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200-120
• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned L" Suspended[ lb.Well Class: 20AAc 25.105, 20AAc 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 4/17/2016 • 200-120/315-537 3.Address: 7. a pudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 September 9, 2000 50-029-22970-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2685'FSL, 3390'FEL, Sec 28,T13N, R10E, UM,AK September 22, 2000 MPJ-23 Top of Productive Interval: 9. Ref Elevations: KB: 69' 17. Field/Pool(s): Milne Point Unit N/A GL: 36.1' BF:36.1' Schrader Bluff Oil Pool ' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2952'FSL, 3183'FEL, Sec 30,T13N, R10E, UM,AK '7,800'MD/3,571'TVD ADL 025517 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 551926 y- 6015082 Zone- 4 12,062'MD/3,783'TVD N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 541571 y- 6015284 Zone- 4 N/A 1,800'MD/1,672'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED APR 2 9 2016 ": APR 2 2 2016 23. CASING, LINER AND CEMENTING RECORD OGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 54.5# K-55 Surface 108' Surface 108' 30" 260 sx Arcticset I 7" 26# L-80 Surface 8,892' Surface 3,839' 9-7/8" 1100 sx, 542 sx 260 sx 4-1/2" 12.6# L-80 8,798' 12,062' 3,824' 3,783' 6-1/8" Cementless Slotted Liner 24. Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 7,937' 7,900'MD/3,579'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7,800'Cement Retainer 295 sx,60 bbls,15.8 ppg Halcem thru cmt rtnr 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period --0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate — Form 10-407 Revisec�1,�/2 r4(.._ NTI U ON PAGE 2 Submit ORIGINIAL onn '�LL� 1��Y� 34- - y� � RBDMS 1-"- APR 2 5 2016 y 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: es ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary,Wellbore Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporholatG7hiIcorp.com Printed Name: go York Title: Operations Manager Signature: ,GC-- C a1 y�✓I` Phone: 777-8345 Date: 7)2-2.j2-0 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Milne Point Unit Well: MPU J-23/J-23L1 SCHEMATIC Abandoned: 4/17/2016 Bacon)Alaska,LLC PTD: 200-120/200-121 Orig.KB Elev=63.2'GL Elev.35.8' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20j '' 20" Conductor 54.5/K-55/Welded N/A Surf 108' } ,, 7" Surface 26/L-80/Btrc. 6.151 Surf 8,892' kik 4,Abandoned sj, y 4-1/2" Liner L1 12.6/L-80/IBT 3.833 8,590' 12,126' *7, 4-1/2" Liner 12.6/L-80/IBT 3.833 8,798' 12,062' a TUBING DETAIL 11 e 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.867 7,892 7,937' iz *44 JEWELRY DETAIL No Depth Item 1 7,800' Cement Retainer a� 2 7,892' 3-1/2"Tubing Cut Joint i�= 3 7,900' Baker S-3 Packer 4 7,937' WLEG k OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sx of Arcticset I 7„ Cmt w/1,100 sx Arcticset III,542 sx Class"G"in 9-7/8" Hole cement returns to surface Cement Cmt w/295 sx(60 bbls)of 15.8 ppg Halcem thru Retainer cement retainer GENERAL WELL INFO API:50-029-22970-00/(60)-00 Drilled and Cased by Doyon 141-10/8/2000 P&A'd by Doyon 14—4/17/2016 1 3 4 AI 1 411 TD=12,062'(MD)/TD=3,783'(TVD) PBTD=7,800'(MD)/PBTD=3,571'(TVD) Created By:STP 4/19/2016 Hilco'Fp Energy Company Composite Report Well Name: MPJ-23/L1 Field: Milne Point County/State: ,Alaska 1(LAT/LONG): evation(RKB): API#: Job Name: MPJ-23 Decomplete Contractor AFE#: 1511739D AFE$: $2,676,786 ! 101'.. _ .Iham:= z :ApsSurrowri , 4/13/2016 Continue to prep for rig move-to J-Pad.Dig out snow from around rig.Remove snow berm from Pad entrance for rig clearance.Pull off well,install boosters.Haul support equipment from K-Pad to J-Pad;Notify Security,Start rig move from K-Pad to J-pad.Continue hauling support equipment to J-Pad.Rig arrived @ J-PAD ©21:00 hrs,9.5 miles total.;Remove rear boosters,remove snow from behind well,set mats around well,place adapter flange and tree behind well,get kill tank f/ B-pad. Mobilize rock washer and equipment f/K-pad to J-pad.;Notify DSO,PJSM,move and spot rig over J-23A,level and set down rig. Note:Rig accepted @ 04:30 hrs.;R/U on J-23A,Skid rig floor into position,lay mats,set cuttings box and rock washer skid,Continue to mobilize equipment from K-pad. 4/14/2016 Rig up floor heat/steam/air and water.Clean out cellar box and prep cellar area,prep mud pits for seawater.load pits with Seawater.Lay mats and spot rock washer skid.;Hook up pump lines on rig floor.Remove BPV and test circulating lines.Blow down circulating lines.Finish setting rock washer skid.Trucks were on hold for weather for about 2 hrs;Line up to kill well pumping down tubing.Both IA and Tubing Pressure @ 0 psi.Pump Seawater down tubing @ 3 bpm/400 psi. Establish returns @ 21 bbls pumped.Mostly Crude returns for first 90 bbls.;lncrease pump rate to 4 bpm/500 psi after bottoms up.Continue to circulate a total of 473 bbls with 321 bbls back to surface w/8.5 SW in/out.Lost 152 bbls on circulation.;Monitor well for 30 minutes with tubing and IA on vac.;Shut in well.Blow down circulating lines.R/D lines.Set BPV.R/U fill up line with gauge to IA for monitor and fill during BOP test. Note:Losses to well @ 12 bph.;N/D Tree.Inspect hanger threads,3.625"acme threads,w/2.95"min ID.Exercise Lock Down Screws. Note:Notify Baker fishing that spear needed to pull hanger due to unconventional hanger thread.;N/U 13 5/8"5M BOPE dressed w/2 7/8"x 5"VBR rams in upper and lower,Blind ram in middle BOP.Get stack measurements. Continue to load 4"DP into pipeshed. Note:well continues taking 12 bph.;Pull BPV,install TWC per wellhead rep.;M/U 3 1/2"test jt,flood stack and lines with fresh water.perform body test to 250/3000 psi,good. Note:AOGCC inspector Matt Herrera verbally waived witness to test @ 03:50 hrs.;Test BOP components using 3 1/2"and 4"test joints with doughnut style upset on end,test to 250 psi low and 3000 psi high 5 min.ea.Chart all tests. Cont to monitor and fill annulus @ 12 bph;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 0 bbls from L-Pad Lake for total=0 bbls Hauled 120 bbls to ORT,total 120 bbls Daily losses 176 bbls,total=176 bbls 4/15/2016 Cont Test BOP components using 3 1/2"and 4"test joints with doughnut style upset on end,test to 250 psi low and 3000 psi high 5 min.ea.Chart all tests. Cont to monitor and fill annulus @ 12 bph;Test gas alarms.Perform Accumulator Test:Start 3000 psi/After Close 1600 psi/200 psi build 38 sec/Full recovery 186 sec.N2 bottles 6 @ 2025 ay.Rig down Test Equipment.;Blow down choke and kill lines,clear XO subs ect from floor.Stage Weatherford/Centrilift equipment on floor.;Pull TWC,Fill tubing with Seawater.20 bbls to fill tubing.;M/U 2 13/16"ITECO Spear to stand of DP.Engage spear into tubing hanger.BOLDS.Unseat hanger @ 115K.Pull hanger to floor.PUW 105/SOW 80K.Break down and lay down Hgr and spear.;POOH UD 3 1/2"Eue 8rd tubing with 1/4"control line from 7888'to 6100',conduct Trip drill,1.56 min response time,Continue POOH to 465',flowing out tbg Note:Fill hole @ 10 bph.;M/U FOSV,circulate out and dump oil cap to rock washer,pump 9 bbls before seeing returns.Blow down top drive.;Continue POH UD tbg from 465'to surface,continue hole fill @ 10 bph.;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 190 bbls to B-50 for total=190 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 102 bbls from L-Pad Lake for total=102 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 385 bbls,total=561 bbls 4/16/2016 Continue to POOH UD 3 1/2"Eue tbg.Lay down total of 248 jts/2 GLM/1 Slide Sleeve/Cut jt 2.10'.;Clear and clean rig floor.Stage BHA components on floor, Load 4 3/4"DC's in pipe shed,tally same.Rig up floor for handling 4"DP.;M/U C/O BHA:6 1/8"Tricone Bit/2ea 4 3/4"Boot Baskets/7"Csg Scraper/Bit Sub/6 1/8"String mill/9 ea 4 3/4"DC's/15 jts 4"HWDP.=754.21'.;TIH with C/O BHA picking up 4"DP from pipe shed 754'to 4850'.PUW 100K/SOW 82K.;Fill pipe @ 4550'.Pumped 46 bbls,catch returns @ 25 bbls.Blow Down Top Drive. Switch Rig to High Line Power.;Cont.TIH with C/O BHA picking up 4"DP from 4850'to 7892'.PUW 140K/SOW 85K.Tag TOF @ 7892'.UD 1 single DP.MU Top Drive.;Break circulation.Fill Pipe.Catch returns @ 28 bbls.CBU @ 6 bpm/950 psi,working scraper 90'from 7878'to 7788'across cement retainer and whipstock setting depth. Note:loss rate circ©130 bph.;Monitor well for 10 minutes,blow down top drive.;POH from 7892'to 750'@ HWDP,rack 5 stds HWDP and 3 stds 4 3/4"drill collars in drk,L/D XO,string mill,bit sub,scraper,2 boot bskts and bit. Note:fill hole @ 20 bph POH.;Fill hole 20 bbls,monitor well,static loss rate @ 108 bph.Load out Tools,clear rig floor.Stage retainer BHA on rig floor.;PJSM, M/U Baker K-1 mech.cement retainer,setting tool and XO=7.39',retainer only=1.89'TIH w/stds 4"DP to 7170'. Note:use 20 bph hole fill TIH.;Single in with 4"DP to 7802'@ retainer setting depth,verify pipe count.;Circulate until hole full,23 bbls,P/U 130K,S/O 80K,set retainer per Baker rep @ 7802'with top retainer @ 7800'(top retainer 7'above casing collar @7807');Unsting,BDTD,M/U head pin on single,stab into retainer setting down 30k,R/U cementers.;Hauled 0 bbls to MP G&I for total=0 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 85 bbls to B-50 for total=275 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 120 bbls from L-Pad Lake for total=222 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 625 bbls,total=1186 bbls seawater 4/17/2016 Continue to RU HES Cementers. Hol with crews.;Squeeze CMT Below Retainer @ 7800'Sows:Pump 10 bbls fresh water.Test lines to 3500 psi. Mix and Pump 295sx/60 bbls 15.8 ppg EM(TM)SYSTEM CMT @ 3.5 bpm/425 psi.;Pump Fr ater displacement @ 4.5 BPM avg/1150 psi,Caught cement @ 18 bbls away.Pumped total of 86 bbls Displacement.2 bbls over calculated.Final pump pressure 700 psi @ 2.8 BPM.;Unsting from ret.Turn over to rig and pump 1 hole vol SW with no CMT returns.Break off head pin,load foam DP wiper.MU Head pin.Circulate DP volume+20 bbls to wipe ID of DP,7.5 bpm/1150 psi.;Close pipe rams.Pressure test 7"casing from surface to retainer @ 7800'to 1800 psi and chart for 30 min.Good Test.;Circulate DP Vol due to unbalanced fluid.Blow down and rig down circ equipment.;POOH with Retainer running tool from 7800'.Lay down Retainer Running tool.PUW 125K/SOW 73K.;Clean and clear rig floor.Stage Whipstock BHA components on rig floor.Prep to N/D and Install tubing spool.;PJSM,Drain stack,de energize Koomey,N/D and Set stack aside.Install new tbg spool on top of existing tbg spool.;N/U BOP stack,re-install kill line,riser and BOP anchors.;PJSM,close blind ram,test spool flanges to 250 psi low/1750 psi high 5 min ea.M/U 4 1/2"test jt,install test plug,test upper and lower 2 7/8"VBR rams;to 250 psi low/3000 psi high 5 min ea. Chart all tests.R/D test equipment.;Record new stack measurements.Install 8.9375"ID wear bushing,;Service rig,drawworks,inspect brake linkage.;PJSM w/ BOT,Sperry,rig crew for P/U Whipstock assembly as follows:M/U 6 1/8"window mill,lower 5 7/8"WM mill,flex jt,upper 6.151"WM mill,1-3 1/2"HWDP,FLT sub,DM and TM collar.;Scribe window mill to MWD w/offset @ 325 deg,set assy to side,close blind ram,P/U WS with hoist,remove shipping bolt and 3 shear bolts on anchor,leaving 3 in w/anchor shear set @ 10695 ft/Ibs.;set WS in hole,M/U to mill w/25k brass shear bolt installed.open Blind ram.M/U XO,9-4 3/4" drill collars from drk and 1 std HWDP, Note:very easy in and out of slips w/run speed @ 50 fpm.;Suface test MWD,good.Blow down top drive. RIH w/remaining 4 stds HWDP=822.93';TIH on elevators 50 fpm from 823'to 3100',slow in/out slips,fill pipe @ 2700';Hauled 114 bbls to MP G&I for total=114 bbls Hauled 0 bbls to GPB G&I for total=0 bbls Hauled 515 bbls to B-50 for total=790 bbls Hauled 0 bbls from Vern Lake for total=0 bbls;Hauled 312 bbls from L-Pad Lake for total=534 bbls Hauled 0 bbls to ORT,total 120 bbls Daily losses 124 bbls,total=1310 bbls seawater • • Hilcorp Alaska, LLC Ilii urpAlaAa. l,1.d Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ-23A Doyon 14 50-029-22970-01-00 215-154 4/13/2016 Future 4/17/16-Sunday Continue to RU HES Cementers. Hold PJSM with crews.Squeeze CMT Below Retainer @ 7800'as Follows:Pump 10 bbls fresh water.Test lines to 3500 psi.Mix and Pump 295sx/60 bbls 15.8 ppg HALCEM(TM)SYSTEM CMT @ 3.5 bpm/425 psi.Pump Fresh water displacement @ 4.5 BPM avg/1150 psi, Caught cement @ 18 bbls away.Pumped total of 86 bbls Displacement.2 bbls over calculated.Final pump pressure 700 psi @ 2.8 BPM.Unsting from ret. Turn over to rig and pump 1 hole vol SW with no CMT returns.Break off head pin,load foam DP wiper.MU Head pin.Circulate DP volume+20 bbls to wipe ID of DP,7.5 bpm/1150 psi.Close pipe rams.Pressure test 7"casing from surface to retainer @ 7800'to 1800 psi and chart for 30 min.Good Test. Circulate DP Vol due to unbalanced fluid.Blow down and rig down circ equipment.POOH with Retainer running tool from 7800'.Lay down Retainer Running tool.PUW 125K/SOW 73K.Clean and clear rig floor.Stage Whipstock BHA components on rig floor.Prep to N/D and Install tubing spool.PJSM, Drain stack,de energize Koomey,N/D and Set stack aside.Install new tbg spool on top of existing tbg spool.N/U BOP stack,re-install kill line,riser and BOP anchors.PJSM,close blind ram,test spool flanges to 250 psi low/1750 psi high 5 min ea.M/U 4 1/2"test jt,install test plug,test upper and lower 2 7/8"VBR rams to 250 psi low/3000 psi high 5 min ea.Chart all tests.R/D test equipment.Record new stack measurements.Install 8.9375"ID wear bushing,Service rig,drawworks,inspect brake linkage.PJSM w/BOT,Sperry,rig crew for P/U Whipstock assembly as follows:M/U 6 1/8"window mill, lower 5 7/8"WM mill,flex jt,upper 6.151"WM mill,1-3 1/2"HWDP,FLT sub,DM and TM collar.Scribe window mill to MWD w/offset @ 325 deg,set assy to side,close blind ram,P/U WS with hoist,remove shipping bolt and 3 shear bolts on anchor,leaving 3 in w/anchor shear set @ 10695 ft/lbs.set WS in hole,M/U to mill w/25k brass shear bolt installed.open Blind ram.M/U XO,9-4 3/4"drill collars from drk and 1 std HWDP, Note:very easy in and out of slips w/run speed @ 50 fpm.Suface test MWD,good.Blow down top drive. RIH w/remaining 4 stds HWDP=822.93'TIH on elevators 50 fpm from 823'to 3100',slow in/out slips,fill pipe @ 2700'. 4/18/16-Monday TIH on elevators with Whipstock @ 50 fpm from 3100'to 7700',slow in/out slips.MU Top Drive,bring on pump @ 277 gpm/1380 psi.Orient Whipstock to 35 deg Left.RIH and tag Retainer @ 7801'. PUW 135K/SOW 85K w/no pump.Set down and shear Anchor Screws @ 12K. PU to 5K over verify WS set. Set back down 35K and shear Bolt.Anchor Set @ 7801'\TOW @ 7783'/BOW 7796'.PUH and lay down single.Displace well to 8.9 mud system @ 3 bpm/920 psi. Note:ditch magnets in place.Establish Milling Parameters. Mill window from 7783'to 7796'. 100 rpm/7-10 TO.,250 gpm/1200 psi,3-6K WOM.Pump Hi vis sweep as needed. AROP 3.25 fph milling window.Drill new formation from 7796'to 7827'making enough footage to get Geo steer BHA out window.Back ream window 2 times,shut off pump and make dry pass,Ream 1 more time 7k smooth torque and no wt.Park inside 7"casing @ 7772'condition mud for F.I.T.pumping 250 gpm,1200 psi until good 8.9 ppg MW in/out. Note:92 lbs metal recovered from milling window.Close annular.Perform F.I.T.to 12 ppg EMW with existing mud wt 8.9 ppg,apply 575 psi.Lost 35 psi in 10 sec,1 min 510 psi,5 min 475 psi, open annular. Note:pumped.81 bbl,.8 bbl bled back.Flow check well,static.Mix and Pump dry job,blow down top drive and choke.POH on elevators from 7772'to 805'@ HWDP.flow check well before pulling BHA,well static. Note:correct hole fill on trip out.Rack 4 stds HWDP in derrick,L/D 9-4 3/4"DCs,MWD tools,and window mill assy.Starter mill 1/4"out of gauge,string N mill in gauge.Load out BHA,clear rig floor.Load Geo-steer tools to rig floor. c)�� Monitor well with trip tank.P/U Geo-pilot,M/U 6 1/8"PDC bit. 4/19/16-Tuesday Continue to MU BHA#4:Bit,HDBS MM64 PDC/Geo-Pilot w/Stab/ADR/ILS/GM/PWD/DM/TM/Float sub.Upload MWD.Issues up loading.Circulate through ,ii)(" MWD @ 2 bpm/100 psi.Up load MWD with no further issues.Continue MU BHA:3 NM Flex Collars/XO Sub/1 jt HWDP/Jars/1 jt HWDP.total BHA Length= 275.33.TIH with Geo-Pilot picking up 4"HT38 DP from 275'to 1217'MU Top Drive/Fill pipe/Test MWD&Geo-Pilot with no issues.Blow down Top Drive. Continue to single in the hole Picking up 4"DP from 1217'to 5934'. Continue TIH f/5934'to 7726'w/stands from derrick,filling pipe every 20 stands.Park @ 7726'.Slip and cut Drill line.Establish parameters @ 7726'MD. 155k up,89k dn,105k rot,30 rpm,6k tq off. Obtain SPR's @ 7726'MD/3537'TVD(see pump data). TIH F/7726'-T/7827'MD. Clean through window. Drill 6-1/8"production hole F/7827'-T/8008'MD.Reduced rotating and pumping rate until MWD is off slide. Increase rot F/30 to 130 rpm,Inc pump F/ 232 to 288 gpm,w/1800 psi off,1830 psi on.181 ft @ 41 ft/hr avg rop. 6k tq off,6.5k tq on,11.0 ECD's.(10.7 clean hole ECD baseline). Build and turn as per WP03.Cont drilling build and turn F/8008'-T/8288'. 284 gpm,1858 psi on,1800 psi off,28%flow,145 rpm,6.5k tq,8k wob. Pump 25 bbl wt'd sweep w/condet&nut plug due to bit balling @ 8150.280 ft @ 47 ft/hr avg rop.Last svy @ 8122'-2.3'High,17'Right of plan. V Or T4F . yi).,\1�j�,s, THE STATE Alaska Oil and Gas ��,,;,s ��, of AL AS KA Conservation Commission t r-e_= 333 West Seventh Avenue u GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 04t, \rh Main: 907 279 1433 ALAS/1"t' SCANNEDFax 907 276 7542 i) - www.aogcc alaska gov Paul Chan ca V a/ti f�,O Senior Operations Engineer r Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ-23 Sundry Number: 315-537 Dear Mr. Chan: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ale4. Cathy P. oerster A Chair n.94DATED this 3 day of September, 2015 Encl. RBDMS' SEP 0 4 2015 ' . R E C E.W STATE OF ALASKA ,U U 2 8 7.015 ALASKA OIL AND GAS CONSERVATION COMMISSION D S V Z /S APPLICATION FOR SUNDRY APPROVALS A000C 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate El Pull Tubing 0 Operations shutdown 0 Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redril❑� - Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: 4 Current Well Class 5.Permit to Dri Number: Hilcorp Alaska,LLC - Exploratory ❑ Development Q 200-120 " 3.Address: Stratigraphic ❑ Service ❑ 8.