ID Centrilift GC 1700 ESP, Series 513, GPMTAR, 123 STG Tandem gas separator Centrilift GST3DBHL seal Centrilift KME1 562 Series, 165 hp, motor, 2230V I 43 amp. Centrilift PHD \~ ...... Multi-Lateral Junction 4,8721 6-1/8" OA Lateral TO 9,073' ....... - - - - - - - OA Horizontal 6-1/8" hole ........ ..... - ----- - - 4-1/211 Slotted Liner W/Hookwall hanger 7.0" 26.0#, L-80, BTC-M Casing Drift: 6.151" Casing 10: 6.276" Coupling aD: 7.656" Burst: 7,240-psi Collapse: 5,410-psi A~ , \.. 8.5" Hole " \ \.. . -OB=--=6-:~ ~'-- -------- 5,1008 Well Inclination @ Shoe = 78 Degrees DATE 22 Jul 02 REV. BY MOO COMMENTS Level 3 Multi-Lateral, 2.875" ESP Completion 6-1/8" OB Lateral TO I 9,080' I - - - - 4-1/211 Slotted Liner & Hanger Milne Point Unit W~I . : MPI-15 API NO: BP Exploration (Alaska) ö COMPANY IWIAII.s BPAmoc(} REFERENCE INFORMATION C<H>rdinate (NIB) Reference: We1I Centre: Plan MPI.15. True North Vertical (TVD) Reference: 62.10' 62.10 Section (VS) Refereoce: Slot - (O.OON,O.OOE) Measured Depth Reference: 62.10' 62.10 Calculation Method: Minimum Curvature C'a1culatìoll Mdhlkl: Minimum ('urvat1.lft: I:rror Systcm: IS('WSA Scan Method: Trav Cylinder North EIT0f Surface: E1Iîptical -j Casing WUn1in~ Method: Rulcs IJaS<.'<i ." " , " " ,,~,...... , 3600- CASING DETAILS No. TVD Size SURVEY PROGRAM Plan: MPI-15L1 wp03 (Plan MPI-15/Plan MP1-15L1) MD Name Depth Fm Depth To Smvey/Plan Tool 4872.00 9072.60 Planned: MPI-15Ll wp03 V3 MWD+IFR+MS Created By: Ken Allen Checked: _. 4072.10 9072.59 4 1/2" 4.500 Date: 7/22/2002 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 3992.10 4870.71 TSBD-OA 4022.10 5948.69 TSBC 4057.10 7539.27 TSBB-OB Reviewed: Date: WELL DETAILS Name +N/..g +E/-W Northing Easting L~titude Longitude Stot Plan MPI-15 1038.70 t511.43 6009436.77 551750.08 70'26'11.496N 149'34'41.064W NJA TARGET DETAILS Name TVD +N/-S +EI-W Northing Easting Shape MPI-OIALl T2b 4017.10 -1611.53 2819.08 6007845.00 554580.00 Point MPl-OlALl Db 4042.10 -1675.66 3413.71 6007785.00 555175.00 Point MPI-OIALI Poly 4052.10 -1749.62 2109.03 6007702.00 553871.00 Polygon MPI-OIA Tlb 4057.10 -1392.17 2195.53 6008060.00 553955.00 Point MPI-OIALI T4b 4057.10 -1563.50 3g24.53 6007900.00 555585.00 Point MPI.OIALI T5b 4057.10 -1026.93 4328.32 6008440.00 556085.00 Point MPI-OIALlT6b 4072. 10 .317.33 4398.25 6009150.00 556150.00 Point MPI-OIALl17b 4072.10 493J5 4343.87 6009960.00 556090.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 4872.00 70.01 115.00 3992.54 -1299.98 I"" 7.82 0.00 0.00 1838.43 2 .1I~').51 90.47 110.44 4021.98 -1365.85 : I .';.65 12.00 -12.84 1987.82 3 '...~. -~. 73 90.47 110.44 4016.77 -1588.06 .'? '1.77 0.00 0,00 2555.07 4 .) .-1.01 89.00 108.00 4017.10 -1611.53 :;..I'j.08 4.00 -121.02 2619.30 MPI-OIALI T2b ~' 5 .,: :1).54 86.59 87.46 4037.17 -1680.66 '.-'7.74 4.00 -97.02 3116.92 6 .. "'1,.41 86.59 87.46 4039.00 -1679.30 "'.~.53 0.00 0.00 3147.67 7 .....i.80 87.00 85.00 4042.10 -1675.66 ql \.71 4.50 -80.69 3202.90 MPI-OIALI T3b 8 ,.h:LI6 87.16 78.43 4048.80 -1656.76 ' .~ \.45 5.00 -88.77 3333.95 9 ..'.'.U3 87.16 78.43 4050.59 -1649.53 ' ;''<.75 0.00 0.00 3369.83 10 ..""';.53 90.00 63.00 4057.10 -1563.50 ''':+.53 6.00 -79.82 3623.76 MPI-OIALI T4b II ""-";.92 90.79 58.79 4056.61 -1528.78 ',,~..i.89 6.00 -79.38 3689.63 12 ..'.1J~.76 90.79 58.79 4055.89 -1501.93 "" 1.22 0.00 0.00 3736.71 13 ¡, "1.27 89.00 21.00 4057.1 0 -1026.93 .¡ '.)\.32 6.00 -92.65 4184.85 MPI-OIALI T5b 14 ~'I,¡".40 88.61 354.55 4069.84 -436.73 .¡ ~1'S.90 4.40 -91.10 4331.49 15 ,,-'11'1.14 88.61 354.55 4071.46 -370.31 "¡~":,.56 0.00 0.00 4332.69 16 "_".".31 90.00 356.16 4072.10 -317.33 .~ "'S.25 4.00 49.34 4334.38 MPI-O I All T6b 17 ""; ~.60 90.00 356.16 4072.10 493.15 '~'''¡_\.87 0.00 0.00 4371.77 MPI-OIALI T7b All TVD depths are ssTVD plus 62.1'for RKBE. 2700 Total Depth: 9072.6' MD, 4072.1' TVD End Dir : 8260.31' MD, 4072.1' TVD Start Dir4/100': 8207.14' MD, 4071.46TVD \ í: Start Dir 12/100': 4872' MD, 3992.54'TVD End Dir : 8140.4' MD,4069.84'TVD ~ 3900- ~. End Dir : 5046.51' MD, 4021.98' TVD Start Dir4/100' : 5682.73' MD, 4016.77'TVD Start Dir 6/100' : 6908.76' MD, 4055.89'TVD g - ~ rSBD'O~A j EndDir : 6856.92'MD,4056.61'TVD \ ~ ß &, I III ~ V ~I\ I '~ " ---- --- .-- TSD' - / ' 4 In" ~ --~--'-:;oo,,-,+"-_LLl___1-_--LJ ~- _.,,~--~!