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 50-020-22970-00-00• 7.If perforating: 114 8.Weil Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 477.0c Will planned perforations require a spacing exception? Yes 0 No MPJ-23 9.Property Designation(Lease Number) 10.Field/Pool(s) ADL 025517 • Milne Point Field/Schrader Bluff Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft). Plugs(measured): Junk(measured): 12,062' 4 3,783' • 12,126'• 3,783' . None None Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 8,865' 7" 8,892' 3,830' 7240 5410 - Liner 3,264' 4-1/2" 12,062' 3,783' 8430 7500 Liner Liner Perforation Depth MD(ft): Perforation Depth ND(ft) Tubing Size Tubing Grade: Tubing MD(R): 3-1/2"9 3# L-80 28'-793T Slotted Liner 8,798'-12,062'MD Slotted Liner 3,840'-3,781'ND 4-1/2"12.6# L-80 8573'-8814' Packers and SSSV Type: 3-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(It): -7,90d MD/3,579'ND Baker ML Torque Master Packer . 8,595'MD/3,773'TVD 12.Attachments Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development Rc Service [ All 14.Estimated Date for 15 Well Status after proposed work: 10/10/2015 �( Commencing Operations: OIL ❑ WINJ L WDSPL ❑ Suspended LI 16.Verbal Approval. Date GAS ❑ WAG ❑ GSTOR El SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pail Chan r Email pchan©hilcorp corn Printed Name Title Paul Chan , Senior Operations Engineer Signature APhone 907-777-8333 Date O (2"(j ST COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number. Plug Integrity r / 2 BOP Test V- Mechanical Integrity Test ❑ Location Clearance ❑ Other: . J cod {A 5‘' cc r C 1- (/'Y t J!' , /Z t r.0 / r 2 44c_ U• ei L 6> Spacing Exception Required? Yes ❑ No [( Subsequent Form Required /o 4/0 7- APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date 9_ 3 - l.5 fI' 3Ai fir IA., `j'-Z--( ' i / s 0 2015 ORIGINAL �/� RBDMS SEP 3 Submit Form and Form 10-403 Revised 5/2015 Approved application Is valid for 12 months from the date of approval. Attachments in Duplicate Current Bottom Hole Pressure: - 1,520 psi @ 4,000' TVD (Sentry Gauge 11/23/2010) Maximum Expected BHP: - 1,600 psi @ 4,000' TVD (RE estimate) Max. Anticipated Surface Pressure: - 1,200 psi @ 4,000'TVD (0.1 psi/ft gas gradient) Pre-Riq Operations O 1. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw one at a time for breakage O 2. PPPOT-IC ar PPPOT-T O 3. CMIT T x IA.'MIT OA 114,...1.c. S 4. Drift tubing. Pull jet pump. Ensure dummy in GLM #2 @ 2636' MD. Leave open pocket in GLM #1 @ 7783' MD as circ point. Drift well to maximum deviation. E 5. Cut 3-Y2" tubing in the middle of the 10' pup above the packer(-7891' MD - in between the Baker S-3 packer and the Baker Sentry gauge). Circ out well to seawater with diesel freeze protect. O 6. Set a BPV, remove the well house and level the pad in preparation for the rig move. 1. MIRU Nordic 2. Pull BPV. Circulate well with 8.5 ppg seawater and monitor well. Adjust brine weight if needed to kill well. Set TWC. 3. ND tree and adapter flange. NU 11" BOPE and test to 250 psi low/3,000 psi high, annular to 250 psi low/2,500 psi high. Pull TWC. Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness the test. 6`y ew4Ac b. With stack out of the test path, test choke manifold per standard procedure. c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. -741f well 45 1,xthere,, ov'l u','1' 61'f f(0 dvcfi pn odrog? 20 8o/p epri vutvi e' Cvr /e44,.91 ti ?9 t/L5, 41/ welt /0c re Atrl J( Skovld c ;r ,' IOb ed /eCOve from r1i f G// '' Q ,/i g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 5. RU spooling unit to handle 7854' of I-wire. Prepare to handle 251 Lasalle clamps. 6. PU landing joint/or spear and engage tubing hanger. BOLDS and unseat hanger. 7. Pull and lay down the 3-'/2" L-80 tubing down to the cut. Number ALL joints (do not include jewelry). 8. RIH with bit/scraper to top of tubing stub at 7891' MD. Circulate well clean. POOH. 9. RU a-line. Run GR/CCL with 6" bull nose or blind box to maximum depth (must have 6';OD on bottom to prevent tool from running beside tubing stub). If necessary, pump tool downhole. Correlate casing tally to GR/CCL. 10. RIH with 7" cement retainer. Set at 7800' MD. Set cement just above a casing collar. Pumpl 15.8 ppg Class G cement plug (from Baker flow guide at 8573' to cement retainer)to plug the Schrader Bluff 0 sands. 11. Unsting from cement retainer and circulate well clean at maximum rate. Set 10K down to confirm cement retainter is holding. PT plug to 1750 psi for 30 charted minutes. The whipstock will be set on top of the cement retainer. 12. POOH and RU to sidetrack the well. '' Tree: 3-1/8"FMC horizontal MP J-23 KB elev.=63.20' Wellhead:11"x 11"5M tbg.spool, DF elev.=62.20' FMC Horizontal tree Model 120 11"x 3.5"8 rd EUE(top&bottom) - GL elev.=35.80' FMC TBG HNG w/3.5"'H'BPV profile. 20" 110' J Tam port collar 1005' fl • 3.5"9.3#ppf,L-80 EUE 8rd tubing Camco 3.5"x 1" (drift ID=2.992",cap.=0.0087 bpf) sidepocket KBUG GLM 2636' 7"26 ppf,L-80,Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) KOP @' Max wellbore Angle:79"@'MD Hole angle through perfs=90 deg. Camco 3.5"x 1" 7783 i sidepocket KBUG GLM "Reverse Circulation"Jet Pump Configuration Produced FNM 1 - 0Y Baker"CMU"sliding sleeve I o — w/2.81"X nipple profile 7840' A. Baker sentry gauge(3567'tvd) 7854' ��) Baker S-3 packer(3.97"ID) 7900' %�� ,N I ' 1 3.5"HES"XN"Nipple 7925' 2.813"packing/2.75"No- --' WLEG 7937 I-- Raservotr Fluid Baker guide shoe' RA tag at 8456' Short joint 8539'(29.73') 0 Milled window from 8569'-8581' lit of slotted liner(39')8902'-8940' Baker 4.5"flow guide stock w/2.375" 8573' `75jts.of slotted liner(3000')(8981'-11981') , id Baker HR setting sleeve 8590' t Baker 7"ML torque master pkr 600-47 8595' WLEG 8614' pI�I .% 4.5"12.6#,L-80 IBT tubing. / Baker Float shoe at 12062' Baker HR sleeve w extension 8798' 4 Baker HMC liner hanger 8807' Z Halliburton float collar 8809' — — `S- Halliburton float shoe 8892' 111111 4.5"12.6#,L-80 IBT tubing. Baker Float shoe at 12126' 87jts.of Slotted liner(3402')(8680'-12082') 4-1/2"SLOTTED INTERVALS OA-8902'-8940'MD(39') OA-8981'-11981'MD(3000') OB-8680'-12082'MD DATE REV.BY COMMENTS MILNE POINT UNIT 10/08/00 M.Linder Initial completion by Doyon 141 WELL J-23 09/15/01 B.Hasebe Addition of Jet Pump flow schematic API NO: 50-029-22970 BP EXPLORATION (AK) • Tree: 3-1/8"FMC horizontal M P J-23 Post-Work KB elev.=63.20' Wellhead:11"x 11"5M tbg.spool, OF elev.=62.20' FMC Horizontal tree Model 120 11"x 3.5"8 rd EUE(top&bottom) GL elev.=35.80' FMC TBG HNG w/3.5"'H'BPV L profile. 20" 110' (} Tam port collar 1005' 0 3.5"9.3#ppf,L-80 EUE 8rd tubing (drift ID=2.992",cap.=0.0087 bpf) 7"26 ppf,L-80,Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) KOP©' Max wellbore Angle:79°@'MD Hole angle through perfs=90 deg. v ' ��� Cement Retainer @—7,800' ✓ C) _ Tubing Cut @ Baker S-3 packer(3.97"ID) 7900' 3.5"HES"XN"Nipple 7925' 2.813"packing/2.75"No- WLEG 7937' c, Baker guide shoe' RA tag at 8456' Shortjoint 8539'(29.73') O 6° „fes Milled window from 8569'-8581' 1jt of slotted liner(39')8902'-8940' Baker 4.5"flow guide stock w/2.375" 8573' 75jts.of slotted liner(3000')(8981'-11981') id • I O / Baker HR setting sleeve 8590' Baker 7"ML torque master pkr 600-47 8595' WLEG 8614' A % 4.5"12.6#,L-80 IBT tubing. Baker Float shoe at 12062' Baker HR sleeve w extension 8798' Baker HMC liner hanger —' _= 8807' — — — — 0.6 Halliburton float collar 8809' Halliburton float shoe 8892 —414 4.5"12.6#,L-80 IBT tubing. Baker Float shoe at 12126' 87jts.of Slotted liner(3402')(8680'-12082') 4-1/2"SLOTTED INTERVALS OA-8902'-8940'MD(39') OA-8981'-11981'MD(3000') OB-8680'-12082'MD DATE REV.BY COMMENTS MILNE POINT UNIT 10/08/00 M.Linder Initial completion by Doyon 141 WELL J-23 09/15/01 B.Hasebe Addition of Jet Pump flow schematic API NO: 50-029-22970 BP EXPLORATION (AK) Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on / both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. 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. ~ i~ O' -Jc:~O Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~~INDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYGWINDY Scanning Preparation _~ x30 =~'2_~ BY: BEVERLY ROBIN VINCENT SHERYL~INDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _.~ YES Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO IF NO IN STAGE 1, PAGE(S) DISCREP~~RE FOUND: YES NO BEVERLY ROBIN VINCENT SHERYL MAR~..~ DATE: ~""t ~'~ ~ RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. ., Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder ao d _ t c 9-, 0 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue „ n �— 9 :3 Anchorage, Alaska 99501 1 Y Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls 5 gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ - 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 -- -, 1 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 • • (IF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer BP Exploration (Alaska), Inc. A� P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Pool, MPJ -23 Sundry Number: 311 -367 Dear Mr. Lopez: ± : AN t U L U Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z day of November, 2011. Encl. TE OF ALASKA I,',v-�u I t�' E I ALASKA OIL AND CONSERVATION COMMISSION 1,- ii ; d : ;, I ; ) / )/ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 t412 t ii 8t G2c f:nng_ CfMMISSIOR 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Change Apprc�vedprq�gram ❑ Suspend Plug Perforations Perforate Pull Tubing ' 1r p ❑ g ❑ ❑ 9 ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ StimulateD Alter Casing ❑ Other: ALTERNATIVE SSV' El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 Exploratory ❑ 200 -1200 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22970 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ❑ MPJ -23 Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025517 MILNE POINT Field / SCHRADER BLUFF Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12062 3783.29 12060 ' 3783.24 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" . 28 108 ' 28 108 Surface 8865' 7" 26# L -80 ' 27 8892 - 27 3839 7240 5410 Liner 3264' 4 -1/2" 12.6# L -80 8798 12062 - 3822 3783 8430 7500 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.3# L -80 26 7937 - - 4 -1/2" 12.6# , L -80 - 8573 8614 Packers and SSSV Tvoe: 3 -1/2" Baker S -3 Packer Packers and SSSV MD and TVD (ft): 7900 3579 Baker ML Torque Master Packer 8595 3773 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/5/2011 Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title PE Signature /► Phone Date `� 564-5718 11/21/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 ( I - l 2 ' - 01 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 40 f f .,„ * N% a4('red f APPROVED BY j / Approved byf COMMISSIONER THE COMMISSION Date: Il l Z ` j ORIGINAL ( 3,g__. qt.:5(i, Form 10 -403 Revised 1/2010 Submit in Duplicate MPJ -23 200 -120 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPJ -23 10/8/00 SL 8,680. 12,082. 3,794.73 3,783.78 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • . Milne Point Unit Well J -23, PTD Number 2001200 Request for approval for an alternative surface safety valve system (SVS) BP Exploration (Alaska) Inc. (BPXA) requests approval to operate Milne Point Unit well J -23 with an alternative surface safety valve configuration. 20 AAC 25.265 (c)(1) requires a well's surface safety valve to be located within the vertical run of a well's tree. MPJ -23 is a reverse acting jet pump Schrader Bluff producing well equipped with a horizontal tree, see attached photos and P &ID. The flow of the well comes out of the well head horizontally through the master valve and then immediately through the surface safety valve prior to entering the flow line. The vertical run of the tree consists only of two swab valves and a tree cap. This wellhead configuration was installed to reduce the tree height and allow rig work without dismantling the flow line equipment. The flow line pressure transmitter is located in the well house downstream of the surface safety valve. The J -23 safety valve system is regularly tested and the tests are subject to witness by AOGCC inspectors when the well is operable. The safety valve system was last tested on 10/18/2009. Currently, the well is SI for reservoir management and classified as Not Operable since it is due for an MIT -IA. There are no known integrity issues and a MIT - IA and safety valve system test will be conducted upon placing back into service. 20 AAC 25.265 (o) provides for granting a variance to the regulation if it "provides at least an equally effective means of complying with the requirement ", or a waiver if it "does not promote waste, is based on sound engineering and geoscience principle, will not jeopardize correlative rights, and does not result in an increased risk to health, safety, or the environment, including freshwater ". This tree configuration provides an equally effective surface safety valve system. BPXA requests a waiver from 20 AAC 25.265 (c)(1) to allow continued operation of well MPJ -23 with the horizontal well configuration described above. Please direct any questions concerning this request to Keith Lopez, MPU lead PE at 564- 5718. • • • • • 1.060 , , 3.708 I,3 818 HEAT TRACE - �� �, CIW 'I'WIRE- 1 INI ^. 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Iw 01- R -2 ' 1 4.11E VIM SMUT A 9KCBLC 2612111611 TX MN /� 1 1 W 9A E 1X1 SPX AM aq SEEf 1:. .2-- CL -3 F - --- !� L M)L111O AS A TAO MEEK L j v� .�: C a SCPEBACIM5 SALLY. 4115115 SET • I CM -37223A DP111S 1101 OUT OF TES T. • SYSTEM 9MC1 011 MS ORA21Ne - M1/M 'i]. 'l1A W PSW A wee MNae WEtL 110. J SET • SET • J-23 P i , ? NOTE s) .Z"., 1'1 A mu vme 10 .. . .Y 0 PS1C ON ESN 1 F }111�� IIQFMD49 ••1440413 IC OA. 4:411101 BT y3 y1�. BAN. yy � It BAIL 1MV111111 N RN *PIMVN. 04EV1BN ARON WC BNYBIB NIUE PM W - 3 A ■151. O90 N REVIEW 19 p7 B. RI/ •111 PROCESS • 11144 018M1Q•h4N N © uew®BT INC BA1 PRODUCTION E7 PUMP WELL J-23 • Iyc.1 © ©� I :'= ARAM.. 2[stMltlEO¢► IN MS UP na MTA31 •m (SLAI M14 PIPING & INSTRUMENT DIAGRAM IC p •• C7 � .:II '11MUM 111114NN m *0 , QM 01.1.1 a MIMS ra grvBM MBSU ...1. s >o , , , EMIR AS c , MIN °"° • 1s CP 75f .,,1... P131P0.0.3.3 P.P.1-14J -B-.0.1 ✓ BM MOW 3 NI B• la Tau, ICE 1111111 I wax tA3C. YBC I 0,0.0.8 U NOM. AD., EN• 0.6 0 W r 8 I 7 I 6 5 ♦ 4 I 3 I 2 I 1 • Tree: 3-1/8" FMC horizontal tree • KB elev. 0' Wellhead: 11 "x11" 5Mtbg.spool, �� �_�� DF elev. = 62.20' FMC Horizontal tree Model 120 11 "x 3.5" 8 rd EUE (top & bottom) - GL elev. = 35.80' FMC TBG HNG w/ 3.5 "'H' BPV ik profile. 20" 1 110' Tam port collar 1 1005' I 0 3.5" 9.3# ppf, L -80 EUE 8rd tubing Camco 3.5" x 1" ( drift ID = 2.992 ", cap. = 0.0087 bpf) 2636' sidepocket KBUG GLM 7" 26 ppf, L -80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) KOP @ ' Max w ellbore Angle: 79" @ ' MD Hole angle through perfs = 90 deg. Camco 3.5" x 1" I 7783' sidepocket KBUG GLM "Reverse Circulation" Jel Pump Configuration ! Produced Fk)od `. 3 m ' LL • Baker "CMU" sliding sleeve a w /2.81 "X nipple profile 7840' Baker sentry gauge (3567' rid) 7854' I e I (_ Baker S -3 packer (3.97" ID) 7900' \\..\....s.......s.........._ : I I 1 i' y 3.5" HES '7W" Nipple 7925' 2.813" packing/ 2.75" No- WLEG 7937' Reservoir Fluid --/ Baker guide shoe ' RA tag at 8456' Short joint 8539' (29.73') D Milled window from 8569 %8581' 1jt of slotted liner (39') 8902' -8940' Baker 4.5" flow guide stock w/2.375" 8573' ` 75jts. of slotted liner (3000') (8981' - 11981') , id Baker HR setting sleeve 1 8590' Baker 7" ML torque master pkr 600 -47 I 8595' WLEG I 8614' i - - - 1 11 4.5" 12.6#, L -80 IBT tubing. a 0 Baker Float shoe at 12062' Baker HR sleeve w extension 8798' , Baker HMC liner hanger 8807' . Halliburton float collar 8809' - Halliburton float shoe 8892' - - - ....,14 4.5" 12.64, L - IBT tubing. Baker Float shoe at 12126' 87jts. of Slotted liner (3402') (8680'- 12082') 4 -1/2" SLOTTED INTERVALS OA- 8902' -8940' MD (39') OA- 8981' - 11981' MD (3000') OB- 8680'- 12082' MD DATE REV. BY COMMENTS MILNE POINT UNIT 10/08/00 M. Linder Initial completion by Doyon 141 WELL J -23 09/15/01 B. Hasebe Addition of Jet Pump flow schematic API NO: 50 -029 -22970 BP EXPLORATION (AK) -~. ~... ......., ~......, '... - -..-.. . " ....... ' - . . . . , MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001200 MD 12062 TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. MILNE PT UNIT SB J-23 Operator BP EXPLORATION (ALASKA) INC 3783 Completion Dat 10/7/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22970-00-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments 43 D D 10200 FINAL 10264,.~.-- FI NAL 43 43 43 12008 Open 8/2/2001 10200 43-12008 12008 Open 8/10/2001 10264/~t~-12008 12008 OH 7/2/2001 10200 43-12008 Digital Data 12008 oh 8/20/2001 10264(..~-12008 digital data Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ,~ Chips Received? ~ Analysis .~f../..N--~' R ~.c.P. iv~.d ? Daily History Received? Formation Tops ~)/N Comments: Compliance Reviewed By: Date: I0 ~,~.__~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7a' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPJ-23, AK-MM-00178 MPJ-23: LIS Data / Digital Log Images: 50-029-22970-00 1 CD Rom August 10, 2001 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: WELL LOG TRANSMITTAL To: State of Alaska August 1, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPJ-23, AK-MM-00178 1 LDWG formatted Disc with verification listing. API#: 50-029-22970-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: .RECEIVED ,4thieka ~l& ~ns.~n Afldtorage · STATE OF ALASKA ' ALASKa, .,,L AND GAS CONSERVATION COMI(. _DION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator ~7. Permit Number BP Exploration (Alaska)Inc. 200-120 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22970-00 4. Location of well at surface ..?-.~.: .............. .~ 9. Unit or Lease Name ! ~.'91".,;:?' ;'T ~ ~ "'"'"'""'""'='~ 2685' NSL, 3390' WEL, SEC. 28, T13N, R10E, UM 't ;...';i~. '"'::~ i LOC;",?~ON$ Milne Point Unit .,- . . ', At top of productive interval i ¥1~_/~ ~,, 2932' NSL, 5242' WEL, SEC. 29, T13N, R10E, UM ! --/-~ ' ~'-{:;~t. i' .' ~u ~" 10. Well Number At total depth !; '~'.~?:::::. L~ : ~:~ ' MPJ-23 2952' NSL, 3183' WEL, SEC. 30, T13N, R10E, UM i ...... ,~ ......... · 3:._[- _ .?-,.~.~,' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease'l~esignation ~nd Se~'i'~i' ~o. 11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 62.30' ADL 025517 12. Date Spudded 9/9/2000 113' Date T'D' Reached 114' Date cOmp'' Susp'' Or Aband' 9/22/2000 10/7/2000 115' water depth' if OffshOre N/A MSL II 16' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth Where SSSV set1 21. Thickness of Permafrost 12062 3783 FTI 12060 3783 ETI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, ABI, ABGR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 54.5# K-55 28' 108' 30" 260 SX Arctic Set (Approx.) 7" 26# L-80 / N-80 29' 8892' 9-7/8" 1100 sx Articset III, 542 sx Class 'G', 260 sx Arcticset Lite III 4-1/2" 12.6#" L-80 8798' 12062' 6-1/8" Uncemented Slotted Liner 24. Perforations pp. en to. P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s~ze Bna numDer) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 3-1/2", 9.3#, L-80 7937' 7900' MD TVD MD TVD 4-1/2", 12.6#, L-80 8573'- 8614' 8595' 8902' - 8940' 3840' - 3844' 8981'- 11981' 3844'-3781' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 112 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 20, 2000 Other (explain) - Jet Pumped Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED DEC 07 2000 Alaska 0il & Gas Cons. Commission /~n~,hnranp Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. NA 7943' 3590' NB 8066' 3622' NC 8185' 3655' NE 8256' 3675' NF 8434 3726' OA 8569' 3765' OB 8837' 3829' RECEIVED DEC 0 7 .000 A/aska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~, ~ Title Technical Assistant Date I~,,' ~:~'OO MPJ-23 200-120 Prepared By Name/Nurnbec Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL .i i::(.EiVt.D .. BP AMOCO Page I of 12 DEC 0 7 : 000 Operations Summa Report 'Alaska Oil & Gas Cons. Commission Legal Well Name: MPJ-223 Anchorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG ,Rig Name: DOYON 141 Rig Number: .Date ... Fr°'m - To. Hours .... Task.·' ' gu'b: 'Phase ' ' '" :Code ...... .... '~" '"'"""DeScriPU';n"0f0peraii0?... ..... : :':~':'"'" '"' ...... ..:.... ....... '.. · ............ 9/7/2000 18:00 - 00:00 6.00 MOVE PRE Rig down - Move rig Milne Point F-Pad to Milne Point J-pad 9/8/2000 00:00 - 09:00 9.00 MOVE PRE Finish moving rig from MPF-82 to MPJ-223 - Move over slot 23 & Rig up service lines 09:00 - 12:00 3.00 DIVRTR INT1 Accept rig 0900 hrs 9/8/00 - Nipple up 20" Diverter system with single 16" diverter line 12:00 - 17:30 5.50 DRILL INT1 Load pipe shed, strap & pick up 5" 19.5 'G' Drill pipe - stand back in derrick 17:30 - 18:00 0.50 DRILL INT1 Function test 20" Diverter system - witness of test waived by Mr. John Crisp of AOGCC 18:00 - 19:00 1.00 DRILL INT1 Pre-Spud meeting with both drill crews & service personnel at Milne Point base camp 19:00 - 00:00 5.00 DRILL INT1 Continue picking up 5" drill pipe, stand back in derrick 9/9/2000 00:00 - 00:30 0.50 DRILL INT1 Finished picking up a total of 96 stands 8913' of 5" 19.5 'G' drill pipe and racked in derrick. 00:30 - 01:30 1.00 DRILL INT1 Cut and slip 90' of drill line. 01:30 - 02:00 0.50 DRILL INT1 Service top drive. 02:00 - 03:30 1.50 DRILL INT1 Picked up 1030' of 3?" drill pipe and racked in derrick. 03:30 - 05:30 2.00 DRILL INT1 Made up 9-7/8" Hughes MXC-IMill tooth bit and Sperry 6?" motor w/ 9-5/8" stablizer sleeve - Adjust motor to 177 BH - Pick up Sperry MWD I GR / PWD - oriented MWD and UBHO sub 05:30 - 06:00 0.50 DRILL INT1 Pre-Spud meeting on rig floor - Fill hole with drill mud & Check for leaks - ok 06:00 - 00:00 18.00 DRILL INT1 Spud in at 108' and rotary drill to Kick off point at 300' - Kick-off at 275? azimuth build angle at 2? / 100' increasing to 3.5? 1 100 below 700' - Continue Directional drill to 1875' at 00:00 hrs - Art 7.5 hrs, Ast 7.0 hrs, Average Rop 122 ft/hr - maintain Viscosity 120 to 150 sec/qt- maintain mud wt. < 9.2 ppg 9/10/2000 00:00 - 02:30 2.50 DRILL INT1 Directional drill from 1875' to 2216' building angle at 3.57/100 02:30 - 03:00 0.50 DRILL INT1 Reciprocated and rotated pipe while circulating bottoms up at 2216' 03:00 - 04:30 1.50 DRILL INT1 Short trip 11 stands to 1130' - max drag 25K - TIH wash through tight spot at 2089' - wash 60' to bottom at 2216' - Lost 4? of angle from survey before short trip, due to washing out of soft formation 04:30 - 08:30 4.00 DRILL INT1 Directional drill 2216 to 2799' - Continue building angle - Survey at 2,734' showed 7.5? dog leg 08:30 - 10:00 1.50 DRILL INT1 Ream hole 2,650 to 2,740 attempt to wipe out some of dog leg - no SUCceSS 10:00 - 14:00 4.00 DRILL INT1 Directional drill 2,799 to 3,327' - Finish building angle to 74? at ? 2900' 14:00 - 14:30 0.50 DRILL INT1 Circulate bottoms up at 3,327' - Prepare to trip for BHA - At bottoms up shaker loaded with sand - Survey lost 4? of angle due to washing out of hole 14:30 - 17:00 2.50 DRILL INT1 Drill ahead 3,327 to 3,727' to get out of sand. Sand section drilling 600-800ft/hr. 17:00 - 20:30 3.50 DRILL INT1 Pump out of hole 3,727 to 850' at 220 to 300 gpm - Pooh without Printed: 11/28/2000 8:42:57 AM BP AMOCO E C I VP 2 of,2 Operations Summary Report DEC 0 7 2000 Ala~ka 0ii & Gas Cons. [;ommission Legal Well Name: MPJ-223 Anch0ra.~e Common Well Name: MPJ-223 Spud Date: 9'/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: SUb Phase . ' . Description of oPerati°ns. Date From-To Hours. Task Code ~.: . . 9/10/2000 17:00 - 20:30 3.50 DRILL INT1 pumping 850 to surface - 10 to 20K drag & some packing off noticed while pumping out of hole 20:30 - 21:30 1.00 DRILL INT1 Pull BHA - Lay down MWD & GR tool 21:30 - 23:30 2.00 DRILL INT1 Make up new bit, Adjust motor down to 1.157 BH - Pick up Sperry MWD / GR / Res I PWD - Orient MWD & program logging tools 23:30 - 00:00 0.50 DRILL INT1 Slip & Cut 220' of drill line due to bad line 9111/2000 00:00 - 00:30 0.50 DRILL INT1 Finish cutting bad drill line. 00:30 - 01:30 1.00 DRILL INT1 Ran in hole with drilling assembly. Worked through tight spot at 990'. Hit bridge at 1695'. Unable to work through bridge. 01:30 - 03:00 1.50 DRILL OTHR INT1 Pulled out of hole (wet) with BHA. Stood back MWD/LWD and motor. 03:00 - 03:30 0.50. DRILL OTHR INT1 Pick up 9-7/8" Smith roller cone hole opener & 9-7/8" stablizers placed at N/B, 30 & 60' 03:30 - 10:30 7.00 DRILL OTHR INT1 RIH and tagged bridge at 1695'. Worked through bridge and continued washing and reaming to bottom at 3726'. Reamed to bottom at 400-500 '/hr pumping 400 gpm and rotating at 90 rpm. 10:30 - 11:30 1.00 DRILL OTHR INT1 Pumped 35 bbls high vis weighted sweep and circulated around. Circulated around at 630 gpm at 1280 psi. Rotated pipe 100 rpm and reciprocated pipe 40' during circulation. Started second 35 bbl weighted high vis sweep and circulated around. Had only fair cutting with first sweep and no appreciable increase in cuttings with second sweep. 11:30 - 12:30 1.00 DRILL OTHR INT1 Pulled out of hole (wet) from 3726' to tight hole at 2093'. 12:30 - 14:30 2.00 DRILL OTHR INT1 Made up topdrive and backreamed from 2093'-1752'. Wiped tight spots several times to open hole. 14:30 - 16:30 2.00 DRILL OTHR INT1 Finished pulling out of hole (wet) and laid down BHA. 18:30 - 18:00 1.50 DRILL INT1 Make up BHA- Change jets in Bit to 3/18's 1/10 - Program Sperry GR / Res I PWD / MWD - Orient MWD - Sperry motor 6? with 9 5/8" stablizer sleeve 1.157 BH 18:00 - 20:30 2.50 DRILL INT1 TIH - Tag Bridge at 2435' - attempt to work through without pumping - no success - M/U top drive & wash through bridge - continue TIH - Check shot survey at 2980' - ok - Wash 60' to bottom - no fill 20:30 - 00:00 3.50 DRILL INT1 Directional drill 3,727 to 4,300' at 00:00 hrs - Art 1.75 hrs, Ast .5 hrs, Average Rop 255 fi/hr - Pumping 600 gpm 2200 psi, 100 rpm with 10,000 fi/lb torque - Maintain mud wt. <9.2 ppg 9/12/2000 00:00 - 05:00 5.00 DRILL INT1 Continue Directional drilling 4300 to 5175' - Maintain mud wt. < 9.2 ppg - slide as needed for directional control 05:00 - 06:00 1.00 DRILL INT1 Pump 35 bbl high vis weighted fiber sweep - Circulate around 06:00 - 09:00 3.00 DRILL INT1 Short trip 16 stands 5175 to 3626' - Backream 4880 - 4460 & 4180-3810' due to tight and swabbing hole Printed: 11/28/2000 8:42:57 AM RECEIVE D ;\ i... ~ L i ~' BP AMOCO DEC 0 7 ?0110~ge 3 of 12 . Operations Summary Report Naska 0ii & Gas Cons. Commission Annhnran~ Legal Well Name: MPJ-223 Common Well Name: MPJ-223 Spud Date: 9/912000 Event Name: DRILL+COMPLETE Start: 9~7~2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ......... Sub' ' ' .......... " of Operations ' Date From-To Hours. .Task 'Code Phase..'. .. DeScription.. "":" . :... i . , 9112/2000 09:00 - 14:30 5.50 DRILL INT1 ~ D~recbonal drill 5175 to 5944' - Pumping 596 gpm 2500 psi, 80 -100 rpm with 12,000 fi/lb torque 14:30 - 15:00 0.50 DRILL 'INT1 Circulate while change swab in mud pump 15:00 - 19:00 4.00 DRILL lINT1 Continue directional drilling 5944 to 6475' - Pumping 596 gpm 2500 psi - Torque 15,000 ft/Ib at 80 rpm 19:00 - 20:00 1.00 DRILL INT1 Circulate around weighted high vis fiber sweep 20:00 - 23:30 3.50 DRILL INT1 Short trip 21 stands 6475 to 4515' - Back ream 6125-5945, 5715-5620, 5430-5145' - due to tight hole & swabbing, Drag 30K - No problem above 4860' - Normal p/u 150k, s/o 70k - Block wt 40k 23:30 - 00:00 0.50 DRILL INT1 Directional drill 6475 to 6501' at 00:00 hrs - maintain mud wt. < 9.2 ppg- Using Baroid solids control van to aid solids removal- Pumping 596 gpm 2600 psi on bottom psi - ECD 10.0 ppg - Last 24 hrs Art 7.9 hrs, Ast 3.3 hrs, Average Rop 196 fi/hr 9/1312000 00:00 - 06:30 6.50 DRILL INT1 Directional drill 6,501 to 7,429' - Pumping 596 gpm 2600 psi - Rotating at 80 rpm with 21,000 ~ torque ~06:30 - 07:00 0.50 DRILL INT1 Circulate while changing shaker screens ;07:00 - 10:30 3.50 DRILL INT1 Continue directional drilling 7,429 to 7,775' - Maintain mud wt. < 9.2 ppg - Torque increasing to 24,000 fi/lb 10:30 - 12:30 2.00 DRILL INT1 Circulate high vis weighted fiber sweep around - Circulate two hole volume 12:30 - 15:30 3.00 DRILL INT1 Short trip 16 stands 7,775 to 6,320 - Pump out of hole 13 stands of new hole, Pull 3 stands of old hole without problems - TIH with no problem - P/u wt. 160, s/o 65, Block wt. 40K 15:30 - 00:00 8.50 DRILL INT1 Directional drill 7,775 to 8,650' at 00:00 hrs -last 24 hrs Art 6.0 hrs, Asr 2.0 hrs, Average Rop 268 fi/hr - Maintain mud wt. < 9.2 ppg - Flow rate 596 gpm 2800 psi - Torque 25,000 fi/lb at 80 rpm 9/14/2000 00:00 - 03:30 3.50 DRILL INT1 Continue Directional drilling 8,650 to 7" casing point at 8,895' - Start building angle at ? 8,600' at 6? / 100 build rate - Est 82? on bottom at Casing pt. 03:30 - 06:00 2.50 DRILL INT1 Pump High vis, Weighted, fiber sweep around, Circulate hole clean 2? hole volume at 596 gpm 2800 psi 06:00 - 09:00 3.00 DRILL INT1 Short trip 8,895 to 7,525' - 15 stands, Precautionary backream 13 stands, - Pull ok last two stands - TIH with no problem - wash to bottom - no fill - Drill 7' of new hole for casing rat hole to 8,902' 09:00 - 11:00 2.00 DRILL INT1 Circulate around high vis, weighted, fiber sweep - Circulate two hole volume 11:00 - 17:00 6.00 DRILL INT1 Pump slug - Pooh - sim, no correction - Take p/u, s/o, r/t wts. and rotating torque every 5 stands while pooh 17:00 - 19:00 2.00 DRILL INT1 Lay down MWD / LWD tools - drain & Lay down mud motor 19:00 - 20:00 1.00 DRILL INT1 P/u 9 7/8" Smith hole opener assembly with 9 7~8" stablizers at N/B, 30 & 60' 20:00 - 21:00 1.00 DRILL INT1 TIH with 5" drill pipe to 1967' 21:00 - 00:00 3.00 DRILL INT1 Ream with hole opener 1,967 to 3,500' at 00:00 hrs - Pumping 635 gpm 1300 psi, 100 rpm - Torque 10,000 fi/lb at 3,500' before any lubricate additions - Maintain mud wt. < 9.2 ppg with solids van and water- condition mud as reaming hole Lower YP to < 15 - Lower APl fluid loss to < 4cc 9/15/2000 00:00 - 17:00 17.00' DRILL INT1 Finish 9 7~8" hole opener run to TD at 8,902' - Pumping 635 -650 gpm 1800 psi, Rotating at 100 rpm with final torque of 23,000 fi/lb -Add 5% by volume of lubricants while reaming from 4,000' to 8,902'- Torque at TD did not decrease 17:00 - 20:00 3.00 DRILL INT1 Circulate hole clean - Circulate at 423 gpm while adding 12 lb/bls of Glass beads to mud in hole, torque increased from 23,000 to 25,000 Printed: 11/28/2000 8:42:57 AM K r'L.l: U BP AMOCO Page 4 of 12 DEC 0 7 000 Operations Summa Report Alaska 0il & Gas Cons. Commission , Legal Well Name: MPJ-223 Anchorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: Date'· From - To. Hours· . Task· SUb · Code Phase : Description of operations '·· . . . 9/15/2000 17:00 - 20:00 3.00 DRILL INT1 fi/lb - monitor well - Pump slug 20:00 - 00:00 4.00 DRILL INT1 Pooh stand back 5" drill pipe - Max drag off bottom 10K - Take p/u, s/o, r/t wts & torque reading every 10 stands - at BHA 00:00 hrs - Proper hole fill 9/16/2000 00:00 - 01:00 1.00 DRILL INT1 Lay down Hole opener BHA & Clear floor 01:00 - 02:30 1.50 CASE INT1 Rig up 7" 350 ton casing equipment and 20' long 350 ton bails 02:30 - 03:00 0.50 CASE INT1 Safety meeting with drill crew on running 7" Long string 03:00 - 06:00 3.00 CASE INT1 Run 74 jts 7" 26~ L-80 Btc-Mod casing - Make up Torque 9,000 fi/lb 06:00 - 06:30 0.50 CASE INT1 Precautionary circulate at ? 3,000' - 10 BPM 400 psi - Reciprocate pipe 06:30 - 09:00 2.50 CASE INT1 Continue running 7" 26~ L-80 Btc-Mod casing to ? 6,000' 09:00 - 10:30 1.50 CASE INT1 Precautionary circulate at 6,000' - 10 BPM 600 psi- Reciprocate pipe 10:30 - 13:00 2.50 CASE INT1 Continue Run 7" 26~ L-80 Btc-mod casing - make up FMC mandrell hanger & land casing at 8891' - Ran total 219 jts 8862' set at 8891' 13:00 - 16:00 3.00 CEMT INT1 Circulate and reciprocate 7" casing at 10 BPM 800 psi for two annular volume - Final down wt. 80K, Pick up wt. 225K - Safety meeting with drill crew on cement job 16:00 - 19:30 3.50 CEMT INT1 Test line to 3500 psi - Pump 75 bbls of Mud Push spacer mixed at 10.2 ppg - drop bottom plug - Pump ..1100 sx Arctic set III lite mixed at 10.7 ppg yield 4.44 cflsx 870 bbls of slurry Tailed with 542 sx Class 'G' mixed at 15.8 ppg Yield 1.16 cf/sx 112 bbls of slurry - full returns while cementing - Drop Top plug with 10 bbls of fresh water 19:30 - 20:00 0.50 CEMT INT1 Displace with rig pump at 10 BPM 1400 psi - No returns after shutting down to drop top plug - ClP at 2000 hrs 9/16/00 - Rig pump efficency 95.26% - Float ok - No cement to surface 20:00 - 21:00 1.00 CEMT INT1 Lay down cement head, Landing jt. and casing tools 21:00 - 22:30 1.50 CEMT INT1 Make up Tam combo tool on 3?" drill pipe - TIH slowly 22:30 - 23:30 1.00 CEMT INT1 Locate Tarn port collar at 1,004' - Verify sleeve closed with 1000 psi - Open sleeve - Circulate with 9.0 ppg mud - Circulated out 60 bbls of Cement spacer - No cement 23:30 - 00:00 0.50 CEMT INT1 Pump 100 bbls of fresh water ahead at 5 BPM 350 psi - Cement with Arctic set III lite mixed at 10.7 ppg at 00:00 hrs 9/17/2000 00:00 - 01:00 1.00 CEMT INT1 Finish cementing with 260 sx ^Sill lite mixed at 10.7 ppg - Yield 4.44 cf/sx - 205 bbls of slurry - pump cement until cement at surface - displace with 5 bbls of fresh water- 20 bbls 10.7 ppg cement to surface 01:00 - 01:30 0.50 CEMT INT1 Close Tam port collar - Verify with 1000 psi - P/u 10' - shear ball seat - Circulate with fresh water until clean 01:30 - 02:30 1.00 CEMT INT1 Pooh stand back 3?" drill pipe - Lay down Tam combo tool 02:30 - 06:00 3.50 BOPSUF INT1 Nipple down 20" diverter system & remove from cellar 06:00 - 07:00 1.00 WHSUR PROD1 Nipple up FMC SO x 11" 5,000# tubing head - Torque lock screws to 150 fi/lb - Test seal to 1,000 psi 07:00 - 11:30 4.50 BOPSUF PROD1 Nipple up 11" 5k x 13 5/8" 5K spacer spool & 13 5/8" 5,000~ Hydrill BOP stack - 3? rams bottom, Blind middle, 3? x 6" variable top 11:30 - 12:30 1.00 DRILL PROD1 Slip & Cut drill line 12:30 - 20:00 7.50 DRILL PROD1 Lay down 5" drill pipe from derrick 286 jts 20:00 - 00:00 4.00 DRILL PROD1 Change handling tools - Load pipe shed with 3?" 13.30 S-135 drill pipe - strap, rabbit & pick up ? 