/ /- ~ L- - - ~ I 7oeO .,/ --~_9000 r¡ Fnd Úlr : 6270.54' MJ, 4U37.n TV J / /; / Start Dir4.<-/l00 : 75~9.27 MD. 4057.1 TVD 'f ----_.__._---- Star.Dir U/lIJO': 630IAI'WD,4(39'TVD / >- ~-- Star. Dir 5/10(': 6356.8' \1D, ~042 I'TV) v - ---~- 2 End::>ir '648&.16'MD,4048.~'TV) f- 4200 Start Dir 6I10Ó' : 65;M.23' MD,405059'TVD 4500 1800 2100 2400 '~ 3600 I 4500 3000 3300 Vertical Section at 83.520 [300ft/in] 4200 3900 REFERENCE INFORMATION SURVEY PROGRAM Plan: MPI-15L1 wp03 (Plan MPI-15/Plan MPI-I5L1) Co-ordinate (N/E) Reference: Well Centre: Plan MPI-15, True North Depth Fm Depth To Survey/Plan Tool Created By: Ken Allen Date: 7/2212002 Venical (TVD) Roforen"e: 62.10' 62.10 Section (VS) Referenœ: Slot - (O.OON,O.OOE) 4872.00 9072.60 Planned: MPI-15L1 wp03 V3 MWD+IFR+MS Checked: - M..sured Depth Referen"e: 62.10' 62.10 Calculation Method: Minimum Curvature Reviewed: - SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target I J:: '_'..00 70.01 115.00 3992.54 -1299.98 1"":'.82 0.00 0.00 I~' ';;.43 2 ,"~'¡,51 90.47 110.44 4021.98 -1365.85 .: 1 ";.65 12.00 -12.84 I"~. 7,82 3 .."'-'..73 90.47 110.44 4016.77 -1588.06 : ;'.1.77 0.00 0.00 -'- ;.07 4 '. ,-1.01 89.00 108.00 4017.10 -1611.53 :'" 1'1.08 4.00 -121.02 .',.1 '1.30 MPI-OIALl T2b 5 ..: ¡".54 86.59 87.46 4037.17 -1680.66 ,,-' 7.74 4.00 -97.02 '11'¡,92 6 ,. '''1.41 86.59 87.46 4039.00 -1679.30 ''';;.53 0.00 0.00 \I ~ 7.67 7 ,. ,',j.80 87.00 85.00 4042.10 -1675.66 '~I \.71 4.50 -80.69 '-"'.'..90 MPI-OIALl T3b 8 '.~:,:U6 87.16 78.43 4048.80 -1656.76 "~ \.45 5.00 -88.77 \, \ \.95 9 '. -'-1.23 87.16 78.43 4050.59 -1649.53 " ';;.75 0.00 0.00 '" '1.83 10 '. ;;.;i.53 90.00 63.00 4057.10 -1563.50 '''':+.53 6.00 - 79.82 ".: \.76 MPI-OIALl T4b II '.:. '"j.92 90.79 58.79 4056.61 -1528.78 ,~~,j.89 6.00 -79.38 ..sl.63 12 ',"";;.76 90.79 58.79 4055.89 -1501.93 "" 1.22 0.00 0.00 ,:' "¡.71 13 ;' .-1.27 89.00 21.00 4057.10 -1026.93 .. '-';;.32 6.00 -92.65 .. ¡''¡.85 MPI-OIALl T5b 14 ~1..11.40 88.61 354.55 4069.84 -436.73 -I ~":;.90 4.40 -91.10 -I' \ 1.49 15 ~<"7.14 88.61 354.55 4071.46 -370.31 .~ ~"-~.56 0.00 0.00 -I "-~.69 16 ~:'.'1.31 90.00 356.16 4072.10 -317.33 -I "':;.25 4.00 49.34 .~ "..1.38 MPI-OIALlT6b 17 "":'-~.60 90.00 356.16 4072.10 493.15 '~.' ~.I.87 0.00 0.00 .~..; 1.77 MPI-OIALl T7b d COMPANY IJI'.TAII.s HP Amoco Cakulalil'll M~th()d: Minimum ('urvalun: Em\f Sysh:m: ISCWSA Scan Mclhod: Tmv Cylinder North Enor Sllrlà~è: Elliptical ¡- Casing Wan1in~ Mcthod: Rules Based WELL DETAILS Nan1o: +E/.W Easting Latitude Longitude Slot +N/-S Northing Plan MI)I-15 1038.70 1511.43 551750.08 7o<'26'11.496N 149°34'41.064W NlA 6009436.77 FORMATION TOP DETAILS CASING DETAILS No. TVDPath MDPath Fonnation No. TVD MD Name Size 3992.10 4870.71 TSBD-OA I 4072.10 9072.59 41/2" 4.500 4022.10 5948.69 TSBC 4057.10 7539.27 TSBB-OB 1200- All TVD depths are ssTVD plus 62.1'for RKBE. TARGET DETAILS Name TVD Northing Easting Shape 554580.00 Point 555 I 75.00 Point 553871.00 Polygon 553955.00 Point 555585.00 Point 556085.00 Point 556 I 50.00 Point 556090.00 Point +N/-S +EI-W MPI-15Ll wp03 4 1/2" \ / T útal Depth: 9072.6' MD, 4072.1' TVD tf-- MPI-OIALI T7b MPI-OIALI T2b MPI-OIALI Db MPI-OIALI Poly MPI-OIA Tlb MPI-OIALI T4b MPI-OIALI T5b MPI-OIALIT6b MPI-OIALI T7b 4017.10 -1611.53 2819.08 4042.10 -1675.66 3413.71 4052.10 -1749.62 2I09.03 4057.10 .1392.17 2195.53 4057.10 -1563.50 3824.53 4057.10 -1026.93 4328.32 4072.10 -317.33 4398.25 4072.10 493.15 4343.87 6007845.00 6007785.00 6007702.00 6008060.00 6007900.00 6008440.00 6009150.00 6009960.00 / 4060) '/MPI-I)IALl T5b 1 ./ / ,/ StArt f)ir 4/1 00' . ~óR? T!' \iff), 401;¡ 77'TVD WPH1All T2b !vIP-OIM1 "4b / MP ,-OIALl Db '~ ~04(1 ~ Start Dn 6110U' : 6908.76' MD, 4055.89'TVD 1020 r1\ End Dir : 6855.')2' MD, 4056.61' TVD En< Dir : 6270.5'1' rv D, 1037.17' TVD \ SLlrt Dir 4.5/1 00' : 6301.41' MD, L039 TVD Slart Dir 6/100' : 6524.23' M:J, 4(150.S9'TVD - ----------SïïïrtD'Tr5/11)0': 6356.8' MD, 4042.I'TVD Ene. U¡r : ()"-~M.I()' MU, 4J4M.8' T\U 600 '2 ~ 0 ~ +' :a- t: ~ ~ 0 VJ -600 Slart Dir 12/100' : 4~72' \1D,399U4rrVO ------r En< Dir : 5046.51' MJ,41)21.98' TVD -1200 "-....... -1800 - -~-----~.