3500' - stand back in derrick- 37 stand in derrick 9/18/2000 00:00 - 06:00 6.00 DRILL PROD1 Set test plug. Test rams, choke line, annular and all surface equipment 250 psi. for 5 minutes and 2000 psi for 10 minutes. HCR on kill side did not test. 06:00 - 07:30 1.50 DRILL TEST PROD1 Change out HCR valve on kill side. 07:30 - 08:00 0.50 DRILL PROD1 Test HCR valve 250 psi -5 minutes and 2000 psi-10 minutes. Good test. Pull test plug and install 6? ID wear ring. Printed: 11/28/2000 8:42:57 AM BP AMOCO Page 5 of 12 DEC 07 2000 Operations Summa Report N ,ka 0il & Gas Cons. CommisSion Legal Well Name: MPJ-223 Anchorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: : ' .... "' ........... SUb '" .1' " ' .... "' " ,'Date From. To Hours Task Code, Phase DescriPtiOn of Operations ,,," 9/18/2000 08:00 - 11:00 3.00 DRILL PROD1 Pick up Sperry 4?" ABI motor wi 1.50? BH - M/U Sperry 4? GR / Res I MWD / PWD - Orient and program logging tools - Make up Smith 6 1/8" PDC bit with .557 TFA 11:00 - 18:00 7.00 DRILL PROD1 Trip in hole picking up 3?" drill pipe - fill pipe every 60 jts, Wash 80' to float collar at 8,809' 18:00 - 18:30 0.50 DRILL PROD1 Circulate bottoms up at 8,809' - 250 gpm 2600 psi 18:30 - 19:30 1.00 DRILL PROD1 Test 7" casing to 3500 psi for 30 minutes on chart - ok 19:30 - 21:00 1.50 DRILL PROD1 Drill float collar, Cement & shoe 8,809 to 8,891' - 250 gpm 2600 psi - 60 rpm 10,000 fi/lb torque 21:00 - 21:30 0.50 DRILL PROD1 Tag bottom at 8,902' - Drill 8,902 to 8,932' sliding high side 21:30 - 22:30 1.00 DRILL PROD1 Circulate bottoms up with bit at 8,895' - 250 gpm 2600 psi 22:30 - 23:00 0.50 DRILL PROD1 Preform FIT to 400 psi at 3,838' TVD with 9.0 ppg mud in hole - EMW 11.0 ppg - Ok 23:00 - 00:00 1.00 DRILL PROD1 Pump 35 bbls of Xanvis spacer at 9.1 ppg and displace to 9.1 ppg Baroid Baradrill drill in fluid - Clean fluid to surface at 00:00 hrs 9/19/2000 00:00 - 01:00 1.00 DRILL PROD1 Finish displacing well with 9.0 ppg Baradrill and clean pits. 01:00 - 02:30 1.50 DRILL PROD1 Directional drill 8932'-9006'. 02:30 - 03:00 0.50 DRILL PROD1 Pull back to casing shoe while geologist determined exactly where we were.. 03:00 - 18:30 15.50 DRILL PROD1 Directional drill "OB" sands 9006'-9945'. Art-6 hrs, Ast-3.75 hrs. Rop=96 Fph. 250 gpm with 2500 psi, 60 rpm, 8000 ff lbs torque. 18:30 - 19:30 1.00 DRILL PROD1 Circulate hole clean. 19:30 - 20:00 0.50 DRILL PROD1 Short trip to casing shoe. No problems. Max drag 5000 lbs. 20:00 - 20:30 0.50 DRILL PROD1 Service top drive 20:30 - 21:00 0.50 DRILL PROD1 Trip in hole, no problems. ~21:00 - 00:00 3.00 DRILL PROD1 Directional drill "OB" sands 9945-10,040". Art-1 hrs, Ast-.25 hrs. Rop=76 Fph. 250 gpm. with 2500 psi, 60 rpm, 8000 ft lbs torque. 9/20/2000 00:00 - 14:00 14.00 DRILL PROD1 Directional drill "OB" sands 10,040'-11,095'. Art-5.5 hrs, Ast-2.5 hrs. Rop=132 Fph. 250 gpm with 2500 psi, 60 rpm, 8000 ft lbs torque. 14:00 - 15:30 1.50 DRILL PROD1 Circulate hole clean 15:30 - 16:30 1.00 DRILL PROD1 13 stand wiper trip. No problems. Maximum drag 5-10,000 lbs. 16:30 - 00:00 7.50 DRILL PROD1 Directional drill "OB" sands 11,095'-11,315'. Art-3 hrs, Ast-1 hrs. Rop--55 Fph. 250 gpm with 2950 psi, 60 rpm, 10,000 ft lbs torque. 9121/2000 00:00 - 02:30 2.50 DRILL PROD1 i Directional drill "OB" sands 11,315'-11,334'. Art-1.0 hrs, Ast-1.5 hrs. ~ Rop=7.6 Fph. 250 gpm with 2950 psi, 60 rpm, 10,000 ft lbs torque. 02:30 - 03:30 1.00 DRILL PROD1 Circulate bottoms up. 03:30 - 04:30 1.00 DRILL PROD1 ~Pull 10 stands 04:30 - 06:00 1.50 DRILL PROD1 Pick up 30 jts hwdp and trip in hole. 06:00 - 07:30 1.50 DRILL PROD1 Drill to 11,334- 11,380'. Ast-1.5 hrs. Attempting to slide to build angle and cannot. While rotating ahead the angle is dropping. 07:30 - 09:00 1.50 DRILL PROD1 Circulate bottoms up while waiting on decision to trip out of hole. 09:00 - 15:00 6.00 DRILL PROD1 Trip out of hole recording rotating, pu,slack off and torque every 5 I stands in open hole. In cased hole data was recoreded every 10 ~stands. No hole problems or excessive drag tripping out. 15:00 - 16:30 1.50 DRILL PROD1 Download mwd and check bit. Bit was graded 3-1-CT-A-X-I-NO-PR 16:30 - 18:00 1.50 DRILL PROD1 I Service top drive and crown. Perform hazard assessment on wires and bolts on top drive. 18:00 - 19:00 1.00 DRILL PROD1 Make up new bit and load MWD. 19:00 - 22:00 3.00 DRILL PROD1 Trip in hole to casing shoe filling every 30 stands. 22:00 - 23:00 1.00 DRILL PROD1 Pump sweep and add 4% EP Mud Lube into mud. 23:00 - 00:00 1.00 DRILL PROD1 Ream from 8902'-9900'. Mad pass log for geologist. 9/22~2000 00:00 - 04:00 4.00 DRILL PROD1 Ream from 9900'-11,380'. Mad pass log for geology at 900 fph.. 04:00 - 15:00 11.00 DRILL PROD1 Directional drill "OB" sands 11,380-'12,060'. TD per geologist. Art-5.0 Printed: 11/28/2000 8:42:57 AM RECEIVED BP AMOCO' DEC 0 7~.00~age 6 of 12 Operations Summary Report Uaska0il & Gas Cons. Commission Anchorage Legal Well Name: MPJ-223 Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9~7~2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: Date . From - To .Hours Task (~(~dbe. 'ph'ase. ... .:... Description of OperatiOns : ... .. .: . 9~22~2000 04:00 - 15:00 11.00 DRILL PROD1 hrs, Ast-2.0 hrs. Rop=97 Fph. 250 gpm with 3150 psi, 60 rpm, 7,000 ft lbs torque. 15:00 - 17:00 2.00 DRILL PROD1 Circulate hole clean. Two bottoms up. 17:00 - 19:00 2.00 DRILL PROD1 Monitor well-static. Trip out of hole to casing shoe. Maximum drag 5-10,000. No problems. 19:00 - 20:30 1.50 DRILL PROD1 Drop ESS and pump down Trip in hole 9497' and take check shot for jorps. 20:30 - 23:00 2.50 DRILL PROD1 Mad pass 8900'-8300' for setting packer and whipstock. Maximum speed 300 fph. 23:00 - 00:00 1.00 DRILL PROD1 Pump dry job and pooh. 9~23~2000 00:00 - 03:00 3.00 DRILL PROD1 Pooh to bha. Download MWd. 03:00 - 04:00 1.00 DRILL PROD1 L/D MWD and motor. No ESS survey. 04:00 - 05:00 1.00 DRILL PROD1 M/U hole opener bha. 105:00 - 09:00 4.00 DRILL PROD1 Tih with hole opener assembly to casing shoe. 09:00 - 10:30 1.50 DRILL PROD1 Cut drill line and service top drive. 10:30 - 21:00 10.50 DRILL PROD1 Wash and ream to bottom with hole opener. The last 2000 'the torque increased from 5-6,000 ft lbs to 8-9,000 ft lbs. Rotated at 100 roms, 400-500 fph, 340 gpm with 3500 psi. 21:00 - 23:30 2.50 DRILL PROD1 Pump sweep around and circulate hole clean(no excessive cuttings). Spot 300 bbls new mud in open hole. 23:30 - 00:00 0.50 DRILL PROD1 Monitor well-static. Pooh recording data(up, down, rotating wt) every 5 stands. No hole problems, no excessive drag. 9124/2000 00:00 - 01:30 1.50 DRILL PROD1 Finish pooh to casing shoe recording data. No hole problems. 01:30 - 03:30 2.00 DRILL PROD1 Drop ESS and take check shot at 9754'. Pooh to casing shoe. 03:30 - 08:00 4.50 DRILL PROD1 Pump dry job and pooh recording data( up, .down, and rotating wts) every 10 stands. 08:00 - 09:30 1.50 DRILL PROD1 L/D hole opener bha and retrieve ESS. Good survey. 09:30 - 11 .'00 1.50 DRILL PROD1 Pick up and stand back 21 4-3~4" drill collars. 11:00 - 12:00 1.00 CASE PROD1 Rig up to run 4-1/2" slotted liner. Pre job safety meeting. 12:00 - 14:00 2.00 CASE PROD1 Make up and run 81 jts slotted liner. 14:00 - 19:00 5.00 CASE PROD1 Change elevators and run 2-7~8" inner string, space out and make up Baker liner hanger. 19:00 - 19:30 0.50 CASE PROD1 Circulate capacity of liner. 19:30 - 00:00 4.50 CASE PROD1 Run 4-112" liner on 3-1/2" drill pipe at 90 fpm. Started getting sticky on bottom while running drill collars. Only ran 3 stands of drill collars and switched back to drill pipe-taking too long with dog collars and backing out lift sub. 9/25~2000 00:00 - 00:30 0.50 CASE PROD1 Finish runnning liner and land on bottom. 00:30 - 01:30 1.00 CASE PROD1 Break circulation with good retutrns and drop ball. 01:30 - 02:00 0.50 CASE PROD1 Set liner hanger with 1800 psi and release setting tool at 2800 psi. Attempt to shear out ball but circulated with 4000 psi at 7bpm. 02:00 - 11:00 9.00 CASE PROD1 Pump dry job and pooh. L/D 2-7~8" inner string. 11:00 - 16:00 5.00 CASE PROD1 Test Bops. 250~2000 psi. Lou Grimaldi with AOGCC waived witnessing test. 16:00 - 16:30 0.50 CASE PROD1 Pull test plug and set wear ring. 16:30 - 18:00 1.50 CASE PROD1 Make up Baker Torque Master Packer Assembly and running tool 18:00 - 22:00 4.00 CASE PROD1 Trip in hole with packer assembly 22:00 - 00:00 2.00 CASE PROD1 Rig up Schlumberger and rih with GR logging tool. Could not get below 80' with the rollers. Pulled out of hole and removed rollers. Trip back in hole with GR logging tool. Sat down at 2700'. 9/26/2000 00:00 - 02:00 2.00 CASE PROD1 Attempt to pump down Gr logging tool. Pumped at I bpm with 330 psi. The tool only moved down hole from 2500'-2700'. Did not want to increase pump rate for fear of setting the packer off depth. Discussed Printed: 11/28/2000 8:42:57 AM g i" L I' I V l-, BP AMOCO Page 7 of 12 DEC 07 .000 Operations Summa Report Alaska 0ii & GaS Cons. Commission Legal Well Name: MPJ-223 Anchorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9~7~2000 End: 10/7/2000 ,Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ......... SUb.. ............ : ........................ . ,Date .From - To Hours Task Code Phase Description.of Operations, · 9/26~2000 00:00 - 02:00 2.00 CASE PROD1 situation with office and agreed to pooh with wireline and make a tie-in run with drill pipe only without packer. 02:00 - 07:00 5.00 CASE OTHR PROD1 Pump dry job and pooh with packer 07:00 - 07:30 0.50 CASE OTHR PROD1 Service rig and top drive. 07:30 - 10:00 2.50 CASE OTHR PROD1 Make up muleshoe and and ran in hole with RA sub in string for correlation to 8589'. 10:00 - 11:00 1.00 CASE OTHR PROD1 Slip and cut drill line. 11:00 - 14:00 3.00 CASE OTHR PROD1 Rigged up Schlumberger and ran in hole with GR/CCL tools. Logged RA in casing string at 8456' and found drill pipe RA to be 1' deep. Pulled out of hole with wireline tools. Rigged down and released Schlumberger. 14:00 - 16:30 2.50 CASE OTHR PROD1 Pulled out of hole with drill pipe. 16:30 - 20:30 4.00 CASE OTHR PROD1 Picked up Baker Torque Master Packer Assembly ( Wireline entry guide, 4-1/2" pup joint X 10' and 7" ML TorqueMaster packer 600-47 X 3.88") with setting tools and tripped in hole to setting depth. 20:30 - 21:30 1.00 CASE PROD1 Spaced packer on depth and dropped 1-7/16" ball and pumped down at 3 bpm. Slowed to 1 bpm to pump ball on seat. Pressured up to 1500 psi and set packer. Pulled 45K over and released pressure. Set 40K down to set slips. Picked up to neutral and rotated 20 rounds to the right to release from packer. Picked up and pressured to 3600 psi and blew out ball seat. Top of packer set at 8595' - No-Go at 8599'. .21:30 - 00:00 2.50 CASE PROD1 Pump dry job and pulled out of hole with setting tools. Laid out setting tool. 9~27/2000 00:00 - 01:30 1.50 CASE PROD1 Made up ML TMP Baker oreintation tool and oriented with MWD. Surface tested MWD. 01:30 - 04:30 3.00 CASE PROD1 Ran in hole with oreinting assembly on 3-1/2" drill pipe to packer. Stung into packer and recorded readings of 37L, 97L and 127L. Up weight 100K SOW 65K Rot weight 80K. 04:30 - 07:30 3.00 CASE PROD1 Pumped dry job and pulled out of hole with orienting assembly. 07:30 - 13:30 6.00 CASE PROD1 Picked up Baker WindowMaster Whipstock and adjusted anchor for highside orientation. Oriented whipstock with MWD and ran in hole to top of packer. 13:30 - 14:30 1.00 CASE PROD1 :Broke circulation and oriented whipstock. Latched into packer and sheared bolt. Mill wedged between whipstock and casing wall. Had to . pick up 10K over pick up weight and put 10K right hand troque in string i to free mill. 14:30 - 18:00 3.50 CASE PROD1 i Milled window from 8569'-8593'. Rot weight 85K, 130 RPM at 7500 ftlbs, WOB 1-3K. Printed: 11/28/2000 8:42:57 AM BP AMOCO DEC0 7 ~.000Page 8 of 12 Operations Summary Report aska0il & Gas Cons, COmmisSion Legal Well Name: MPJ-223 A,chorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: : .............. Hours Task' Sub' ' .' ..... : ..... : ...... : ' ' Date To Code Phase.. .. Description of Operations . 9/27/2000 18:00 - 20:00 2.00 CASE PROD1 Pumped 25 bbls weighted high vis sweep and circulated around. , Recovered approximately 25~ of metal cutting on ditch magnets and off of shaker screens. 20:00 - 22:30 2.50 CASE PROD1 Observe well. Pump slug and pulled out of hole with milling assembly. Stood back drill collars and laid down milling assembly. Mills in gauge. 22:30 - 00:00 1.50 CASE PROD1 Made up BHA #11-Picked up 6-1/8" Security PDC FM 2643 (4RR1), Motor adjusted to 1.57, MWD tools, orient and load MWD tools, NMDCs, Jars, and one stand of drill pipe. Surface tested MWD. 9/28~2000 00:00 - 01:30 1.50 DRILL PROD2 Finished making up BHA #11. 101:30 - 04:00 2.50 DRILL PROD2 Ran in hole with drill pipe filling the drill pipe every 30 stands. Oriented through whipstock. 04:00 - 07:00 3.00 DRILL PROD2 Directionally drill sliding straight up from 8593'-8751' to land in target sand. Landed 3.2' Iow to target line. WOB 3-5K and 210 gpm at 1750 psi. 07:00 - 21:30 14.50 DRILL PROD2 Directionally drill sliding and rotating as per geogolist from 8751 '-9615'. WOB 2-5K, 250 gpm {~ 2500 psi, 60 RPM at 5500 ftlbs torque. Displaced hole with new mud at 9000' while drilling ahead. Rot hrs 7.10 hrs Sliding hrs 6 hrs Total drilling hrs 13.10 hrs. 21:30 - 23:00 1.50 DRILL PROD2 Pumped 25 bbls high vis weighted sweep and circulated around. Circulating and conditioned hole 30+' off bottom. 23:00 - 00:00 1.00 DRILL PROD2 Made a wiper trip from 9615' to 8540' (Top of whipstock at 8599'). No problems. 9/29~2000 00:00 - 19:00 19.00 DRILL PROD2 Directional drill from 9615'- 11049' as per geologist. WOB 1-5K, 60 RPM at 6500 ftlbs torque, 250 gpm at 2700 psi. 19:00 - 20:30 1.50 DRILL PROD2 Pumped 25 bbls high vis sweep and circulated hole clean. Significant increase across shakers with sweep. 20:30 - 22:00 1.50 DRILL PROD2 Made a 15 stand wiper trip from 11049'-9600'. No problems with trip. Hole in good shape. 22:00 - 00'.00 2.00 DRILL PROD2 Directional drill from 11049'-11173'. Geosteering as per geologist. WOB 1-5K, 60 RPM ~ 7000 ftlbs torque, 250 gpm ~ 2830 psi. ART 17.93 hrs AST 4.09 hrs. 9/30/2000 00:00 - 17:30 17.50 DRILL PROD2 Directional drill from 11173'- 12127' as per the geologist. WOB 1-5K, 60 RPM at 7000 ftlbs of torque, 250 gpm at 3040 psi. ART 7.6 hrs AST 4.10 hrs. 17:30 - 20:00 2.50 DRILL PROD2 Pumped high vis sweep and circulated out and pumped additional high vis sweep and circulated out. Not much with second sweep. ECD 12.2 down to 11.9 after sweeps. Printed: 11/28/2000 8:42:57 AM ~\ LL. E. i V gL/ BP AMOCO DEC 0 7 )~Jtlll~age 9 of 12 Operations Summary Report Alaska 0il & Gas Cons.. Commission Anrhnr~na Legal Well Name: MPJ-223 Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG 'Rig Name: DOYON 141 Rig Number: · ·Date· Fr°m-To ·Hours, '.Task S~:b ..... COde Phase ... Description of OPerations:'. , : ~., . ,: ,,, ·. 9/30/2000 17:30 - 20:00 2.50 DRILL PROD2 20:00 - 21:00 1.00 DRILL PROD2 Check flow. Pumped dry job and pulled out of hole to top of whipstock. 21:00 - 23:00 2.00 DRILL PROD2 Drop ESS and pumped down same. Ran in hole to 9584' for check shots. Pulled back out of hole to 8300'. 23:00 - 00:00 1.00 DRILL PROD2 Circulated sweep out of hole. Check flow and pumped slug. 10/1/2000 00:00 - 02:30 2.50 DRILL PROD2 Check flow. Pump dry job and pulled out of hole with 3-1/2" drill pipe. 02:30 - 04:00 1.50 DRILL PROD2 Laid down ESS tool - good survey. Break bit and download MWD. Laid down MWD and motor. 04:00 - 04:30 0.50 DRILL PROD2 Picked up Hole opener and three point reamer bottom hole assembly. 04:30 - 07:30 3.00 DRILL PROD2 Trip in hole to top of window at 8550'. 07:30 - 08:30 1.00 DRILL PROD2 Cut and slip drill line. 08:30 - 21:00 12.50 DRILL PROD2 ' Ran in hole to 8581'. Washed and reamed from 8581' to TD at 12127'. Reaming parameters: WOB 0-5K, 100 RPM with rotary torque of 6000 ftlbs initially increasing with depth to 8000 ftlbs, 350 gpm at 3600 psi, reaming 400-500'/hr. 21:00 - 00:00 3.00 DRILL PROD2 Pumped 25 bbls weighted high vis sweep and circulated out. Pumped an additional 25 bbl weighted high vis sweep and circulated hole clean. Spotted 100 bbls of new mud in open hole. Check flow. Pumped slug. 10/2/2000 00:00 - 01:00 1.00 DRILL PROD2 Pulled slowly out of hole from 12127' to 10210' recording up, down and rotating weights every 5 stands. Hole not taking proper fill. Observed well. Hole static. 01:00 - 01:30 0.50 DRILL PROD2 Ran back in hole to bottom. 01:30 - 03:30 2.00 DRILL PROD2 Circulated bottoms up - no influx in wellbore. Spotted 100 bbls of mud treated with 4 drums lubetex in drillpipe. 03:30 - 05:30 2.00 DRILL PROD2 Pumped out of hole from 12127' to 8550' ( top of whipstock 8569'). 05:30 - 07:00 1.50 DRILL PROD2 Circulate 8 drums of EP Mudlube into annulus to assist with running liner. 07:00 - 07:30 0.50 DRILL PROD2 Service rig and top drive - dropped 1-3/4" rabbit. 07:30 - 12:00 4.50 DRILL PROD2 Pumped slug and pulled out of hole and laid down hole opener assembly. 12:00 - 12:30 0.50 CASE PROD2 Rigged up to run 4-1/2" slotted liner. Held pre job safety meeting. 12:30 - 13:30 1.00 CASE PROD2 Picked up Guide shoe and pack off assembly and made up 2 additional joints of slotted liner. While removing tubing tongs tong die fell out of tongs and went down hole. Tong die 4" long, 1" wide and 318" thick. Laid down tubing and rigged down tongs. Printed: 11128/2000 8:42:57 AM BP AMOCORF-CEIVE De ' ~g 10 of 12 Operations Summary Report DEC 07 2000 Legal Well Name: MP,1-223 Anchorage Common Well Name: MP,J-223 Spud Date: 9~9~2000 Event Name: DRILL+COMPLETE Start: 91712000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ' '~' ' ........... Sub ........... '" :"' .... :' · Date · Fro. m - To. Hours Task Code Phase . · 'Description of Operations ... .. . 1012/2000 12:30- 13:30 1.00 CASE PROD2 13:30 - 14:00 0.50 CASE JUNK PROD2 Pulled wear bushing and installed test plug. 14:00 - 17:00 3.00 CASE ,JUNK PROD2 Tested BOPE, annular and top drive to 250 psi Iow / 2000 psi high for 10 minutes. Right to witness test waived by AOGCC Inspector, ,John Crisp. 17:00 - 17:30 0.50 CASE JUNK PROD2 Pulled test plug and installed wear bushing. 17:30 - 21:00 3.50 CASE JUNK PROD2 Picked up 6" magnet fishing assembly with HWDP and drilling jars and ran in hole to 4500'. Test all valves on choke manifold 250 psi Iow/2000 psi high for 10 minutes while tripping in hole. 21:00 - 00:00 3.00 CASE JUNK PROD2 Pulled out of hole slowly. 10/312000 00:00 - 01:00 1.00 DRILL JUNK PROD2 Finished pulling out of hole slowly. Recovered tong die. Laid down fishing tools. 