~----_._- 1800 2400 3000 3600 W est( - )Æast( +) [600ft/in] 4200 End Dir : 8260.31' MD, 4072.1' TVD ../ ~ MPI-OIALIT6b -- "---- Start Dir 4/100' : 8207.14' MD, 4071.46'TVD End Dir : 8140.4' MD, 4069.84' TVD '~ - Start Dir 4.4/100': 7539.27' MD, 4057.I'TVD 4', "., - "" ", ~._- ..,.~ "" ..,.~ -', "' , ~~ I 4800 I 5400 ) BP My Planning Report MAP BP Amoco Mirna Point M PtI Pad Plan MPI-15 Plan MPI-15l1 Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Company: Field: Site: Well: Wellpath: Field: Site: Well: Plan MPI-15 ) Date: 7/22/2002 Time: 13:05:29 Page: Co~i"diöate(NE)Reference: Well: PlånMPJ-15, Trüe North Vertical (TVD) Reference: 62.1 0'62~ 1 Section (VS)Reference: Wen (0.00N,O.OOE,83.52Azi) Survey CalciJl~tion Method: Minimum Curvature Db: Map Zone: Coordinate System: Geomagnetic Model: 6008388.01 ft 550245.83 ft Latitude: Longitude: North Reference: Grid Convergence: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Slot Name: Well Position: +N/-S 1038.70 ft Northing: 6009436.77 ft +E/-W 1511.43 ft Easting : 551750.08 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan MPI-15L 1 Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan: Principal: Yes MPI-15L 1 wp03 Casing Points MD TVD ft ft 9072.59 4072.10 Formations ft ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3992.10 4022.10 4057.10 4870.71 5948.69 7539.27 Targets Map Map <- Latitude -> <- Longitude --> Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft 4017.10 -1611.53 2819.08 6007845.00 554580.00 70 25 55.641 N 149 33 18.347 W 4042.10 -1675.66 3413.71 6007785.00 555175.00 70 25 55.008 N 149 33 0.900 W 4052.10 -1749.62 2109.03 6007702.00 553871.00 70 25 54.285 N 149 33 39.182 W 4052.10 -1749.62 2109.03 6007702.00 553871.00 70 25 54.285 N 149 33 39.182 W Name MPI-01 AL 1 T2b MPI-01 AL 1 T3b MPI-01AL 1 Poly -Polygon 1 62.10' 7/16/2002 57494 nT Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 62.10 ft +N/-S ft 0.00 Date Composed: Version: Tied-to: Diameter in Hole Size in Name 4.500 6.125 41/2" Formations Lithology BPRF TUgnu BUgnu SBF2-NA SBF1-NB SBE4-NC SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB Oracle Alaska, Zone 4 Well Centre BGGM2002 70 26 1.282 N 149 35 25.422 W True 0.39 deg 70 26 11.496 N 149 34 41.064 W Plan MPI-15 4872.00 ft Mean Sea Level 25.75 deg 80.80 deg Direction deg 83.52 7/19/2002 3 From: Definitive Path Dip Angle deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ) BP My Planning Report MAP ) Company: BP Amoco Field: Milne, Point Site: M Pt I Pad Well: Plan MPI-15 Wellpath: Plan MPI-15L1 Targets Date: 7/22/2002 Time: 13:05:29 Page: Co..ordinate(NE) Reference: Well: Plan MPI-15; True North Vertical (TVD) Reference: 62J 0' 62.1 S~tion(VS) Reference: Well (0;00N,O.QOE,83.52Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 2 Map Map <-- Latitude ---> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg MinSec Deg MiJi "See Dip. Dir. ft ft ft ft ft -Polygon 2 4052.10 -1759.20 3203.10 6007700.01 554965.00 70 25 54.187 N 149 33 7.081 W -Polygon 3 4052.10 -1628.84 4163.12 6007837.02 555924.00 70 25 55.465 N 149 32 38.910 W -Polygon 4 4052.10 -1134.09 4496.58 6008334.02 556253.99 70 26 0.329 N 149 3229.117 W -Polygon 5 4052.10 551.90 4527.27 6010020.02 556272.98 70 26 16.910 N 149 32 28.187 W -Polygon 6 4052.10 562.43 4162.30 6010028.01 555907.98 70 26 17.015 N 149 32 38.899 W -Polygon 7 4052.10 -904.24 4089.13 6008561.01 555844.99 70 26 2.592 N 149 32 41.070 W -Polygon 8 4052.10 -1331.20 3210.06 6008128.01 554968.99 70 25 58.397 N 149 33 6.871 W -Polygon 9 4052.10 -1331.67 2123.93 6008120.00 553883.00 70 25 58.396 N 149 33 38.741 W MPI-01A T1 b 4057.10 -1392.17 2195.53 6008060.00 553955.00 70 25 57.801 N 149 33 36.641 W MPI-01AL 1 T4b 4057.10 -1563.50 3824.53 6007900.00 555585.00 70 25 56.109 N 149 32 48.844 W MPI-01 AL 1 T5b 4057.10 -1026.93 4328.32 6008440.00 556085.00 70 26 1.384 N 149 32 34.053 W MPI-01 AL 1T6b 4072.10 -317.33 4398.25 6009150.00 556150.00 70 26 8.362 N 149 32 31.989 W MPI-01AL 1 T7b 4072.10 493.15 4343.87 6009960.00 556090.00 70 26 16.333 N 149 32 33.571 W Plan Section Information MD lncl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1 OOftdeg/1 OOft dég/100ft deg 4872.00 70.01 115.00 3992.54 -1299.98 1997.82 0.00 0.00 0.00 0.00 5046.51 90.4 7 110.44 4021.98 -1365.85 2155.65 12.00 11.72 -2.61 -12.84 5682.73 90.47 110.44 4016.77 -1588.06 2751.77 0.00 0.00 0.00 0.00 5754.01 89.00 108.00 4017.10 -1611.53 2819.08 4.00 -2.06 -3.43 -121.02 MPI-01AL 1 T2b 6270.54 86.59 87.46 4037.17 -1680.66 3327.74 4.00 -0.47 -3.98 -97.02 6301.41 86.59 87.46 4039.00 -1679.30 3358.53 0.00 0.00 0.00 0.00 6356.80 87.00 85.00 4042.10 -1675.66 3413.71 4.50 0.73 -4.45 -80.69 MPI-01AL 1 T3b 6488.16 87.16 78.43 4048.80 -1656.76 3543.45 5.00 0.12 -5.00 -88.77 6524.23 87.16 78.43 4050.59 -1649.53 3578.75 0.00 0.00 0.00 0.00 6785.53 90.00 63.00 4057.10 -1563.50 3824.53 6.00 1.09 -5.90 -79.82 MPI-01AL 1 T4b 6856.92 90.79 58.79 4056.61 -1528.78 3886.89 6.00 1.11 -5.90 -79.38 6908.76 90.79 58.79 4055.89 -1501.93 3931.22 0.00 0.00 0.00 0.00 7539.27 89.00 21.00 4057.10 -1026.93 4328.32 6.00 -0.28 -5.99 -92.65 MPI-01AL 1 T5b 8140.40 88.61 354.55 4069.84 -436.73 4408.90 4.40 -0.06 -4.40 -91.10 8207.14 88.61 354.55 4071.46 -370.31 4402.56 0.00 0.00 0.00 0.00 8260.31 90.00 356.16 4072.10 -317.33 4398.25 4.00 2.61 3.03 49.34 MPI-01AL 1T6b 9072.60 90.00 356.16 4072.10 493.15 4343.87 0.00 0.00 0.00 0.00 MPI-01 AL 1 T7b Survey MD Incl Azim TVD ~ysTVD MapN l\fap~ VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/10Oft 4870.71 70.01 115.00 3992.10 3930.00 6008151.31 553755.57 1837.39 0.00 TSBD-OA 4872.00 70.01 115.00 3992.54 3930.44 6008150.81 553756.68 1838.43 0.00 Start Dir 12/100' : 4872' MD, 4875.00 70.36 114.92 3993.56 3931.46 6008149.63 553759.24 1840.83 12.00 MWD+IFR+MS 4900.00 73.29 114.22 4001.36 3939.26 6008139.91 553780.91 1861.18 12.00 MWD+IFR+MS 4925.00 76.22 113.55 4007.93 3945.83 6008130.30 553803.03 1881.99 12.00 MWD+IFR+MS 4950.00 79.15 112.89 4013.26 3951.16 6008120.83 553825.53 1903.21 12.00 MWD+IFR+MS 4975.00 82.08 112.25 4017.34 3955.24 6008111.53 553848.37 1924.77 12.00 MWD+IFR+MS 5000.00 85.01 111.61 4020.15 3958.05 6008102.41 553871.47 1946.62 12.00 MWD+IFR+MS 5025.00 87.95 110.98 4021.69 3959.59 6008093.51 553894.78 1968.69 12.00 MWD+IFR+MS 5046.51 90.47 110.44 4021.98 3959.88 6008086.05 553914.95 1987.82 12.00 End Dir : 5046.51' MD, 4021.9 5100.00 90.47 110.44 4021.55 3959.45 6008067.71 553965.19 2035.51 0.00 MWD+IFR+MS 5200.00 90.47 110.44 4020.73 3958.63 6008033.44 554059.12 2124.67 0.00 MWD+IFR+MS 5300.00 90.47 110.44 4019.91 3957.81 6007999.17 554153.05 2213.83 0.00 MWD+IFR+MS 5400.00 90.47 110.44 4019.09 3956.99 6007964.89 554246.98 2302.99 0.00 MWD+IFR+MS 5500.00 90.47 110.44 4018.27 3956.17 6007930.62 554340.91 2392.15 0.00 MWD+IFR+MS ) BP ) My Planning Report MAP Company: BP Amoco Dade: 7/22/2002 Time: 13:05:29 Page: 3 Field: Milne Point Co..ordinate(NE} Reference: Well:' Plan MPI-15, True North Site: M PtI Pad Vertical. (TV))) ,Reference: 62.10' 62.1 Well: Plan MPI-15 Section(VS)~eference: Well. (0,00N.0~OOE;83.52Azi) Wellpath: Plan MPI-15L 1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 5600.00 90.47 110.44 4017.45 3955.35 6007896.35 554434.84 2481.32 0.00 MWD+IFR+MS 5682.73 90.47 110.44 4016.77 3954.67 6007867.99 554512.54 2555.07 0.00 Start Dir 4/100' : 5682.73' MD 5700.00 90.11 109.85 4016.68 3954.58 6007862.16 554528.80 2570.52 4.00 MWD+IFR+MS 5754.01 89.00 108.00 4017.10 3955.00 6007845.00 554580.00 2619.30 4.00 MPI-01AL 1 T2b 5800.00 88.78 106.17 4017.99 3955.89 6007831.79 554624.04 2661.45 4.00 MWD+IFR+MS 5900.00 88.29 102.20 4020.55 3958.45 6007807.97 554721.09 2754.96 4.00 MWD+IFR+MS 5948.69 88.06 100.27 4022.10 3960.00 6007798.82 554768.88 2801.31 4.00 TSBC 6000.00 87.82 98.23 4023.94 3961.84 6007790.94 554819.54 2850.67 4.00 MWD+IFR+MS 6100.00 87.35 94.25 4028.16 3966.06 6007780.77 554918.90 2948.11 4.00 MWD+IFR+MS 6200.00 86.90 90.27 4033.17 3971.07 6007777.52 555018.70 3046.81 4.00 MWD+IFR+MS 6270.54 86.59 87.46 4037.17 3975.07 6007779.40 555089.08 3116.92 4.00 End Dir : 6270.54' MD, 4037.1 6301.41 86.59 87.46 4039.00 3976.90 6007780.98 555119.86 3147.67 0.00 Start Dir 4.5/100' : 6301.41' 6356.80 87.00 85.00 4042.10 3980.00 6007785.00 555175.00 3202.90 4.50 MPI-01AL 1 T3b 6400.00 87.05 82.84 4044.34 3982.24 6007789.86 555217.86 3246.04 5.00 MWD+IFR+MS 6488.16 87.16 78.43 4048.80 3986.70 6007804.79 555304.60 3333.95 5.00 End Dir : 6488.16' MD, 4048.8 6500.00 87.16 78.43 4049.39 3987.29 6007807.25 555316.17 3345.73 0.00 MWD+IFR+MS 6524.23 87.16 78.43 4050.59 3988.49 6007812.27 555339.84 3369.83 0.00 Start Dir 6/100' : 6524.23' MD 