01:00 - 02:00 1.00 CASE JUNK PROD2 Rigged up casing tools and held PJSM. 02:00 - 06:00 4.00 CASE PROD2 Picked up 4-112" guide shoe, 4-1/2" blank casing and Baker packoff bushing. Ran 87jts of 4-1/2" L-80 IBT slotted liner and 2 jts of 4-1/2" 12.6~ L-80 IBT solid liner. 06:00 - 09:30 3.50 CASE PROD2 Ran 111 its of 2-718" Fox tubing for interstring. Tagged up on no-go and spaced out and picked up Baker HR setting tool. 09:30 - 10:00 0.50 CASE PROD2 Broke circulation and circulated liner volume. 10:00 - 15:00 5.00 CASE PROD2 Ran in hole with 4-1/2" slotted liner on 3-112" drill pipe to 12127' (recording pick up and slack off wt). 15:00 - 16:30 1.50 CASE PROD2 Broke circulation and circulated hole clean at 150 gpm at 1450 psi. 16:30 - 17:30 1.00 CASE PROD2 Dropped 1-1/4" ball and pumped down at 3 bpm and slowed rate to 1 bpm before bumping seat. Pressured up to 2500 psi to release liner. Picked up weight 105K. Setting tool operated properly. Pressured up to 3700 psi and shear ball seat. Top of 'CA' liner 8589' - 9' outside bottom of 7" window 17:30 - 19:00 1.50 CASE PROD2 Pooh slow with Baker HR setting tool & 2 3/8" interstring - 8 stands - hole not taking fill 19:00 - 20:00 1.00 CASE PROD2 Circulate bottoms up - no indication of influx - mud wt. 9.1 ppg in & out 20:00 - 00:00 4.00 CASE PROD2 Continue Pooh slowly - Baker setting tool at surface at 00:00 hfs 10/4/2000 00:00 - 01:00 1.00 CASE PROD2 Continue Pooh with Baker HR liner running tool and 2-7/8" interstring - stand back 3-1/2" drill pipe 01:00 - 04:00 3.00~ CASE PROD2 Lay down running tool and 110 jts interstring - Clear rig floor 04:00 - 05:00 1.00 FISH PROD2 Make up Baker fishing whipstock retrieving tool & fishing BHA with Sperry 4-3/4" MWD - Orient MWD 05:00 - 07:00 2.00 FISH PROD2 TIh with Fishing Assembly to +/- 2200' - Fill pipe and shallow test MVVD - MWD failed Printed: 11/28/2000 8:42:57 AM .PASO00 RECEIVp. Operations Summary Report DEC 0 7 2000 ~Legal Well Name: MPJ-223 A/aska Oil & Gas Cons. Commission Common Well Name: MPJ-223 sp~il~ra't~. 9/9/200o Event Name: DRILL+COMPLETE Start: 9~7~2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ..........Sub ........ DescriPtion_ Date From-'To HOurs Task Code .Phase of OPerations: .. . . 10/4/2000 07:00 - 08:00 1.00 FISH BHA PROD2 Pooh for MWD failure 08:00 - 09:30 1.50 FISH BHA PROD2 Change out Sperry MWD 09:30 - 13:00 3.50 FISH PROD2 TIH with Fishing assembly to 8550' - Fill pipe every 25 stands 13:00 - 13:30 0.50 FISH PROD2 Break circulation - Orient retrieving tool - Latch whipstock and pull free with 30K over 13:30 - 15:00 1.50 FISH PROD2 Circulate bottoms up - full returns - 9.1 ppg in & out 15:00 - 21:00 6.00 FISH PROD2 Pooh slowly with whipstock - Lay down jam & whipstock - Clear rig floor 21:00 - 22:00 1.00 STWHIP COMP Make up Baker flow thru hollow Guidestock onto running tool - secure with two 10k shear screws - Orient MWD 22:00 - 00:00 2.00 STWHIP COMP TIH with Guidestock on 3-112" S-135 drill pipe - +/- 6000' at 00:00 hrs 10/512000 00:00 - 02:00 2.00 STWHIP COMP Finished tripping in hole with guidestock assembly on 3? S-135 drill pipe to 8568'. 02:00 - 03:00 1.00 STWHIP COMP Orient tool face to high side and latch into packer. Attempt to shear off 'guidestock with 30K down. No visible indication of shear. Picked up and pulled 50K over string weight before snap out of packer 03:00 - 03:30 0.50 STWHIP COMP Stood back 3 stands of drill pipe and picked up 3 stands of 4-3/4" collars. 03:30 - 04:00 0.50 STWHIP COMP Orient tool face high side and latch into Baker ML packer. Attempt to shear off of guidestock. No indication of shearing off - Pull 30k over to pull free 04:00 - 10:00 6.00 STWHIP COMP Pulled out of hole standing back 3? drill pipe to inspect guidestock assembly. Retrieved guidestock setting tool. Guidestock left in hole set in ML packer as planned - Running tool was getting friction grip on guidestock top 10:00 - 11:00 1.00 STWHIP COMP Slip and cut drill line. 11:00 - 11:30 0.50 STWHIP COMP Service rig and top drive. 11:30 - 12:30 1.00 CLEAN COMP Make up 3?" drill pipe Mule shoe sub on Drill pipe -TIh 12:30 - 13:30 1.00 CLEAN TDRV COMP Repair link tilt on top drive 13:30 - 18:00 4.50 CLEAN COMP Continue TIH with 3?" drill pipe to 8,550' - Top of window 8,569' 18:00 - 18:30 0.50 CLEAN COMP Pre-Job safety meeting on displacing to Kcl brine water 18:30 - 20:00 1.50 CLEAN COMP Pump 35 bbls high vis spacer follow by 9.1 ppg Kcl brine water - Displace at 480 gpm 3400 psi - Rotate at 120 rpm, 7000 ft~ torque - pump total 540 bbls - Final NTU 125 20:00 - 21:00 1.00 CLEAN COMP Clean pits - Take on 200 bbls of Kcl brine in pits 21:00 - 00:00 3.00 CLEAN COMP Pooh lay down 3?" drill pipe 10/6/2000 00:00 - 06:30 6.50 CLEAN COMP Finish Pooh lay down 3 1/2" drill pipe and drill collars 06:30 - 07:00 0.50 RUNCOI~! COMP Pull wear bushing 07:00 - 08:30 1.50 RUNCOI~! COMP Rig up tubing tongs - Rig up TEC cable spooling unit 08:30 - 09:00 0.50 RUNCOI~! COMP Safety meeting with drill crew on running completion 09:00 - 18:00 9.00 RUNCOI~! COMP Make up Baker 7" x 4 112" S-3 packer & tail pipe assembly - Install Baker Sentry temp & pressure gauge one jt above packer - Run in Hole with completion, install LaSalle clamp every connection around 1/4" TEC cable 18:00 - 18:30 0.50 RUNCOI~ COMP Safety meeting with night drill crew on running completion 18:30 - 23:00 4.50 RUNCOI~ COMP Continue RIH with 3 1/2" 9.3~ L-80 Eue 8rd AB-Mod Class 'B' tubing completion - Total 249 its 7,777.3' Printed: 11/28/2000 8:42:57 AM BP AMOCO Page 12 of 12 .Operations Summa Report Legal Well Name: MPJ-223 Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: · Date From - To Hours Task Sub. · Phase .' · ' '· Description of OPerations Code 10/6/2000 23:00 - 00:00 1.00 RUNCOI~! COMP i Make up FMC Schrader Bluff producer tubing hanger with two dummy penetrator - Connect TEC line to hanger 10/7/2000 00:00 - 00:30 0.50 RUNCOI~ i COMP Finish Making up FMC Schrader Bluff 11"x 3 1/2" producer tubing hanger - Check TEC cable -ok - Land tubing string & Run in lock down screws 00:30 - 04:00 3,50 RUNCOI~I COMP Drop 1 1/4" ball on rod with roller with 2 7/8" GS fishing neck - Pump down with rig pump at 3 bpm 300 psi - Ball not reaching seat - pump total 8 tubing volume 04:00 - 06:00 2,00 RUNCOI~I COMP Rig Up HES ,105 wireline unit 06:00 - 08:00 2.00 RUNCOI~I COMP RIh with GS pulling tool & push ball & rod to 'XN' nipple at 7,924' 08:00 - 09:30 1.50 RUNCOI~! COMP With ball on seat- Pressure up tubing string to 3500 psi and set Baker S-3 permanent packer at 7,899' - Bled pressure to 3200 psi and test tubing for 30 minutes - lost 200 psi over 30 minutes Bled tubing to 2000 psi - Pressure up 7 x 3 1/2" annulus to 3500 psi - Test annulus for 30 minutes - lost 100 psi over 30 minutes - bleed off all pressure 09:30 - 10:00 0.50 RUNCOI~! COMP Pooh with slick line - Recovered ball & rod - R/D slick line unit 10:00 - 10:30 0.50 RUNCOI~! COMP Pressure up down annulus and shear RP valve at 2700 psi 10:30 - 11:30 1.00 RUNCOI~! COMP Lay down landing jt. Set Two way check valve - Test two way check from top to 1000 psi 111:30 - 13:00 1.50 RUNCOI~ ! COMP Nipple down and set back 13 5/8" BOP stack 13:00 - 18:00 5.00 RUNCOI~! COMP Nipple up FMC Schrader Bluff 11" 5K x 3 118" 5K tubing head adapter & 3 1/8" Horizontal tree - Test tree and Hanger to 5000 psi - Test failed - Replaced SBM seal and increase torque on lock down screws 450 to 500 fi/lbs- Re-Test hanger ok - pull two way check valve 18:00 - 22:00 4.00 RUNCOI~! COMP Rig up HB&R hot oil unit - Test lines 3000 psi - Pump 112 bbls of diesel down annulus taking returns out tubing - Allow diesel to U-Tubing to tubing string - Monitor well - Well flowing on both sides - SITP 150 psi, SICP 150 psi 22:00 - 00:00 2.00 RUNCOI~! COMP Install BPV with lubricator - Rig down lines - Secure well - Rig Released at 24:00 hrs 10/7/00 RECEIVED DEC 07 2000 Alaska Oit & Gas Cons. Commission Anchorage Printed: 11/28/2000 8:42:57 AM I IIIIIIUlfflllllllfflllllmlllBIl~lllfflfillgllffllllll 10202597451 North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-223 Surveyed: 22 September, 2000 SURVEY REPORT 10/16/2000 14:28:86 PM Your Ref: API-500292297000 Surface Coordinates: 6015082.24 N, 551926.95 E (70° 27' 07.0094" N, Kelly Bushing: 62.30ft above Mean Sea Level 149° 34' 34.7184" W) Survey Reft svy9624 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Reft API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (it) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -62.30 0.00 105.26 0.130 187.790 42.96 105.26 227.78 0.300 188.340 165.48 227.78 317.67 1.340 270.440 255.36 '317.66 413.33 3.520 268.810 350.93 413.23 504.38 4.640 280.670 441.75 504.05 596.38 6.720 272.070 533.29 595.59 690.23 10.760 276.000 626.03 688.33 783.88 12.680 275.100 717.73 780.03 873.55 14.260 274.000 804.93 867.23 967.08 16.540 272.970 895.09 957.39 1056.11 .19.120 276.440 979.84 1042.14 1153.27 21.700 277.200 1070.90 1133.20 1245.61 25.190 277.110 1155.60 1217.90 1338.69 28.860 273.880 1238.51 1300.81 1432.91 32.240 273.670 1319.64 1381.94 1526.27 34.550 272.250 1397.58 1459.88 1618.11 38.100 274.030 1471.56 1533.86 1711.92 41.610 276.080 1543.57 1605.87 1804.53 46.900 275.750 1609.88 1672.18 1898.72 49.330 276.670 1672.76 1735.06 1991.55 48.920 276.720 1733.51 1795.81 2084.77 49.840 276.830 1794.19 1856.49 2175.59 45.610 277.680 1855.27 1917.57 2269.37 47.600 277.010 1919.70 1982.00 0.00 N 0.00 E 0.12 $ 0.02 W 0.57 $ 0.08 W O.80 S 1.17 W 0.85 S 5.22 W 0.23 S 11.64 W 0.66 N 20.67 W 1.77 N 34.88 W 3.60 N 53.81 W 5.24 N 74.63 W 6.74 N 99.42 W 9.03 N 126.57 W 13.07 N 160.21 W 17.64 N 196.66 W 21.61 N 238.74 W 24.76 N 286.52 W 27.40 N 337.84 W 30.41 N 392.14 W 35.75 N 452.01 W 42.39 N 516.27 W 49.99 N 585.97 W 58.17 N 655.69 W 66.52 N 725.95 W 74.99 N 792~60 W 83.69 N 860.18 W Global Coordinates Dogleg Northings Eastings Rate (ftc) (ft) (°[lOOft) 6015082.24 N 551926.95 E 6015082.12 N 551926.93 E 6015081.67 N 551926.87 E 6015081.43 N 551925.78 E 6015081.35 N 551921.73 E 6015081.93 N 551915.31E 6015082.75 N 551906.27 E 6015083.77 N 551892.05 E 6015085.46 N 551873.11E 6015086.96 N 551852.28 E 6015088.28 N 551827.48 E 6015090.39 N 551800.31E 6015094.19 N 551766.65 E 6015098.51N 551730.17 E 6015102.19 N 551688.06 E 6015105.00 N 551640.25 E 6015107.28 N 551588.93 E 6015109.92 N 551534.60 E 6015114.83 N 551474.70E 6015121.04 N 551410.39 E 6015128.15 N 551340.64 E 6015135.84 N 551270.87E 6015143.70 N 551200.55 E 6015151.70 N 551133.85 E 6015159.94 N 551066.20 E 0.124 0.139 1.482 2.280 1.534 2.437 4.349 2.059 1.785 2.455 3.133 2.669 3.780 4.245 3.589 2.612 4.032 3.995 5.718 2.680 0.444 0.991 4.709 2.185 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 0.00 0.01 0.07 1.14 5.20 11.63 20.68 34.91 53.89 74.75 99.57 126.77 160.50 197.06 239.24 287.09 338.45 392.82 452.80 517.22 587.10 657.01 727.47 794.33 862.12 Comment Continued... 10/16/2000 14:28:57 PM - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: AP1-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim, Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~t) (ft) (ft) (ft) (fi) 2362.41 51,430 276,660 1980,10 2042,40 2455.25 56.460 275,710 2034,72 2097,02 2548,05 60.760 273,710 2083,05 2145,35 2641,47 62,200 271,430 2127,66 2189,96 2735.29 68.920 273,640 2166,46 2228,76 2827.00 71,980 274,080 2197,14 2259,44 2919,48 73,860 274,390 2224,30 2286,60 3011.54 73,950 270,040 2249,84 2312,14 3102,78 74,750 271,280 2274,45 2336,75 3196,66 73,730 270,640 2299,95 2362,25 3288,84 69.920 271,690 2328,70 2391,00 3381,41 69,840 271,370 2360,54 2422,84 3474,25 73,520 270,680 2389,72 2452,02 3566,92 77,070 270,650 2413,24 2475,54 3659,73 77,800 270,590 2433,43 2495,73 3745,86 76,160 270,850 2452,83 2515,13 3843,26 73,890 270,220 2478,00 2540,30 3935,71 71,680 271,850 2505,36 2567,66 4028,29 74,660 272,280 2532,16 2594,46 4121,88 75.210 271,580 2556,49 2618,79 4214,50 73.830 273,380 2581,21 2643.51 4307,21 73,980 274,380 2606,91 2669.21 4400,63 74,890 273,960 2631,98 2694,28 4493.54 73,130 272,800 2657,57 2719,87 4586,35 72,690 271,820 2684,85. 2747,15 92,11N 930,43W 100,17 N 1005,02W 106,64N 1083,95W 110,31N 1165,94W 114,13 N 1251,21W 119,95 N 1337,43W 126,48N 1425,59W 129,90 N 1513,95W 130,91N 1601,80W 132,43 N 1692,13W 134,20 N 1779,68W 136,52N 1866,57W 138,09 N 1954,67W 139,13 N 2044,29W 140,11N 2134,87W 141,16 N 2218,77W 142.04 N. 2312,86 W 143,63 N 2401,14 W 146,83 N 2489,69 W 149,87N 2580,01W 153,73N 2669,18W 159,75 N 2758,05W 166,30 N 2847,80W 171,57N 2936,96W 175,14 N 3025,60W Dogleg Rate (°llOOft) Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6015167,86 N 550995,90 E 4,126 932,57 6015175,41N 550921,25 E 5.481 1007.35 6015181,33 N 550842,28 E 4,985 1086,43 6015164,42N 550760,26 E 2,641 1168,49 6015187,65 N 550674,97E 7.476 1253,83 6015192,87 N 550588.71E 3,367 1340.17 6015198~8 N 550500,51 E 2,058 1428,47 6015201,58 N 550412.13 E 4.541 1516.89 6015201,99 N 550324.28 E 1.575 1604,74 6015202,87 N 550233,93 E 1,269 1695.08 6015204,03 N 550146,38 E 4,272 1782,64 6015205,75 N 550059,47E 0,336 1869.56 6015206,70 N 549971,36 E 4,026 1957,68 6015207,12 N 549881,74 E 3.831 2047,29 6015207,47N 549791,15 E 0,789 2137.86 6015207,94 N 549707,24E 1.927 2221.77 6015208,16 N 549613.16 E 2,413 2315.84 6015209,14 N 549524,86 E 2.924 2404.13 6015211,71N 549436,30 E 3,249 2492,73 6015214,13 N 549345,95 E 0,931 2583.10 6015217,36 N 549256,76 E 2.393 2672.35 6015222,77 N 549167,85 E 1.049 2761.35 6015228,69 N 549078.05 E 1,066 2851,24 6015233,34 N 548988,86 E 2.242 2940,51 6015236,30 N 548900.20 E 1.115 3029,21 Comment i'1'1 Continued,.. DriilQuest 1,05,05 10/16/2000 14:28:58 PM - 3 - Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northlngs Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 4678.79 73.690 270.000 2711.58 2773.88 4772.01 70.910 269.380 2739.92 2802.22 4864.65 73.180 270.820 2768.48 2830.78 4957.20 75.610 269.680 2793.37 2855.67 5050.47 76.340 270.610 2815.98 2878.28 5145.49 77.380 271.020 2837.58 2899.88. 5236.71 78.230 272.640 2856.85 2919.15 5328.80 77.090 271.820 2876.53 2938.83 5422.18 78.250 270.700 2896.47 2958~7 5514.00 77.100 271.520 2916.07 2978.37 5606.76 75.980 270.950 2937.66 2999.96 5699.25 76.780 270.050 2959.44 3021.74 5792.38 75.620 270.090 2981.66 3043.96 5884.09 76.160 269.380 3004.01 3066.31 5976.36 77.140 269.860 3025.32 3087.62 6069.82 76.250 270.200 3046.83 3109.13 6163.00 73.230 268.860 3071.35 3133.65 6255.12 73.500 269.530 3097.72 3160.02 6350.20 73.570 268.870 3124.67 3186.97 6441.64 77.280 269.390 3147.68 3209.96 6535.76 77.640 267.630 3168.11 3230.41 6628.67 75.800 269.240 3189.46 3251.76 6721.49 76.900 269.370 3211.36 3273.66 6814.72 76.750 269.560 3232.61 3294.91 6905.70 75.460 270.740 3254.46. 3316.76 176.55 N 3114.07W 6015237.08 N 548811.72 E 176.07N 3202.87W 6015235.99 N 548722.93 E 176.23 N 3290.99W 6015235.53 N 548634.81E 176.61N 3380.12W 6015235.29 N 548545.68 E 176.84N 3470.60W 6015234.89 N 548455.19 E 178.16 N 3563.12W 6015235.57N 548362.67E 181.01N 3652.24W 6015237.79 N 548273.54 E 184.51N 3742.13W 6015240.67N 548183.62 E 186.52 N 3833.33W 6015242.04 N 548092.41E 188.25 N 3923.01W 6015243.15 N 548002.71 E 190.20N 4013.20W 6015244.47 N 547912.51E 190.98 N 4103.09W 6015244.62 N 547822.63 E 191.09 N 4193.53W 6015244.10 N 547732.19 E 190.68 N 4282.47W 6015243.07N 547643.25 E 190.08 N 4372.24W 6015241.85 N 547553.48 E 190.13 N 4463.19W 6015241.26 N 547462.54 E 189.40N 4553.07W 6015239.91N 547372.66 E 188.16 N 4641.33W 6015238.05 N 547284.42E 186.89 N 4732.50W 6015236.15 N 547193.26 E 185.55 N 4820.97W 6015234.19 N 547104.80 E 183.16 N 4912.81W 6015231.16 N '547012.98 E 180.68 N 5003.19W 6015228.06 N 546922.61E 179.59N 5093.38W 6015226.33 N 546832.43E 178.74N 5184.16W 6015224.85 N 546741.67 E 178.97N 5272.47W 6015224.47N 546653.36 E Dogleg Rate (°ll00ft) 2.173 3.049 2.862 2.881 1.244 1.172 1.970 1.513 1.708 1.526 1.347 1.282 1.246 0.954 1.177 1.016 3.525 0.756 0.670 4.094 1.865 2.601 1.193 0.255 1.896 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 3117.69 32o6.44 3294.53 3383.64 3474.1o 3566.63 3655.78 3745.74 3836.96 3926.66 4016.87 4106.74 4197.15 4286.05 4375.77 4466.69 4556.52 4644.71 4735.81 4824.21 4915.96 5006.24 5096.37 5187.09 5275.37 Continued... 10/16/2000 14:28:58 PM - 4 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API-500292297000 Surveyed: 22 September, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 6999.83 74.040 271.960 3279.22 3341.52 7092.82 73.980 272.400 3304.83 3367.13 7187.05 74.390 272.640 3330.51 3392.81 7278.42 73.930 272.240 3355.45 3417.75 7371.47 74.860 272.850 3380.48 3442.78 7464.34 74.910 272.460 3404.70 3467.00 7557.35 75.110 272.100 3428.76 3491.06 7649.98 75.510 272.650 3452.25 3514.55 7741.75 75.110 272.040 3475.52 3537.82 7836.15 74.800 272.840 3500.03 3562.33 7928.53 74.950 273.660 3524.13 3586.43 8021.77 74.920 273.540 3548.36 3610.66 8114.44 73.980 271.630 3573.21 3635.51 8207.68 73.500 270.560 3599.32 3661.62 8300.18 73.220 272.720 3625.81 3688.11 8391.98 73.640 271.970 3651.99 3714.29 8485.58 73.270 271.090 3678.64 3740.94 8578.57 72.700 271.900 3705.85 3768.15 8671.15 76.580 272.140 3730.37 3792.67 8764.60 76.550 271.810 3752.08 3814.38 8809.66 78.350 270.800 3761.88 3824.18 8832.79 79.680 271.410 3766.28 3828.58 8881.53 80.420 273.890 3774.71 3837.01 8914.57 83.030 275.160 3779.46 3841.76 8943.34 88.030 274.470 3781.70 3844.00 181.11 N 5363.26 W 6015225.97 N 546562.56 E 184.51 N 5452.58 W 6015228.75 N 546473.21 E 188.49 N 5543.16 W 6015232.10 N 546382.61 E 192.24 N 5630.98 W 6015235.23 N 546294.76 E 196.22 N 5720.51 W 6015238.59 N 546205.21 E 200.37 N 5810.07 W 6015242.12 N 546115.62 E 203.94 N 5899.84 W 6015248.07 N 546025.82 E 207.66 N 5989.37 W 6015248.16 N 545936.28 E 211.29 N 6078.06 W 6015251.17 N 545847.56 E 215.17 N 6169.14 W 6015254.42 N 545756.45 E 220.23 N 6258.18 W 6015258.85 N 545667.38 E 225.88 N 6348.04 W 6015263.88 N 545577.49 E 229.91 N 6437.22 W 6015267.29 N 545488.28 E 231.62 N' 6626.71 W 6015268.38 N 545398.78 E 234.16 N 6615.29 W 6015270.29 N 545310.18 E 237.76 N 6703.21 W 6015273.28 N 545222.24 E 240.15 N 6792.90 W 6015275.05 N 545132.54 E 242.47 N 6881.79 W 6015276.75 N 545043.64 E 245.62 N' 6970.99 W 6015279.28 N 544954.42 E 248.75 N 7061.83 W 6015281.78 N 544863.56 E 249.75 N 7105.80 W 6015282.47. N 544819.58 E 250.19 N 7128.50 W 6015282.75 N 544796.88 E 252.41 N 7176.45 W 6015284.64 N 544748.91 E 254.99 N 7209.04 W 6015286.99 N 544716.30 E 257.40 N . 