6550.00 87.43 76.90 4051.80 3989.70 6007817.94 555364.95 3395.44 6.00 MWD+IFR+MS 6600.00 87.97 73.95 4053.81 3991.71 6007830.85 555413.20 3444.90 6.00 MWD+IFR+MS 6650.00 88.51 71.00 4055.34 3993.24 6007846.22 555460.74 3493.94 6.00 MWD+IFR+MS 6700.00 89.06 68.05 4056.40 3994.30 6007864.03 555507.44 3542.44 6.00 MWD+IFR+MS 6750.00 89.61 65.10 4056.98 3994.88 6007884.23 555553.16 3590.26 6.00 MWD+IFR+MS 6785.53 90.00 63.00 4057.10 3995.00 6007900.00 555585.00 3623.76 6.00 MPI-01AL 1 T4b 6800.00 90.16 62.15 4057.08 3994.98 6007906.75 555597.79 3637.27 6.00 MWD+IFR+MS 6850.00 90.71 59.20 4056.70 3994.60 6007931.53 555641.20 3683.34 6.00 MWD+IFR+MS 6856.92 90.79 58.79 4056.61 3994.51 6007935.14 555647.11 3689.63 6.00 End Dir : 6856.92' MD, 4056.6 6908.76 90.79 58.79 4055.89 3993.79 6007962.30 555691.25 3736.71 0.00 Start Dir 6/100' : 6908.76' MD 6950.00 90.67 56.32 4055.37 3993.27 6007984.66 555725.89 3773.78 6.00 MWD+IFR+MS 7000.00 90.53 53.32 4054.84 3992.74 6008013.75 555766.54 3817.63 6.00 MWD+IFR+MS 7050.00 90.39 50.32 4054.44 3992.34 6008044.92 555805.62 3860.16 6.00 MWD+IFR+MS 7100.00 90.25 47.33 4054.16 3992.06 6008078.09 555843.02 3901.27 6.00 MWD+IFR+MS 7150.00 90.10 44.33 4054.01 3991.91 6008113.17 555878.64 3940.83 6.00 MWD+IFR+MS 7200.00 89.96 41.33 4053.98 3991.88 6008150.06 555912.37 3978.74 6.00 MWD+IFR+MS 7250.00 89.81 38.34 4054.08 3991.98 6008188.67 555944.12 4014.89 6.00 MWD+IFR+MS 7300.00 89.67 35.34 4054.31 3992.21 6008228.88 555973.82 4049.19 6.00 MWD+IFR+MS 7350.00 89.53 32.34 4054.66 3992.56 6008270.59 556001.37 4081.53 6.00 MWD+IFR+MS 7400.00 89.38 29.35 4055.13 3993.03 6008313.69 556026.70 4111.84 6.00 MWD+IFR+MS 7450.00 89.24 26.35 4055.73 3993.63 6008358.04 556049.74 4140.04 6.00 MWD+IFR+MS 7500.00 89.11 23.35 4056.45 3994.35 6008403.54 556070.44 4166.03 6.00 MWD+IFR+MS 7539.27 89.00 21.00 4057.10 3995.00 6008440.00 556085.00 4184.85 6.00 MPI-01AL 1 T5b 7600.00 88.95 18.33 4058.19 3996.09 6008497.31 556105.03 4211.60 4.40 MWD+IFR+MS 7700.00 88.87 13.93 4060.09 3997.99 6008593.51 556132.13 4250.02 4.40 MWD+IFR+MS 7800.00 88.80 9.53 4062.12 4000.02 6008691.51 556151.76 4281.25 4.40 MWD+IFR+MS 7900.00 88.74 5.13 4064.27 4002.17 6008790.72 556163.82 4305.10 4.40 MWD+IFR+MS 8000.00 88.68 0.73 4066.52 4004.42 6008890.56 556168.23 4321.43 4.40 MWD+IFR+MS 8100.00 88.63 356.33 4068.87 4006.77 6008990.45 556164.97 4330.15 4.40 MWD+IFR+MS 8140.40 88.61 354.55 4069.84 4007.74 6009030.69 556161.47 4331.49 4.40 End Dir : 8140.4' MD, 4069.84 8207.14 88.61 354.55 4071.46 4009.36 6009097.05 556154.67 4332.69 0.00 Start Dir 4/100' : 8207.14' MD 8260.31 90.00 356.16 4072.10 4010.00 6009150.00 556150.00 4334.38 4.00 MPI-01AL 1T6b 8300.00 90.00 356.16 4072.10 4010.00 6009189.58 556147.07 4336.21 0.00 MWD+IFR+MS 8400.00 90.00 356.16 4072.10 4010.00 6009289.29 556139.68 4340.81 0.00 MWD+IFR+MS 8500.00 90.00 356.16 4072.10 4010.00 6009389.01 556132.29 4345.41 0.00 MWD+IFR+MS Company: BP Amoco Fiëld: Milne, Point Site: M pt I Pad Well: Plan MPI~15 WeUpath: Plan MPI~15l1 Survey MD ft 8600.00 8700.00 8800.00 Ind Azim deg deg 90.00 356.16 90.00 356.16 90.00 356.16 8900.00 90.00 356.16 9000.00 90.00 356.16 9072.59 90.00 356.16 9072.58 90.00 356.16 9072.60 90.00 356.16 BP My Planning Report MAP ) Date: . ' 7/22/2002 Time: "13:05:29 Page: Co~rdinät~(NE)Rëferënçe: Well:.Plari MPI~15; TrüeNë>rth VertiçaHTVD) Réference: 62.10' 62: 1 Section. (VS)Reference: V\{eU(ROQN,O;OOE;83;52Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 4 TV» Sys TVD MapN MapE 'VS DLS Tool/Comment ft ft ft ft ft dég/tOOft 4072.10 4010.00 6009488.73 556124.90 4350.01 0.00 MWD+IFR+MS 4072.10 4010.00 6009588.45 556117.51 4354.61 0.00 MWD+IFR+MS 4072.10 4010.00 6009688.16 556110.13 4359.21 0.00 MWD+IFR+MS 4072.10 4010.00 6009787.88 556102.74 4363.81 0.00 MWD+IFR+MS 4072.10 4010.00 6009887.60 556095.35 4368.41 0.00 MWD+IFR+MS 4072.10 4010.00 6009959.98 556089.98 4371.75 0.00 41/2" 4072.10 4010.00 6009959.97 556089.99 4371.75 0.00 Total Depth: 9072.6' MD, 4072 4072.10 4010.00 6009960.00 556090.00 4371.77 0.00 MPI-01AL 1 T7b ) Per Alaska Oil and Gas Conservation Commission Regulation 20 AA 25.005 Permit to Drill sub section 14 (e) if a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface or production casing, the applicant shall designate one branch as the primary Wellbore and include all information required under (c) of this section that is unique to that branch and need not include the $100 fee. ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ;£1 IJ - IS ¿ / PTD# 7_°2-/5:3 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL v (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well /1 /: 1; ~ / S Permit No,2oë.-1 f2...API NO.fð"C1.2.~ - 2S jol:. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. :WELL PERMIT CHECKLIST COMPANY ~ X WELL NAME /11:1"'/_5 ¿:1. PROGRAM: Exp - Dev _Redrll- Re-Enter - Serv - Wellbore seg X- FIELD & POOL 5' 25'/ f/ I"r INIT CLASS f)e> J/ /'-6// GEOL AREA ?'7 r""J UNIT# (I .5 ¿ t? ON/OFF SHORE C)"tJ :ADMINISTRATION '1. Permilfee attached. . . . . . . . . . . . . . . . . . . . . . . (('.N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . / ~ N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wetls.. . .. . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N . //0 /'h g/¿<- .... 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N . ~ / <- V' ¿.- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y \ N 12. Permit can be issued without administrative approval.. . . . . .;xJ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#- Y N . (Service Well Only) 14. All wens w/in X mile area of review identified. . . . . . . . .. Y N <ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥--N- 16. Surface casing protects all known USDWs. . . . . . . . . . . -¥--tr ~ J / A ~ 17. CMT vol adequate to circulate on conductor & surf csg. . . . . '¥ N . IV { tr 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . '¥-'M'" . 19. CMTwill coverall known productive horizons. . . . . . . . . . ~ Stoffel 20. Casing designs adequate for C, T, B & permafrost. . . . . . . , N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . ,N Ð 1fl-<-1~ {" / 22. If a re-driU, has a 10-403 for abandonment been approved. . . -¥--tt" ¡oJ fA- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . @ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥--N-N/t1- 25. Drilling fluid program schematic & equip list adequate. . . . . ,," N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . " N 27. BOPE press rating appropriate; testto 400tt? psig. N r J 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ltJlW4- 7/bI¡ OL 29. Work will occur without operation shutdown. . . . . . . . . . .' R 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y áV 31. Mechanical condition of wells within AOR verified. . . . . . . . ,.;:) N ~A- 32. Permit can be issued w/o hydrogen sulfide measures. . . . . ;frN 33. Da~a ~resente~ on potential overpressure zones. . . . . . . . Y N A' / J) 34. Seismic analysIs of shallow gas zones. . . . . . . . . . . . . Y '1/' y:; J 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~ TEM JDH .:::J¡t- JBR APPR DATE (Service Well Only) GEOLOGY APPR DATE ,IIÞ~ 7b~~ . (Exploratory Only) Rev: 07/12102 SFD- WGA t;J6þ MJW G:\geology\permits\checklist.doc ) COMMISSIONER: COT DTS °1( ¿(J Comments/Instructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simplify finding infom1ation. infonnation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically. . organize this category of information. ) ) eX o~- J53 1133« Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 03 15:37:37 2002 Reel Header Service name.. .......... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 0 3 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.... ............ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments..... .......... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-15 Ll 500292310660 BP Exploration (Alaska), Inc Sperry-Sun Drilling Services 03-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22136 J. STRAHAN E. VAUGHN MWDRUN 2 AK-MW-22136 J. STRAHAN E. VAUGHN MWDRUN 5 AK-MW-22136 B. ZIEMKE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 6 AK-MW-22136 J. STRAHAN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2326 3641 62.50 35.00 ) ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 6.125 CASING SIZE (IN) 20.000 9.625 7.000 DRILLERS DEPTH (FT) 112.0 3084.0 4849.