7237.61 W 6015289.20 N 544687.72 E Dogleg Rate (°/lOOft) 1.959 0.459 0.499 0.656 1.182 0.409 0.431 0.719 0.777 0.882 0.872 0.128 2.230 1.216 2.258 0.907 0.984 1.034 4.198 0.345 4.555 6.306 5.237 8.767 17.543 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 5366.19 5455.57 5546.22 5634.11 5723.72 5813.36 59o3.19 5992.78 6o81.55 6172.70 6261.84 6351.81 6441.o7 6530.58 6619.20 67o7,18 6796.90 6885.82 6975.07 7065.96 71o9.94 7132.65 7180.64 7213.29 7241.91 Continued,.. 10/16/2000 14:28:59 PM - $. DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eestings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8976.40 90.550 276.170 3782.11 3844.41 9008.67 91.790 275.240 3781.45 3843.75 9037.56 93.570 275.780 3780.10 3842.40 9072.69 93.450 272.600 3777.95 3640.25 9105.17 92.340 270.930 3776.31 3838.61 9134.08 91.110 269.780 3775.44 3837.74 9165.67 91.910 269.750 3774.61 3836.91 9199.22 93.390 270.380 3773.06 3835.36 9229.48 93.510 270.890 3771.24 3833.54 9263.56 90.060 271.690 3770.17 3832.47 9296.41 88.520 269.380 3770.58 3832.88 9326.37 90.120 269.020 3770.94 3833.24 9357.25 90.740 269.730 3770.71 3833.01 9393.59 91.970 270.800 3769.85 3832.15 9421.63 90.620 270.770 3769.21 3831.51 9452.85 90.310 271.190 3768.96 3831.26 9486.93 90.120 271.070 3768.83 3831.13 9516.37 90.130 270.540 3768.77 3831.07 9547.80 90.250 270.060 3768.66 3830.96 9582.52 90.120 270.410 3768.55 3830.85 9612.37 90.180 270.500 3768.47 3830.77 9644.38 89.020 269.220 3768.70 3831.00 9675.09 89.080 269.620 3769.20 3831.50 9707.26 90.980 268.210 3769.19 3831.49 9739.94 93.080 270.520 3768.03 3830.33 260.46 N 7270.52W 6015292.03 N 544654.79 E 263.67 N 7302.62W 6015295.02 N 544622.66 E 266.44N 7331.35W 6015297.59 N 544593.92 E 269.00 N 7366.31W 6015299.90 N 544558.94 E 270.00N 7398.74W 6015300.68 N 544526.51E 270.18 N 7427.63W 6015300.65 N 544497.61E 270.05 N 7459.21W 6015300.30 N 544466.04 E 270.09 N 7492.72W 6015300.11N 544432.52 E 270.42N 7522.93W 6015300.23 N 544402.32 E 271.19 N 7556.97W 6015300.76 N 544368.26 E 271.50 N 7589.82W 6015300.84 N 544335.42 E 271.08 N 7619.77W 6015300.21N 544305.47 E 270.74 N 7650.65W 6015299.66 N 544274.60 E 270.91N. 7686.98W 6015299.58 N 544238.27 E 271.29 N 7715.01W 6015299.77 N 544210.24 E 271.83 N 7746.22W 6015300.08 N 544179.02 E 272.50 N 7780.29W 6015300.52 N 544144.94 E 272.91N 7809.73W 6015300.72 N 544115.50 E 273.08 N 7841.16W 6015300.67 N 544084.07 E 273.22 N 7875.88W 6015300.57 N 544049.35 E 273.46 N 7905.73W 6015300.60 N 544019.50 E 273.38 N 7937.74W 6015300.30 N 543987.50 E 273.07 N 7968.44W 6015299.77 N 543956.80 E 272.46 N 8000.60W 6015298.94 N 543924.64 E 272.10 N 8033.26W 6015298.35 N 543891.99 E Dogleg Rate (°/lOOft) 9.194 4.803 6.438 9.042 6.168 5.823 2.534 4.794 1.728 10.392 8.451 5.474 3.052 4.486 4.816 1.672 0.659 1.801 1.574 1.075 0.362 5.396 1.317 7.355 9.549 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 7274.90 7307.07 7335.86 7370.88 7403.32 7432.21 7463.77 7497.27 7527.48 7561.53 7594.37 7624.30 7655.16 7691.48 7719.51 7750.73 7784.81 7814.24 7845.67 7880.38 7910.22 7942.22 7972.90 8005.03 8037.67 Comment r'rl Continued... 10/16/2000 14:28:59 PM - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: AP1-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 9774,08 91,850 270,720 3766,56 3828,86 9803,69 92,090 270,750 3765,54 3827,84 9833.50 90,920 271,060 3764,76 3827,06 9864.88 90.490 270,750 3764,38 3826,68 9898,28 90,490 270,580 3764,09 3826,39 9932,60 90,680 270,730 3763,74 3826,04 9965,42 90,920 270,300 3763,28 3825,58 9993,92 92,090 271,910 3762,53 3824,83 10030,33 92,950 272,740 3760,93 3823,23 10061.11 92,090 272,200 3759,58 3821,88 10090.19 91,660 271,830 3758,63 3820,93 10123,55 90,430 270,950 3758,02 3820,32 10156,26 90,310 270,710 3757,81 3820,11 10186,07 90.310 270,830 3757,65 3819,95 10219.39 89.940 270,610 3757,57 3819,87 10252,64 89,450 270,540 3757,75 3820,05 10281,16 89,450 270,150 3758,02 3820.32 10317,49 89.690 269,660 3758,30 3820,60 10349,13 89,690 269,260 3758,47 3820,77 10377,51 89,510 269,320 3758,67 3820,97 10407,44 90,620 268,360 3758,63 3820,93 10440,69 91,480 269,350 3758.02 3820,32 10472,14 91,420 269.220 3757,23 3819,53 10502,88 90,680 268,700 3756,66 3818,96 10536,21 90,430 268,710 3756,34. 3818,64 272,47N 8067,36W 6015298,48 N 543857,88 E 272,85 N 8096,95W 6015298,66 N 543828,29 E 273,32N 8126,75W 6015298,92 N 543798,49 E 273,81N 8158,12W 6015299,20 N 543767,11E 274,20N 8191,52W 6015299.35 N 543733,72 E 274,59 N 8225,83W 6015299,50 N 543699,40E 274,89 N 8258,65W 6015299,57N 543666,58 E 275,44N 8287,13W 6015299,92 N 543638,10 E 276,91N 8323,48W 6015301,14 N 543601,74E 278,24 N 8354,20W 6015302,25 N 543571,01E 279,26 N 8383,24W 6015303,07N 543541,96 E 280,07N 8416,59W 6015303,65 N 543508,61E 280,54 N 8449,29W 6015303,90 N 543475.90 E 280,94 N 8479,10W 6015304,09 N 543446,09 E 281,36 N 8512,42W 6015304,28 N 543412,77 E 281,69 N 8545,66W 6015304,38 N 543379,52 E 281,87N 8574,18W 6015304,35 N 543351,01 E 281,81N 8610,51W 6015304,04 N 543314,68 E 281,51N 8642,15W 6015303,52 N 543283,04 E 281,16 N 8670,53W 6015302,97 N 543254,67E 280,55 N 8700,45W 6015302.15 N 543224,75 E 279,89 N 8733,69W 6015301,26 N 543191,52 E 279,49N 8765,12W 6015300,65 N 543160,09 E 278,94N 8795,85W 6015299,87 N 543129,36 E 278,18 N 8829,17W 6015298,89 N 543096.05 E Dogleg Rate (°/lOOft) 3.650 0,817 4,060 1.689 0,509 0,705 1,500 6,982 3,281 3.298 1,950 4,533 0.820 0.403 1.292 1.489 1.367 1,502 1.264 0,669 4,903 3,944 0,455 2,942 0,751 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 8071,77 8101,36 8131,16 8162.53 8195,93 8230.24 8263,05 8291,54 8327,91 8358,66 8387.72 8421.07 8453.78 8483.59 8516,90 8550.15 8578.66 8614.98 8646.59 8674.95 8704.85 8738,05 8769,47 8800,17 8833,46 Comment Continued... 10/16/2000 14:29:00 PM - 7- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Easflngs Northings Easfings (ft) (ft) (ft) (ft) (ft) 10565.34 90.250 268.500 3756.17 3818.47 10600.29 90.060 267.430 3756.07 3818.37 10632.97 91.230 266.950 3756.71 3818.01 10663.26 90.980 266.890 3755.12 3817.42 10696.32 90.550 266.290 3754.68 3816.98 10729.16 90.370 268.290 3754.42 3816.72 10760.11 92.400 269.430 3753.67 3815.97 10791.81 92.030 270.160 3752.44 3814.74 10825.78 91.780 269.000 3751.31 3813.61 10855.31 91.850 268.460 3750.38 3812.68 10888.58 91.970 268.370 3749.27 3811.57 10920.92 91.910 268.250 3748.17 3810.47 10951.81 91.790 267.380 3747.18 3809.48 10984.13 91.780 266.830 3746.17 3808.47 11016.12 92.090 267.630 '3745.09 3807.39 11047.93 92.090 267.410 3743.93 3806.23 11082.00 92.520 270.060 3742.56 3804.86 11123~72 92.650 270.520 3740.68 3802.98 11142.03 92.150 270.110 3739.91 3802.21 11178.73 91.660 268.660 3738.69 3800.99 11209.49 91.970 269.250 3737.72 3800.02 11238.33 90.920 267.550 3736.99 3799.29 11280.93 91.910 270.700 3735.94 3798.24 11318.47 92.340 271.320 3734.55 3796.85 11351.12 91.050 272.180 3733.58 3795.88 277.47N 8858.29W 6015297.98 N 543066.93 276.23 N 8893.22W 6015296.49N 543032.01 274.63 N 8925.86W 6015294.66 N 542999.39 273.00 N 8956.10W 6015292.83 N 542969.16 271.04N 8989.10W 6015290.63 N 542936.18 269.48 N 9021.90W 6015288.85 N 542903.39 268.87N 9052.83W 6015288.02N 542872.46 268.76 N 9084.51W 6015287.68 N 542840.78 268.51N 9118.46W 6015287.20 N 542806.84 267.85 N 9147.97W 6015286.34 N 542777.34 266.93 N 9181.20W 6015285.19 N 542744.10 265.98 N 9213.51W 6015284.01N 542711.80 264.80 N 9244.36W 6015282.62 N 542680.96 263.17 N 9276.63W 6015280.76 N 542648.71 261.63N 9308.56W 6015278.99 N 542616.79 260.25 N 9340.32W 6015277.40 N 542585.04 259.50 N 9374.35W 6015276.41N 542551.01 259.71N 9416.03W 6015276.33 N 542509.34 259.81N 9434.32W 6015276.30 N 542491.04 259.42N 9471.00W 6015275.65 N 542454.37 258.86 N 9501.74W 6015274.88 N 542423.64 258.05 N 9530.55W 6015273.87 N 542394.82 257.40N 9573.13W 6015272.92 N 542352.25 258.06 N 9610.64W 6015273.32 N 542314.74 259.06 N 9643.26W 6015274.09'N 542282.12 Dogleg Rate (°/lOOft) 0.949 3.109 3.87O 0.849 2.233 6.115 7.522 2.580 3.491 1.843 0.451 0.415 2.842 1.701 2.681 0.691 7.874 1.145 3.530 4.168 2.166 6.927 7.749 2.009 4.748 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 8862.55 8897.43 8930.02 8960.20 8993.14 9025.88 9056.79 9088.45 9122.38 9151.86 9185.06 9217.33 9248.14 9280.35 9312.23 9343.94 9377.94 9419.61 9437.89 9474.55 9505.26 9534.05 9576.59 9614.10 9646.74 Comment Continued... 10/16/2000 14:29:01 PM -8- DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sperry-Sun Drilling Services Survey Report for MPJ-223 . Your Ref: API.-500292297000 Surveyed: 22 September, 2000 Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (fi) 11377.93 90.370 270.070 3733.25 3795.55 259.58 N 9670.06 W 11409.20 91.970 270.810 3732.61 3794.91 259.82 N 9701.32 W 11441.42 93.140 271.470 3731.17 3793.47 260.46 N 9733.50 W 11473.21 93.020 271.390 3729.46 3791.76 261.26 N 9765.24 W 11504.18 93.570 272.100 3727.68 3789.98 262.20 N 9796.14 W 11536.65 93.570 271.660 3725.66 3787.96 263.26 N 9828.53 W 11567.40 93.390 271.650 3723.80 3786.10 264.15 N 9859.21 W 11598.38 91.290 271.040 3722.53 3784.83 264.87 N 9890.15 W 11631.10 90.550 270.860 3722.01 3784.31 265.42 N 9922.86 W 11662.78 90.180 270.660 3721.80 3784.10 265.84 N 9954.54 W 11695.13 89.690 270.530 3721.84 3784.14 266.17 N 9986.89 W 11727.87 92.160 271.130 3721.31 3783.61 266.65 N 10019.62 W 11760.09 93.260 272.360 3719.79 3782.09 267.63 N 10051.79 W 11793.42 91.480 273.040 3718.41 3780.71 269.20 N 10085.05 W 11824.07 91.050 272.250 3717.73 3780.03 270.61 N 10115.66 W 11855.70 90.120 271.290 3717.41 3779.71 271.59 N 10147.27 W 11887.36 89.630 271.360 3717.48 3779.78 272.32 N 10178.92 W 11919.59 89.200 271.010 3717.81 3780.11 272.98 N 10211.14 W 11951.41 88.890 270.870 3718.34 3780.64 273.51 N 10242.96 W 11985.19 88.580 270.320 3719.09 3781.39 273.86 N 10276.73 W 12062.00 88.580 270.320 3720.99 3783.29 274.29 N 10353.51 W 6015274.43 N 542255.31 E 6015274.45 N 542224.05 E 6015274.87 N 542191.87 E 6015275.44 N 542160.13 E 6015276.17 N 542129.22 E 6015277.00' N 542096.82 E 6015277.68 N 542066.13 E 6015278.19 N 542035.19 E 6015278.50 N 542002.47 E 6015278.70 N 541970.79 E 6015278.81 N 541938.44 E 6015279.06 N 541905.71 E 6015279.81 N 541873.54 E 6015281.15 N 541840.26 E 6015282.35 N 541809.65 E 6015283.11 N 541778.03 E 6015283.62 N 541746.37 E 6015284.06 N 541714.15 E 6015284.36 N 541682.33 E 6015284.48 N 541648.56 E 6015284.37 N 541571.77 E Dogleg Rate (°ll00ft) 8.268 5.637 4.168 0.453 2.897 1.352 0.586 7.058 2.328 1.328 1.567 7.764 5.118 5.716 2.934 4.226 1.563 1.720 1.069 1.869 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 9673.54 97o4.8o 9736.99 9768.73 9799.65 9832.05 9862.75 9893.70 9926.41 9958.09 9990.44 ~- 10023.17 o 10055.35 ~ 10088.64 ~ lO119.28 1015o.91 10182.56 10214.79 10246.61 10280.37 lO357.14 Projected Continued... 10/16/2000 14:29:01 PM - 9 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-223. Northings and Eastings are relative to MPJ-223. Alaska State Plane 4 Milne Point MPJ The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-223 and calculated along an Azimuth of 271.540° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12062.00ft., The Bottom Hole Displacement is 10357.14ft., in the Direction of 271.518° (True). Comments Measured Station Coordinates Depth TVD Northings Eastinge (fi) (fi) (ft) (ft) 0.00 0.00 0.00 N 0.00 E 12062.00 3783.29 274.29 N 10353.51 W Comment All Surveys are MWD+IIFR tool type Projected Survey Continued... 10/16/2000 14:29:03 PM - 10- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 12062.00 Vertical Depth (ft) 3783.29 Survey Tool Description AK-6 BP_IFR-AK 10/16/2000 14:29:04 PM - 11 - DrillQuest 1.05,05 I llllllBllll~llilllllllllllllllllllllRIIl~llllll~llll 1O2O2597448 North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-223 MWD Surveyed: 22 September, 2000 SURVEY REPORT 17 October, 2000 Your Ref: API-500292297000 Surface Coordinates: 6015082.24 N, 551926.95 E (70° 27' 07.0094" N, Kelly Bushing; 62.30ft above Mean Sea Level 149° 34' 34.7184" W) _ Survey Ref: svy9547 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -62.30 0.00 105.26 0.130 187.790 42.96 105.26 227.78 0.300 187.790 165.48 227.78 317.67 1.340 270.310 255.36 317.66 413.33 3.520 268.580 350.93 413.23 504.38 4.640 280.510 441.75 504.05 596.38 6.720 271.970 533.29 595.59 690.23 10.760 276.060 626.03 688.33 783.88 12.680 275.260 717.73 780.03 873.55 14.260 274.200 804.93 867.23 967.08 16.540 273.170 895.09 957.39 1056.11 19.120 276.660 979.84 1042.14 1153.27 21.700 277.490 1070.90 1133.20 1245.61 25.190 277.360 1155.60 1217.90 1338.69 28.860 274.090 1238.51 1300.81 1432.91 32.240 273.880 1319.64 1381.94 1526.27 34.550 272.500 1397.58 1459.88 1618.11 38.100 274.360 1471.56 1533.86 1711.92 41.610 276.080 1543.57 1605.87 1804.53 46.900 276.080 1609.87 1672.17 1898.72 49.330 277.050 1672~6 1735.06 1991.55 48.920 277.160 1733.50 1795.80 2084.77 49.840 277.290 1794.19 1856.49 2175.59 45.610 277.680 1855.27 1917.57 2269.37 47.600 277.050 1919.70 1982.00 0.00 N 0.00 E 0.12 $ O.O2 W 0.57 $ O.08 W 0.80 S 1.16 W 0.87 $ 5.22 W 0.27 $ 11.63 W 0.60 N 20.67 W 1.71 N 34.88 W 3.58 N 53.81 W 5.29 N 74.62 W 6.87 N 99.41 W 9.26 N 126.55 W 13.45 N 160.17 W 18.19 N 196.59 W 22.33 N 238.66 W 25.66 N 286.43 W 28.5O N 337.73 W 31.79 N 392.02 W 37.29 N 451.87 W 44.13 N 516.11 W 52.16 N 585.77 W 60.84 N 655.42 W 69.74 N 725.62 W 78.49 N 792.23 W 87.21 N 859.81 W Dogleg Rate (°/lOOff) Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6015082.24 N 551926.95 E 0.00 6015082.12 N 551926.93 E 0.124 0.01 6015081.67 N 551926.87E 0.139 0.06 6015081.43N 551925.79 E 1.485 1.14 6015081.34 N 551921.74 E 2.280 5.19 6015081.89 N 551915.32 E 1.537 11.62 6015082.69 N 551906.27 E 2.434 20.68 6015083.71N 551892.06 E 4.353 34.91 6015085.44N 551873.11 E 2.057 53.88 6015087.01N 551852.29 E 1.783 74.74 6015088.42N 551827.49 E 2.455 99.56 6015090.62 N 551800.34 E 3.135 126.75 6015094.57 N 551766.69 E 2.672 160.47 6015099.06 N 551730.23 E 3.780 197.01 6015102.91N 551688.13 E 4.252 239.18 6015105.90 N 551640.34 E 3.589 287.02 6015108.38 N 551589.02E 2.604 338.38 6015111.30 N 551534.71 E 4.047 392.73 6015116.38 N 551474.82E 3.921 452.71 6015122.78 N 551410.54 E 5.712 517.11 6015130.32N 551340.83 E 2.691 586.96 6015138.51N 551271.11 E 0.451 656.82 6015146.92N 551200.86 E 0.993 727.23 6015155.20 N 551134.19 E 4.668 794.05 6015163.46 N 551066.55 E 2.177 861.84 Comment Continued... 17 October, 2000- 22:02 - 2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth -(f t) 2362.41 51.430 276.490 1980.10 2455.25 56.460 275.900 2034.72 2548.05 60.760 273.880 2083,05 2641.47 62.200 271.260 2127.66 2735.29 68.920 273.550 2166.46 2827.00 71.980 273.960 2197.14 2919.48 73.860 274.010 2224.30 3011.54 73.950 269.590 2249.84 3102.78 74.750 270.970 2274.45 3196.66 73.730 270.580 2299.95 3261.95 73.300 271.050 2318.48 3288.84 69.920 271.890 2326.96 3381.41 69.840 271.520 2358.80 3474.25 73.520 270.620 2387.98 3566.92 77.070 270.540 2411.50 3659.73 77.800 270.310 2431.69 3745.86 76.160 273.160 2451.10 3843.26 73.890 272.690 2476.26 3935.71 71.680 273.630 2503.62 4028.29 74.660 272.650 2530.43 4121.88 75.210 272.290 2554.75 4214.50 73.830 274.430 2579.47 4307.21 73.980 274.810 2605.18 4400.63 74.890 273.980 2630.24 4493.54 73.130 273.770 2655.84 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2042.40 95.55 N 930.07W ' 2097.02 103.63N 1004.66W 2145.35 110.35 N 1083.57W 2189.96 114.02N 1165.56W 2228.76 117.64N 1250.84W 2259.44 123.31N 1337.06W 2286.60 129.45 N 1425.25W 2312.14 132.23 N 1513.63W 2336.75 132.66 N 1601.48W 2362.25 133.88 N 1691.83W 2380.78 134.77N 1754.43W 2389.26 135.42N 1779.93W 2421.10 138.01N 1866.81W 2450.28 139.65 N 1954.91W 2473.80 140.55 N 2044.53W 2493.99 141.23 N 2135.11W 2513.40 143.76 N 2218.98W 2538.56 148.56 N 2312.94W 2565.92 153.43N 2401.11W 2592.73 158.27N 2489.58W 2617.05 162.17 N 2579.87W 2641.77 167.39 N 2668.97W 2667.48 174.57 N 2757.76W 2692.54 181.46N 2847.48W 2718.14 187.50 N 2936.59W Dogleg Rate (°/lOOft) Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6015171.30 N 550996.23 E 4.142 932.30 6015178.87 N 550921.59 E 5.442 1007.08 6015185.04 N 550842.63 E 4.992 1086.14 6015188.13 N 550760.62E 2.906 1168.20 6015191.16 N 550675.32 E 7.499 1253.55 6015196.23 N 550589.05 E 3.363 1339.90 6015201.75 N 550500.83 E 2.034 1428.21 6015203.91N 550412.43 E 4.614 1516.64 6015203.73 N 550324.58 E 1.700 1604.47 6015204.33 N 550234.23 E 1.158 1694.81 6015204.78 N 550171.62 E 0.954 1757.41 6015205.26 N 550146.12 E 12.914 1782.93 6015207.24 N 550059.22 E 0.385 1869.85 6015208.26 N 549971.10 E 4.069 1957.96 6015208.54 N 549881.48 E 3.832 2047.57 6015208.58 N 549790.90 E 0.823 2138.14 6015210.53 N 549707.02 E 3.744 2222.04 6015214.68 N 549613.02 E 2.377 2316.10 6015218.93 N 549524.82 E 2.580 2404.37 6015223.16 N 549436.32 E 3.374 2492.94 6015226.43 N 549346.01 E 0.695 2583.30 6015231.03 N 549256.87 E 2.679 2672.50 6015237.59 N 549168.04 E 0.426 2761.45 6015243.86 N 549078.27 E 1.297 2851.33 6015249.27 N 548989.12 E 1.907 2940.57 Comment I:2> Continued... 