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SEGMENT IS A LATERAL DRILLED MPI-15 WELLBORE. THE TOP OF THE WHIPSTOCK WAS PLACED AT 4849'MD/3968'TVD AND THE BOTTOM WAS AT 4863'MD/3972'TVD. FROM THE 4. MWD RUNS 1, 2, AND 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 6 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 5 WAS DIRECTIONAL ONLY TO ORIENT A WHIPSTOCK, AND ONLY ROP DATA ARE PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1, PART OF 2, 5, AND 6 REPRESENT WELL MPI-15 Ll WITH API#: 50-029-23106-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9000'MD/ 4042'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name........... ..STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/12/03 Maximum Physical Record. .65535 File Type............... .LO ) ) Previous File Name.... ...STSLIB.OOO Corrunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 42.5 86.0 90.5 90.5 90.5 90.5 90.5 STOP DEPTH 8945.5 9000.0 8952.5 8952.5 8952.5 8952.5 8952.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 42.5 3092.0 MWD 2 3092.0 4849.0 MWD 5 4849.0 4878.0 MWD 6 4878.0 9000.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... . Undefined Absent value... .......... ... ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H Min 42.5 0.02 Max 9000 1235.55 Mean Nsam 4521.25 17916 233.181 17829 First Reading 42.5 86 Last Reading 9000 9000 ) ) GR MWD API 13.53 141.87 72.4339 17807 42.5 8945.5 RPX MWD OHMM 0.06 1750.66 18.8044 17640 90.5 8952.5 RPS MWD OHMM 0.18 2000 25.9641 17640 90.5 8952.5 RPM MWD OHMM 0.15 2000 30.2077 17640 90.5 8952.5 RPD MWD OHMM 0.1 2000 33.7571 17640 90.5 8952.5 FET MWD HOUR 0.0683 189.002 0.797659 17640 90.5 8952.5 First Reading For Entire File......... .42.5 Last Reading For Entire File.......... .9000 File Trailer Service name...... .... ...STSLIB.001 Service Sub Level Name... Version Number.... ... ....1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name......... ..STSLIB.002 Physical EOF File Header Service name. .... ........STSLIB.002 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation..... ..02/12/03 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name... ... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP RPD RPM RPS RPX FET $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 42.5 86.0 90.5 90.5 90.5 90.5 90.5 STOP DEPTH 3050.0 3092.0 3041.5 3041.5 3041.5 3041.5 3041.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17-AUG-02 Insite 66.37 Memory 3092.0 112.0 3092.0 .0 MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... ........... ..0 Data Specification Block Type... ..0 Logging Direction. .... ........ ....Down Optical log depth units........ ...Feet Data Reference Point............. . Undefined Frame Spacing...... ..... ......... .60 .1IN Max frames per record.. ...... .... . Undefined Absent value..... .... ........ ... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 36.2 TOOL NUMBER 136694 134760 12.250 112.0 Water 9.15 211.0 7.5 900 10.1 Based 6.000 5.500 7.000 4.500 66.0 72.6 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42.5 3092 1567.25 6100 42.5 3092 ROP MWD010 FT/H 20.19 1235.55 246.022 6013 86 3092 GR MWD010 API 13.53 117.52 58.5865 6016 42.5 3050 ) ) RPX MWD010 OHMM 0.33 301.11 25.7147 5903 90.5 3041.5 RPS MWD010 OHMM 0.18 653.35 36.6394 5903 90.5 3041.5 RPM MWD010 OHMM 0.15 2000 50.1451 5903 90.5 3041.5 RPD MWD010 OHMM 0.13 2000 58.2868 5903 90.5 3041.5 FET MWD010 HOUR 0.0683 2.1393 0.466831 5903 90.5 3041.5 First Reading For Entire File.... .... ..42.5 Last Reading For Entire File.... ... ... .3092 File Trailer Service name. ........... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record. .65535 File Type......... ...... .LO Next File Name..... ..... .STSLIB.003 Physical EOF File Header Service name...... ...... .STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ......02/12/03 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3050.5 3084.5 3084.5 3084.5 3084.5 3084.5 3092.5 STOP DEPTH 4849.0 4849.0 4849.0 4849.0 4849.0 4849.0 4848.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL ( FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 19-AUG-02 Insite 66.37 Memory 4849.0 3092.0 4849.0 34.3 84.9 ) # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.. ...0 Logging Direction........ ...... ...Down Optical log depth units.. ...... ...Feet Data Reference Point..... ........ . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 136694 134760 8.750 3084.0 Water 10.15 53.0 7.8 600 7.2 Based 9.000 6.190 9.500 7.000 65.0 97.5 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3050.5 4849 3949.75 3598 3050.5 4849 ROP MWD020 FT/H 13.05 756.55 324.528 3513 3092.5 4848.5 GR MWD020 API 21.68 118.41 68.5375 3598 3050.5 4849 RPX MWD020 OHMM 0.06 301.11 14.3185 3530 3084.5 4849 ) ) RPS MWD020 OHMM 1.24 201.6 13.829 3530 3084.5 4849 RPM MWD020 OHMM 0.93 2000 14.658 3530 3084.5 4849 RPD MWD020 OHMM 0.1 2000 17.2814 3530 3084.5 4849 FET MWD020 HOUR 0.0803 40.3652 0.52179 3530 3084.5 4849 First Reading For Entire File........ ..3050.5 Last Reading For Entire File..... ..... .4849 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name. ........... .STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.... ...02/12/03 Maximum Physical Record..65535 File Type. ...... ..... . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 4849.0 $ 4 header data for each bit run in separate files. 5 .5000 STOP DEPTH 4878.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-AUG-02 Insite 66.37 Memory 4878.0 4849.0 4878.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 151107 156401 # ) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ... ........ ......0 Data Specification Block Type.. ...0 Logging Direction... ......... ... ..Down Optical log depth units. ..... ... ..Feet Data Reference Point..... .... ... ..Undefined Frame Spacing............. .... ... .60 .1IN Max frames per record..... .... ... . Undefined Absent value. ... ........... ...... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.151 4849.0 Flo-Pro 9.60 56.0 7.5 62000 4.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD050 FT/H Min 4849 0.02 Max 4878 21.95 First Reading For Entire File.... ..... .4849 Last Reading For Entire File. ......... .4878 File Trailer Service name...... ...... .STSLIB.004 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record. .65535 File Type........... .....LO Next File Name.......... .STSLIB.005 Mean Nsam 4863.5 59 10.0508 59 ) .0 80.6 .0 .0 First Reading 4849 4849 Last Reading 4878 4878 ) Physical EOF File Header Service name. ...... ..... .STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation..... ..02/12/03 Maximum Physical Record. .65535 File Type. ......... ..... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 5 ) header data for each bit run in separate files. 6 .5000 START DEPTH 4849.5 4849.5 4849.5 4849.5 4849.5 4849.5 4878.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8952.5 8952.5 8952.5 8952.5 8945.5 8952.5 9000.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 29-AUG-02 Insite 66.37 Memory 9000.0 4878.0 9000.0 74.4 93.8 TOOL NUMBER 151107 156401 6.125 4849.0 Flo-Pro 9.60 57.0 8.5 48000 5.0 .800 69.0 ) ) MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .560 .800 .900 102.2 69.0 69.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ...... ........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point...... ....... . Undefined Frame Spacing....... ....... ...... .60 .1IN Max frames per record............ .Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4849.5 9000 6924.75 8302 4849.5 9000 ROP MWD060 FT/H 1.12 720.95 186.486 8244 4878.5 9000 GR MWD060 API 49.66 141.87 84.3131 8193 4849.5 8945.5 RPX MWD060 OHMM 0.12 1750.66 15.7636 8207 4849.5 8952.5 RPS MWD060 OHMM 3.62 2000 23.5053 8207 4849.5 8952.5 RPM MWD060 OHMM 0.29 2000 22.5557 8207 4849.5 8952.5 RPD MWD060 OHMM 4.61 2000 23.2004 8207 4849.5 8952.5 FET MWD060 HOUR 0.1981 189.002 1.16654 8207 4849.5 8952.5 First Reading For Entire File....... ...4849.5 Last Reading For Entire File.......... .9000 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .02/12/03 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.006 physical EOF Tape Trailer Service name..... .... ... .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... .......... ..UNKNOWN Continuation Number..... .01 Next Tape Name..... ..... . UNKNOWN Comments.. ........... ... .STS LIS Reel Trailer Service name.......... ...LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name........ ...UNKNOWN Comments....... ......... .STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services