17 October, 2000 - 22:02 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API.500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4586.35 72.690 269.450 2683.12 2745.42 4678.79 73.690 267.630 2709.86 2772.16 4772.01 70.910 269.200 2738.20 2800.50 4864.65 73.180 270.990 2766.76 2829.06 4957.20 75.610 269.600 2791.65 2853.95 5050.47 76.340 270.500 2814.26 2876.56 5145.49 77.380 267.810 2835.86 2898.16 5236.71 78.230 266.840 2855.13 2917.43 5328.80 77.090 266.530 2874.81 2937.11 5422.18 78.250 267.120 2894~5 2957.05 5514.00 77.100 268.310 2914.35 2976.65 5606.76 75.980 269.260 2935.94 2998.24 5699.25 75.980 269.420 2958.35 3020.65 5792.38 75.980 269.360 2980.91 3043.21 5884.09 75.980 269.610 3003.13 3065.43 5976.36 75.980 270.340 3025.48 3087.78 6069.82 75.980 270.930 3048.12 3110.42 6163.00 73.230 269.600 3072.86 3135.16 6255.12 73.500 271.210 3099.23 3161.53 6350.20 73.570 271.070 3126.18 3188.48 6441.64 77.280 269.440 3149.19 3211.49 6535.76 77.640 267.980 3169.63 3231.93 6628.67 75.800 269.420 3190.97 3253.27 6721.49 76.900 269.380 3212.87 3275.17 6814.72 76.750 269.440 3234.12 3296.42 189.99 N 3025.24W 187.74N 3113.70W 185.27N 3202.46W 185.43N 3290.58W 185.88 N 3379.71W 185.96 N 3470.19W 184.59 N 3562.70W 180.43N 3651.77W 175.23 N 3741.58W 170.17 N 3832.66W 166.60 N 3922.29W 164.68 N 4012.48W 163.65N 4102.21W 162.69 N 4192.56W 161.89 N 4281.53 W 161.85 N 4371.05 W 162.85 N 4461.72 W 163.27 N 4551.55W 163.90 N 4639.81W 165.71N 4730.97W 166.10 N 4819.45W 164.03 N 4911.30W 161.97 N 5001.69W 161.03 N 5091.88W 160.09 N 5182.66W 6015251.15 N 548900.45 E 6015248.27 N 548812.01 E 6015245.19 N 548723.27 E 6015244.73 N 548635.16 E 6015244.56 N 548546.03 E 6015244.01 N 548455.54 E 6015242.00 N 548363.04 E 6015237.22 N 548274.01E 6015231.39 N 548184.24 E 6015225.70 N 548093.19 E 6015221.50 N 548003.59 E 6015218.96 N 547913.42E 6015217.30 N 547823.70 E 6015215~1N 547733.35 E 6015214.29 N 547644.39 E 6015213.62 N 547554.87 E 6015214.00 N 547464.19 E 6015213.79 N 547374.37 E 6015213.80 N 547286.11E 6015214.98 N 547194.93 E 6015214.75 N 547106.46 E 6015212.04 N 547014.62 E 6015209.35 N 546924.25 E 6015207.78 N 546834.06 E 6015206.21N 546743.30 E Dogleg Rate (°/lOOft) 4.474 2.173 3.386 3.063 2.998 1.220 2.966 1.396 1.281 1.387 1.781 1.565 0.168 0.063 0.264 0.768 0.612 3.256 1.700 0.159 4.409 1.562 2.489 1.186 0.173 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 3O29.26 3117.62 3206.28 3294.37 3383.48 3473.94 3566.38 3655.30 3744.93 3835.85 3925.35 4015.46 4105.12 4195.42 4284.34 4373.82 4464.49 4554.29 4642.54 4733.72 4822.17 4913.93 5004.24 5094.37 5185.09 Comment Continued... 17 October, 2000 - 22:02 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD -Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northings Eestings Northings Eastings (ft) (ft) (ft) (ft) (ft) 6905.70 75.460 270.490 3255.97 3318.27 6999.83 74.040 272.040 3280.73 3343.03 7092.82 73.980 272,190 3306.35 3368.65 7187.05 74.390 272.810 3332.03 3394.33 7278.42 73,930 272,030 3356.97 3419.27 7371.47 74.860 272,010 3382.00 3444.30 7464.34 74.910 270.600 3406.21 3468.51 7557.35 75.110 271.070 3430.27 3492.57 7649.98 75.510 271.770 3453.76 3516.06 7741.75 75.110 271.974 3477.03 3539.33 7836.15 74,800 272.909 3501.54 3563.84 7928.53 74.950 273.343 3525.64 3587.94 8021.77 74,920 273.605 3549.88 3612.18 8114.44 73.980 271.807 3574.72 3637.02 8207.68 73.500 271.016 3600.83 3663.13 8300.18 73.220 273.960 3627.32 3689.62 8391.98 73.640 272.933 3653.50 3715.80 8484.58 73.270 272.372 3679.87 3742.17 8578.57 72,700 273.096 3707.38 3769.68 8671.15 76,580 272,650 3731.90 3794.20 8764.60 76,550 272.048 3753.61 3815.91 8809.66 78.350 270,304 3763.40 3825.70 8832.79 79.680 270.896 3767.81 3830.11 8914.57 83.030 275.570 3780.10 3842.40 8943,34 88.030 273,400 3782.35 3844.65 160.04N 5270.97W 6015205.54 N 546654.99 E 162.04N 5361.76W 6015206.91N 546564.19 E 165.34N 5451.09W 6015209.59 N 546474.84 E 169.29 N 5541.67W 6015212.91N 546384.23 E 173.00 N 5629.49W 6015216.01N 546296.39 E 176.16 N 5719.05W 6015218.54 N 546206.81E 178.20 N 5808.68W 6015219.96 N 546117.16 E 179.51N 5898.52W 6015220.64 N 546027.32 E 181.73 N 5988.09W 6015222.24 N 545937.73 E 184.63 N 6076.81W 6015224.52 N 545848.99 E 188.52N 6167.89W 6015227.77 N 545757.89 E 193.38 N 6256.94W 6015232.01N 545668.81E 198.83N 6346.81W 6015236.84 N 545578.90 E 203.05 N 6435.98W 6015240.44N 545489.70 E 205.26 N 6525.47W 6015242.02 N 545400.21E 209.10 N 6614.00W 6015245.25 N 545311.65 E 214.39N- 6701.82W 6015249.92 N 545223.79 E 218.50 N 6790.49W 6015253.41N 545135.09 E 222.79 N 6880.27W 6015257.07N 545045.29 E 227.26 N 6969.41W 6015260.92 N 544956.12 E 230.98 N 7060.23W 6015264.02 N 544865.28 E 231.88 N 7104,20W 6015264.61N 544821.31 E 232.12 N 7126.90W 6015264.69 N 544798.60 E 236.69 N 7207,59W 6015268.70 N 544717.88 E 238.93 N 7236.17W 6015270.74 N 544689.28 E Dogleg Rate (°/100ft) 1.807 2.191 0.168 0.768 0.963 1.000 1.467 0,533 0.849 0,486 1.011 0.482 0.274 2.127 0.963 3.064 1.165 0.705 0.955 4.217 0.627 5.498 6,274 6.979 18.935 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 5273.37 5364.18 5453.56 5544,21 5632.1o 5721,72 5811.37 59Ol.21 599o.81 6079.58 617o.73 6259.88 6349.86 6439.12 6528.62 6617.23 67o5.16 6793.91 6883.77 6973.00 7063.88 71o7.86 713o.56 7211.35 7239.98 Continued... 17 October, 2000- 22:02 -5- Dr#1Quest 1.05,05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Messured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 8976.40 90.550 276.040 3782.76 9008.67 91.790 275.780 3782.10 9037.56 93.570 275.620 3780.75 9072.69 93.450 272.310 3778.59 9105.17 92.340 271.020 3776.95 9134.08 91.110 269.940 3776.08 9165.67 91.910 269.290 3775.25 9199.22 93.390 270.580 3773.70 9229.48 93.510 270.560 3771~88 9263.56 90.060 271.470 3770.82 9296.41 88.520 269.280 3771.22 9326.37 90.120 268.730 3771.58 9357.25 90.740 269.170 3771.35 9393.59 91.970 270.500 3770.49 9421.63 90.620 270.940 3769.86 9452.85 90.310 271.070 3769.80 9486.93 90.120 270.980 3769.47 9516.37 90.180 270.590 3769.40 9547.80 90.250 270.200 3769.28 9582.52 90.120 270.200 3769.17 9612.37 90.180 270.500 3769.09 9644.38 89.020 268.980 3769.31 9675.09 89.080 268.560 3769.82 9707.26 90.980 268.190 3769.80 9739.94 93.080 270.680 3768.65 Vertical Local Coordinates Global Coordinates Depth Northings Eestings Northings Eastings (fi) (fi) (ft) (ft) (ft) 3845.06 241.65 N 7269.11W 6015273.23 N 544656.33 E 3844.40 244.97N 7301.20W 6015276.33 N 544624.21E 3843.05 247.84N 7329.92W 6015279.00 N 544595.48 E 3840.89 250.26 N 7364.89W 6015281.18 N 544560.49 E 3839.25 251.21N 7397.32W 6015281.89 N 544528.06 E 3838.38 251.45N 7426.21W 6015281.93 N 544499.16 E 3837.55 251.24N 7457.79W 6015281.50 N 544467.59 E 3836.00 251.20 N 7491.30W 6015281.23 N 544434.08 E 3834.18 251.50 N 7521.50W 6015281.32 N 544403.87 E 3833.12 252.10 N 7555.56W 6015281.69 N 544369.81E 3833.52 252.32N 7588.40W 6015281.67 N 544336.97 E 3833.88 251.80 N 7618.35W 6015280.94 N 544307.02 E 3833.65 251.23N 7649.23W 6015280.16 N 544276.15 E 3832.79 251.1'3 N 7685.56W 6015279.80 N 544239.83 E 3832.16 251.48 N 7713.59W 6015279.96 N 544211.79 E 3831.90 252.03 N 7744.80W 6015280.29 N 544180.58 E 3831.77 252.64N 7778.87W 6015280.66 N 544146.50 E 3831.70 253.04N 7808.31W 6015280.86 N 544117.06 E 3831.58 253.26 N 7839.74W 6015280.86 N 544085.63 E 3831.47 253.38 N 7874.46W 6015280.74 N 544050.91E 3831.39 253.56 N 7904.31W 6015280.71N 544021.06 E 3831.61 253.41N 7936.32W 6015280.34 N 543989.06 E 3832.12 252.76 N 7967.01W 6015279.47 N 543958.36 E 3832.10 251.84 N 7999.17W 6015278.33 N 543926.21 E 3830.95 251.52 N 8031.82W 6015277.78 N 543893.56 E Dogleg Rate (°/lOOft) 11.039 3.926 6.186 9.411 5.236 5.661 3.263 5.849 0.402 10.469 8.149 5.647 2.462 4.984 5.064 1.077 0.617 1.340 1.261 0.374 1.025 5.973 1.381 6.017 9.963 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 7272.98 7305.15 7333.93 7368.96 7401.40 7430.29 7461.85 7495.35 7525.55 7559.60 7592.44 7622.37 7653.22 7689.53 7717.56 7748.78 7782.85 7812.29 7843.71 7878.42 7908.27 7940.26 7970.93 8003.05 8035.68 0 r'1'1 '-4 __., o o Continued... 17 October, 2000 - 22:02 - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API-500292297000 Sun, eyed: 22 September, 2000 North Slope Alaska Measured Depth (it) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) . (ft) (ft) (ft) (ft) 9774.08 91,850 270,930 3767,18 9803,69 . 92,090 270,950 3766,16 9833,50 90,920 271,260 3765,38 9864,88 90,490 270,870 3764,99 9898,28 90,490 270,660 3764,71 9932,60 90,680 270,820 3764,36 9965,42 90,920 270,340 3763,90 9993,92 92,090 271,980 3763,15 10030,33 92,950 272,820 3761,55 10061,11 92,090 272,370 3760,19 10090,19 91,660 271,900 3759,24 10123.55 90,430 271.030 3758,63 10156,26 90,310 270,730 3758,42 10186,07 90,310 270,900 3758,26 10219,39 89,940 270,690 3758,19 10252,61 89,450 270,540 3758,37 10281,16 89,450 270,270 3758,64 10317,49 89,690 270.200 3758,91 10349,13 89,690 269,320 3759,08 10377,51 89,510 269,390 3759,28 10407,44 90,620 268,240 3759,25 10440.69 91.480 269,460 3758,64 10472,14 91,420 269,200 3757,84 10502,88 90,680 268,650 3757,28 10536.21 90,430 268,580 3756,96 3829,48 252,00N 8065,93W 6015278,03 N 543859,46 E 3828,46 252,49N 8095,52W 6015278,31N 543829,87 E 3827,68 253,06 N 8125,31W 6015278,67 N 543800,07E 3827,29 253,64N 8156,68W 6015279,04N 643768.69 E 3827,01 254,09 N 8190,08W 6015279,25 N 543735.30 E 3826,66 254,53N 8224,39W 6015279,45 N 543700,98 E 3826,20 254,86 N 8257,21W 6015279,56 N 543668,16 E 3825,45 255,44N 8285,69W 6015279,94 N 543639,68 E 3823,85 256,96N 8322,03W 6015281,21N 543603.32 E 3822,49 258,36 N 8352,75W 6015282,38 N 543572,60 E 3821,54 259,44N 8381,80W 6015283,26 N 543543,54 E 3820,93 260,29 N 6415,14W 6015283,88 N 543510,20 E 3820,72 260,79N 8447,84W 6015264,16 N 543477,49E 3820,56 261,22N 8477,65W 6015284,38 N 543447,68 E 3820,49 261,68 N 8510,97W 6015284.61N 543414,36 E 3820,67 262,04N 8544,18W 6015284,73 N 543381.14 E 3820,94 262,24N 8572,73W 6015264,73 N 543352,59 E 3821,21 262,39 N 8609,06W 6015284,63 N 543316,26 E 3821,38 262,26 N 8640,70W 6015264,28 N 543284,63 E 3821,58 261,94N 8669,08W 6015283,76 N 543256,25 E 3821,55 261,32N 8699,00W 6015282,93 N 543226,34 E 3820,94 260,65 N 8732,24W 6015282,03 N 543193.10 E 3820,14 260,28 N 8763,67W 6015281,45 N 543161.67 E 3819,58 259,71N 8794,40W 6015280,66 N 543130,95 E 3819,26 258,90 N 8827,72W 6015279,62N 543097,63 E Dogleg Rate (°/lOOft) 3,676 0,813 4,060 1.850 0.629 0,724 1,635 7,067 3,300 3,153 2,190 4.516 0,988 0,570 1,277 1.543 0,946 0,688 2,781 0,681 5,340 4,489 0,848 2,999 0,779 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 8069.79 8099,38 8129.18 816o,55 8193.95 8228.26 8261,o8 8289,56 8325.93 8356.68 8385,74 8419,09 8451,8o 8481,61 8514,93 8548.14 8576,68 8613.00 8644.63 8672.99 8702.88 8736,09 8767,50 8798,21 8831,49 0 Continued.,, 17 October, 2000- 22:02 - 7- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Reft API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 10565.34 90.250 268.310 3756.78 10600.29 90.060 267.290 3756.69 10632.97 91.230 266.550 3756.32 10663.26 90.980 266.770 3755.74 10696.32 90.550 266.250 3755.30 10729.16 90.370 267.980 3755.03 10760.11 92.400 269.400 3754.28 10791.81 92.030 270.050 3753.06 10825.78 91.780 268.980 3751.93 10855.31 91.850 268.400 3750.99 10888.58 91.970 268.370 3749.89 10920.92 91.910 268.240 3748.79 10951.81 91.790 267.210 3747.79 10984.13 91.780 266.810 3746.79 11016.12 92.090 267.680 3745.71 11047.93 92.090 267.600 3744.55 11082.14 92.520 270.180 3743.17 11123.72 92.650 270.660 3741.30 11142.03 92.150 270.220 3740.53 11178.73 91.660 268.680 3739.31 11209.49 91.970 269.250 3738.33 11238.33 90.920 269.570 - 3737.61 11280.93 91.910 270.510 3736.56 11318.47 92.340 271.320 3735.16 11351.12 91.050 272.180 3734.20 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (fi) (ft) 3819.08 258.11N 8856.84W 6015278.62 N 543068.52E 3818.99 256.77N 8891.76W 6015277.04 N 543033.61 E 3818.62 255.01N 8924.39W 6015275.06 N 543000.99 E 3818.04 253.25 N 8954.63W 6015273.08 N 542970.77 E 3817.60 251.24N 8987.62W 6015270.84 N 542937.79 E 3817.33 249.58N 9020.42W 6015268.96 N 542905.01 E 3816.58 248.88 N 9051.35W 6015268.03 N 542874.08 E 3815.36 248.72 N 9083.03W 6015267.66 N 542842.41 E 3814.23 248.44N 9116.97W 6015267.14 N 542808.46 E 3813.29 247.76 N 9146.48W 6015266.26 N 542778.96 E 3812.19 246.82N 9179.72W 6015265.09 N 542745.73 E 3811.09 245.87N 9212.03W 6015263.91N 542713.43E 3810.09 244.64N 9242.88W 6015262.47N 542682.59 E 3809.09 242.96 N 9275.14W 6015260.56 N 542650.34E 3808.01 241.42N 9307.07W 6015258.80 N 542618.42 E 3806.85 240.11N 9338.83W 6015257.27 N 542586.67E 3805.47 239.45N 9373.01W 6015256.37 N 542552.50 E 3803.60 239.75 N 9414.54W 6015256.38 N 542510.96 E 3802.83 239.89 N 9432.84W 6015256R0 N 542492.67E 3801.61 239.54N 9469.51W 601525529 N 542455.99 E 3800.63 238.99 N 9500.25W 6015255.02 N 542425.26 E 3799.91 238.69 N 9529.08W 6015254.52 N 542396.43 E 3798.86 238.72 N 9571.67W 6015254.25 N 542353.85 E 3797.46 239.32 N 9609.18W 6015254.59 N 542316.33 E 3796.50 240.32N 9641.80W 6015255.36 N 542283.71 E Dogleg Rate (°/lOOft) 1.114 2.969 4.236 1.099 2.041 5.296 8.003 2.358 3.233 1.977 0.372 0.443 3.355 1.237 2.886 0.251 7.640 1.195 3.636 4.401 2.109 3.806 3.204 2.442 4.748 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 8860.58 8895.45 8928.02 8958.20 8991.13 9023.87 9054.77 9086.43 9120.36 9149.84 9183.04 9215.31 9246.11 9278.32 9310.20 9341.91 9376.06 9417.59 9435.88 9472.53 9503.24 9532.05 9574.63 9612.14 9644.77 ~ ---., Continued... 17 October, 2000- 22:02 -8- DrillQuest 1,05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (~t) (~t) (ft) 11377.93 90.370 269.950 3733.87 3796.17 11409.20 91.970 270.730 3733.23 3795.53 11441.42 93.140 271.310 3731.79 3794.09 11473.21 93.020 271.170 3730.08 3792.38 11504.18 93.570 271.910 3728.30 3790.60 11536.65 93.570 271.580 3726.28 3788.58 11567.40 93.390 271.410 3724.41 3786.71 11598.38 91.290 270.850 3723.15 3785.45 11631.10 90.550 270.700 3722.62 3784.92 11662.78 90.180 270.400 3722.42 3784.72 11695.13 89.690 270.250 3722.46 3784.76 11727.87 92.160 270.980 3721.93 3784.23 11760.09 93.260 272.280 3720.41 3782.71 11793.42 91.480 273.020 3719.03 3781.33 11824.07 91.050 272.160 3718.35 3780.65 11855.70 90.120 271.230 3718.03 3780.33 11887.36 89.630 271.280 3718.10 3780.40 11919.59 89.200. 270.870 3718.43 3780.73 11951.41 88.890 270.950 3718.96 3781.26 11985.19 88.580 270.280 3719.70 3782.00 12062.00 88.580 270.280 3721.61 3783.91 240.81N 9668.60W 6015255.67 N 542256.90 E 241.00N 9699.86W 6015255.64 N 542225.64 E 241.57N 9732.04W 6015255.99 N 542193.46 E 242.26 N 9763.78W 6015256.45 N 542161.72 E 243.09 N 9794.68W 6015257.07 N 542130.80.E 244.08 N 9827.08W 6015257.83 N 542098.41 E 244.88 N 9857~6W 6015258.42N 542067.72E 245.49 N 9888.71W 6015258.81N 542036.77 E 245.93 N 9921.42W 6015259.03 N 542004.05 E 246.23 N 9953.10W 6015259.11N 541972.37 E 246.42N 9985.45W 6015259.07 N 541940.02E 246.77 N 10018.18W 6015259.19 N 541907.29 E 247.68 N 10050.35W 6015259.88 N 541875.12 E 249.22 N 10083.61W 6015261.19 N 541841.84 E 250.61N 10114.22W 6015262.36 N 541811.22 E 251.54 N 10145.84W 6015263.08 N 541779.60 E 252.24 N 10177.49W 6015263.55 N 541747.95 E 252.84N 10209.71W 6015263.93 N 541715.72 E 253.35 N 10241.52W 6015264.21N 541683.91E 253.71N 10275.29W 6015264.34 N 541650.14 E 254.09 N 10352.08W 6015264.18 N 541573.35 E Dogleg Rate (°llOOft) 8.695 5.692 4.052 0.580 2.974 1.014 0.804 7.015 2.308 1.504 1.584 7.867 5.282 5.783 3.136 4.158 1.556 1.843 1.006 2.185 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 9671.58 97o2.83 9735.02 9766.76 9797.68 9830.09 mm 9860.78 9891.73 9924.44 ---': 9956.12 :3=,~,.~ (.-) 9988.46 .,-.-.-~ 10021.19 ~ o ",J 10053.37 10086.67 10117.30 10148.93 10180.59 10212.82 10244.63 10278.40 10355.17 Projected Suwey Continued... 17 October, 2000 - 22:02 - 9 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Ref: API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-223. Northings and Eastings are relative to MPJ-223. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-223 and calculated along an Azimuth of 271.540° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12062.00ft., The Bottom Hole Displacement is 10355.19ft., in the Direction of 271.406° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 12062.00 3783.91 254.09 N 10352.08 W Projected Survey Continued... 17 October, 2000- 22:02 - 10- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 MWD Your Reft API-500292297000 Surveyed: 22 September, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Survey tool program From Measured Vertical Depth Depth fit) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) fit) 12062.00 3783.91 Survey Tool Description MWD Magnetic 17 October, 2000 - 22:02 - 11 - DrillQuest 1.05.05 bp November 7, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Davies: Subject: Well Re-Naming The operator request the following Milne Point Wells be re-named as follows: APl num Permit Number Current Name New Name 500292296600 200-1.09. MPI-210 MPI- 10 500292297000 200-120 M PJ-223 M PJ-23 500292297600 200-149 M PJ-224 M PJ-24 500292298000 200-166 M P E-225 M PE-25 500292298060 200-167 M P E-225L 1 M P E-25L 1 Sincerely, Troy D~s . ACT, Production Optimization Team Leader TDW:mw CC: Well Files S. Copeland, MB LR-2 Gary Benson, MB 12-4 Larry Niles, MPU Chuck Mallary, MB 8-1 Mike Bill, MB 7-5 ALASi~A OIL AND GAS CONSERVATION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz Senior Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit J-23 BP Exploration (Alaska) Inc. Permit No: 200-120 Sur Loc: 2685'NSL, 3390'WEL, Sec. 28, T13N, RIOE, UM Btmhole Loc. 2959'NSL, 3295'WEL, Sec. 30, T13N, R10E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt, you from obtaining additional' permits required by law from other governmental agencies.,, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be .given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~_. ~. "% day of August, 2000' · dlf/Enclosures CC: Department of Fish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA(" _ AND GAS CONSERVATION COMIC" SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Ddll [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 66' Milne Point Unit / Schrader 3. Address 6. Property Designation z~Sl.~, Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517~ ~,~ 4. Location of well at surface 7. Unit or Property Name '~ ~ 1. Type Bond (See 20 AAC 25.025) 2685' NSL, 3390' WEL, SEC. 28, T13N, R10E, UM (As Staked) Milne Point Unit At top of productive interval 8. Well Number ~ 2941' NSL, 173' WEL, SEC. 30, T13N, R10E, UM MpJ,~3 ' Number 2S100302630-277 .! At total depth 9. Approximate spud date 2959' NSL, 3295' WEL, SEC. 30, T13N, R10E, UM 08/20/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025519, 1948' MDI MPN-01,300' away at 10287' MD 2560 12163' MD / 3797' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 330' MD Maximum Hole Angle 92 ° Maximum surface 1265 p$ig, At total depth (TVD) 3800'/1700 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Wei.qht Grade Couplinq Len.qth MD TVD MD T VD (include sta.qe data) 30" 20" 94# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7" 26# L-80 BTC-M 8950' 30' 30' 8950' 3782' 915 sx Arctic Set III, 525 sx Class 'G' , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner ORIGINAL Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Fred Johnson, 564-5427 Prepared By Name/Number. Terrie Hubble, 564-4628 21. I hereby certify that the foregq~'g~f,,,._~_, truel~'co~ect...., to the best of my knowledge Si~n~d St~e~h,,u,,Itz ,~~"' /~"//.,~,~,, Titl,,,e, Senior Drillin.?, Engineer , Date ~,.~.!I,~.=.,...,.,~ ,..l,~,,,~,;~tl,...~.l~l,..~.,,~.~ .... l~..If. '' 'i~i ~',r~ ...... , .... , ........ ~, ' ' Permit Number ~/..J APl Number Allp~oval Dste See cover letter ~--~'"/------~ 50- C.,2...'~" ~---~---'~"~ -' ~ ~'['~. [OD for other requirements Conditions of Approval: Samples Required r-I Yes ,1~ No Mud Log Requir~ct [] Yes ,J~,No Hydrogen Sulfide Measures [] Yes I~ No Directional Survey Required IR] Yes [] No Required Working Pressure for BOPE '~,2K; [] 3K; [] 4K; [] 5K; [] 10K; [] 15K Other: by order of _Approved By ORIGINAL_ _ SIGNED_. BY. Commissioner the commission Date Form 10-401 Rev. 12-01-85 D Tuyiu~ S=,,,,~uu,~ Submit In Triplicate M,-'!r]e Poii'~t J-23 Permit questions Subject: Milne Point J-23 Permit questions Date: Thu, 24 Aug 2000 13:38:05-0500 From: "Townsend, Monte A" <TownseMA@bp.com> To: '"Maunder, Tom (AOGCC)'" <Tom_Maunder@admin.state.AK. US> CC: "Jenkins, David P" <JenkinDP@bp.com>, "Collins, Patrick J" <CollinsP@bp.com>, "Johnson, Frederick C (ARCO)" <JohnsoFC@bp.com> Tom, Attached is the note we discussed on the phone today. It should explain in more detail the issues around power fluid and downhole tubular integrity for BP's jet pumped wells. After you have read and if you have additional questions please call or e-mail me. Phone# 564-4602 thanks - Monte <<MP-J223 State Briefing document.doc>> Name: MP-J223 State Briefing document.doc ~MP-J223 State Briefinfl document.doc Type: Microsoft Word Document (applimtion/msword)! ......................................................................................................................................... Encoding?ase64 .................................................................................................................................................. 1 of 1 8/24/00 3:03 PM BP has applied to the AOGCC to drill Milne Point well J-23 and J-23L. These permits are for two laterals that will access the Schrader Bluff formation through a single wellbore. This note address questions the State has asked concerning erosion/corrosion issues of downhole tubulars. System Configuration MP J-23 and J-23L1, along with MP J-24, will utilize jet pumps as the form of artificial lift. The power fluid for these pumps will consist of produced water that will be pumped down the 7" by 3-1/2" annulus. The water will come from a separator system that will be constructed on J-pad. The feed stream for this vessel will be produced fluids from J- pad, from which the oil, gas and solids will be separated and sent down the flowline to the processing facilities. The water will be sent to a local pump that will boost pressures to a maximum of 3500 psi and supply the energy for lifting produced fluids from the two subject wells. Required power fluid rates are estimated at 1500 - 2000 bfpd for each well. Erosion Issues Errosion is not considered to be a problem as downhole velocities will be around 1 ft/sec, the rate for 2000 BFPD passing down a 7" by 3-1/2' annulus. Under downhole conditions erosion would not be a concern until velocities approached the 13-15 fi/sec range. The 13-15 ft/sec, guideline comes from the APl 14E Hydraulic Institute and BP's erosion guidelines. These guidelines are for a system with the following specifications: · Two-phase liquid system without gas · Solids present at 50 to 150 pptb ( pounds per thousand bbls) · Carbon Steeltubulars · Tubulars assumed to have bends · Erosion rate of 0.1mm/year allowed. Not only will the velocities be much lower than guidelines suggest, but downhole conditions will be more conservative than those for which these guidelines were developed. First, the solids will be removed with the separator system, so they should be less than the 50 to 150 pptb. Second, downhlole.conditions will have straight pipe flow, not bends. Allowable velocity limits for straight pipe are higher than those suggested above. Corrosion Issues During the life of the project power fluid will be produced water from two sources. For the first 2-4 years treated make-up water from the Milne CPF will be used as the wells will be dry production. Once the wells on J-pad began to produce water, this produced water will be separated out on location and supplemented with make-up water to supply the needed power fluid. Make-up water that comes from the Milne CPF contains chemicals used to protect the surface piping from corrosion. Currently this consists of an Oxygen Scavenger, Biocide and Scale Inhibitor. Surface corrosion rates and chemicals are consistently monitored and adjusted to prevent corrosion. As conditions change, chemicals are also adjusted, and they will be carried over with the power fluid to protect the downhole tubulars. Later in the life of the project less make-up water will be used (as the watercut of the wells increases) and the power fluid will become mostly produced water. However as this fluid is not exposed to oxygen sources, its corrosivity is expected to be Iow. It is the same fluid that is, and has been pumped through the surface flowlines without corrosion problems. Additionally, corrosion coupons will be installed at the separator system to provide a method of continually monitoring corrosion rates. Should corrosion rates become unacceptable, additional chemicals will be injected with the power fluid prior to being pumped downhole. Downhole Pressure Testin; The most conclusive means of determing downhole tubular integrity is via a pressure test. The proposed completion will allow BP to conduct mechanical integrity tests of the 7" casing and/or the 3-1/2" tubing string. The 7" by 3-1/2" annulus can be tested by closing the downhole sliding sleeve and pressuring up on the annulus. Additionally, the jet pump can be pulled and a wireline plug set below the packer and a pressure test done via the tubing or casing. If it is suspected that downhole tubular integrity has been lost, one of these tests will be conducted to verify the condition of the piping. ¢' ( I Well Name: IMP J-23 & MPJ-23L1 I Well Plan Summary Type of Well (producer or injector): I Producer (Multilateral) I Surface Location: MPJ-23 OB Target Start: MPJ-23 OB Target End: MPJ-23 L10A Target Start: MPJ-23 L10A Target End: 2685' NSL, 3390' WEL, Sec. 28, T13N, R10E X = 551,926.84 Y = 6,015,082.54 2941 NSL, 173 WEL, Sec. 30, T13N, R10E X = 544,582 Y = 6,015,291 Z = 3785' TVDss 2959 NSL, 3295 WEL, Sec. 30, T13N, R10E X = 541460 Y = 6,015,291 Z = 3732' TVDss 2931 NSL, 5055 WEL, Sec. 29, T13N, R10E X = 544,980 Y = 6,015,283 Z = 3719' TVDss 2959 NSL, 3294 WEL, Sec. 30, T13N, R10E X = 541,461 Y = 6,015,291 Z = 3665' TVDss I AFE Number: 1337xxx I I"ig= I Doyon ~4~ I Estimated Start Date= I Aug. 20, 2000 ] I Operating days to complete: M PJ-23 MD 12,160' MPJ-23LI MD 12156' MPJ-23 TVD: 3800' MPJ-23LI TVD: 3730' I KBE: 166.00' Well Design (conventional, slim hole, etc.): IGrassroots multi-lateral with extended horizontal laterals. Jet pump completion. Objective: Drill 9-7/8" mainbore hole to +/-8950'md. Land mainbore hole in OB reservoir. Run and cement 7" casing. Drillout shoe and drill 3200' horizontal well in OB. Run multilateral packer & whipstock at top of OA interval at +/-8635'md. Mill window in 7" casing. Drill 3500' horizontal well in OA. Present plan is to leave horizontal laterals open hole. Slotted liners may be run as a contingency. Complete well with a 3-1/2" tubing jet pump completion. Jet Pump Completion: MP J-23 will be completed with a jet pump as the means of artificial lift. The jet pump completion on J-23 consists of 3-1/2" completion tubing and a 7" x 3-1/2" packer set at +/-7900'md. A sliding sleeve is installed in the tubing string right above the packer. The jet pump nozzle is installed in the sliding sleeve and the sliding sleeve is opened to provide the flowpath for the power fluid. During operation power fluid is pumped down the tubing x casing annulus to the sliding sleeve. The power fluid then flows thru the sliding sleeve and jet pump nozzle creating the drawdown required to produce the well due to the venturi effect of the power fluid and nozzle. Both the power fluid and well production are produced up the tubing to the surface. Power fluid for J-23 will be 2500 psi water. R _CEIVED Current Well Information Well Name: APl Number: Well Type: Current Status: BHP: BHT: Mechanical Condition: MP J-23: Doyon 141: Conductor: Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: Production Casing: Production Liner: L-80 Completion: MP J-23 Development - Shrader Bluff Multilateral Producer New well, 20" conductor to be set 1,700 psi Schader Bluff 'OB' sand. Normal pressure gradient. 80°F@ 4,020' ss Estimated Cellar Box MSL = 35.50' KB / MSL = 65.00' 20", 921b/ft, H-40 Welded set at 110' RKB Expected reserves 1.7 mmbbl Production rate: 1,200 b/d Production rate: 1,000 b/d 9000' I each I each 100 each 50 each I assembly I assembly I lot 7000' contingency 200 - 4-5/8" x 5 3/4" x 8" 7" x 4-1/2" 4-1/2" 200 - 4-5/8" x 5 3/4" x 8" 8500' 3-1/2" CMU SSD 3x3-1/2"Landing nipples 7"x3-1/2" Packer 3-1/2" I assembly I assembly I each I lot 7" 26 Ib/ft L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" BTC-M Tam Port Collar ;7" x 8-1/2" Rigid SB Casing Centralizers '7" Stop Rings · FMC 11" 5m x 3-1/2" Horizontal Wellhead/Tree Baker Level 2 Multilateral Equipment 7" casing pups 5', 10', 20' 4.5", 12.6#, L-80, IBT-Mod Slotted Liner Rigid Straight Blade Centralizers and stop rings Baker liner top hanger with inner string Baker guide shoe, packoff bushing Rigid Straight Blade Centralizers and stop rings 3-1/2" 9.3 Ib/ft, L-80, 8rd EUE tubing Baker sliding sleeve X and XN nipples Baker S3 FMC tubing hanger for horizontal tree wellhead Bottom Hole pressure gauge with I-wire BIW I-wire penetrator BIW ESP & Heat Trace Dummy Penetrators 3-1/2" tubing pup joints .., RECEIVED Gas Cons. C0mmissi0~ ,Anchorage . . . . . Drillir(, Hazards and Contin_ -=nciee Well Control a) The 9-7/8" surface hole will be drilled with a diverter on the well. The 6-1/8" horizontals will be drilled with the BOP installed. MP J-23 is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.7 lb/gal equivalent. The planned mud weight is 9.1 lb/gal which provide a .4 lb/gal overbalance (80 psi). Kick tolerance a) The 7" casing will be set into the Schrader Bluff OB reservoir. The kick tolerance for the 6- 1/8" horizontal open hole section is infinite assuming an influx at the 12,100' in the Schrader OB formation. This is a worst case scenario based on a 8.7 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 lb/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. b) The 7" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 7500'. Lost Circulation a) b) c) Lost circulation has not been encountered while drilling this interval on previous J-Pad wells. Three more recent wells (Sweet 16 wells J-17, J-20, J21) used the same single 7" casing string design. These wells did not experience lost cimulation problems while running and cementing casing. d) A major fault (+165' throw) will be drilled in the surface hole at approximately -3461' ss TVD (7700' MD). This fault' is located in the Ugnu formation. This fault is not expected to cause lost cimulation but contingency plans should be developed should lost cimulation occur. Maintain minimum ECD thru use of proper hole cleaning procedures and PWD monitoring. Clean hole ECD in the 9-7/8" surface hole is estimated to be 10.1 lb/gal. Clean hole ECD in the 6- 1/8" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD th'ru use of proper hole cleaning procedures, PWD monitoring, and control drilling. 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 [Jnexpected High Pressures a) It is .unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no offfake or injection support. Reservoir pressure is expected to be 1700 psi (8.7 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. Stuck Pipe a) b) c) The J-23 directional plan has a 6500' interval of high angle(74 deg'rees) in the surface hole and 3500' horizontal intervals in the OA/OB reservoirs. All these hole intervals have massive permeable sand intervals which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! A major risk of the J-23 well is running the 7" casing to TD. The 7" casing must be run all the way d) to TD to allow fo ~ multilateral to be drilled. Sticking the ca ~ off bottom will result in not being able to drill the multilateral as planned. The 9-7/8" surface hole has a 6500' high angle tangent section which is built to horizontal at TD. Similar wells in the past have experienced problems running the 7" casing to TD due to the high drag and differential sticking. On the previous wells it was necessary to wash the casing to TD and to utilize the top drive weight to help push the casing. Past operations were successful in running the 7" casing using these techniques in additional to liberal use of lubricants and strict attention to hole cleaning and mud/hole conditioning prior to running casing. 4-1/2" Slotted liners are being planned as a contingency for the 6-1/8" horizontal holes. If the slotted liners are run there will be a risk of differentially sticking the 4-1/2" liner. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.7 lb/gal OA/OB sand reservoir pressure (80 psi differential pressure @ 3,800' TVD). The liner should be kept moving as much as possible while running in the open hole. In 1999, the 5-1/2" casing on the J-15i well was differentially stuck. Differential sticking was also encountered in the OA Sand interval while running in the hole with the 4-1/2" liner on MPJ-01A, with 350 psi differential pressure and no centralization. Moderate differential sticking was encountered while running the centralized slotted liner on the MP J-09A well with 9.1 lb/gal mud and 300 psi differential pressure. Se m . . 10. 11. Pad Data Sheet a) Please Read the J-Pad Data Sheet thoroughly. Hydrates: a) Hydrates have not been encountered on previous J-Pad wells and are not expected. However hydrates have been encountered on H-Pad and mud returns should be monitoredto determine if hydrates are encountered on this well. Breathing: a) No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. Hydrocarbons: a) Hydrocarbons will be enCountered in the Ugnu and Schrader Bluff intervals. Geosteering: a) b) Two rig site geologists are required onsite for accurate geosteering through the thin OA/OB sands It is critical that we achieve a high percentage of in reservoir zone drilling in the OA/OB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. Hydrogen Sulfide a) MP J Pad is not designated as an H2S Pad. ., Drillin Pro_ ram Overview Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MP J-23. Close Approach Wells: J-20 and N-01B are close approach wells and will be risked based. Well Name Current Status Production Priority Precautions MP J-20 Shut in SB Producer Failed ESP I Low Well to be secured as required MP N-01B Shut in test well NoneI Well is shut in and secured Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 1,700 psi, 3,600' TVD (estimated) IMax Exp Surface Pressure 1,265 psi (.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2,000/250 psi Rams and Valves 2~000/250 psi Annular Mud Program 9-718" Surface Hole Mud Properties: I Spud - LSND Freshwater Mud I Density (ppg) Funnel vis YP HTHP pH APl Filtrate LG Solids 8.6 - 9.2 150 - 50 40 -15 N/A 9.0 - 9.5 <6 <6.5 6-1/8" Production Hole Mud Properties: OBIOA I KCL - CaCO3 Baradril N Mud I Density (PPg) I Funnel visI YP I "THP p" I APl Filtrate J LG Solids 9.1 40 - 55 20 - 27 <10 8.0 - 8.5 4 - 6 < 15 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or ARCO KRU 1R. ~.. u~s ~,o,~s. Cor~ss~on .Anchorage Formation Markers Formation Tops MD TVDss Pore Psi EMW (ppg) Comments Base Permafrost 2096 1865 Top Ugnu 6294 3138 1383 8.65 Top Ugnu M 7128 3368 1486 8.65 NA 8001 3609 1595 8.65 NB 8095 3635 1607 8.65 NC 8208 3666 1620 8.65 NE 8302 3692 1632 8.65 NF 8498 3746 1656 8.65 Top OA 8625 3781 1672 8.65 Base OA 8737 3812 1686 8.65 Top OB 3842 1700 8.65 Base OB 3864 1710 8.65 Casing/Tubing Program Hole Size Csgl Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 94# H-40 Weld 80' 30'/30' 110'/11 O' 9-7/8" 7" 26# L-80 BTC-Mod 8950' 30'/30' 8,950'/3,782' 6-1/8" OB 4-1/2" * 12.6# L-80 IBT-Mod 3,260' 8,900?3,844' 12,160'/3,797' 6-1/8" OA 4-1/2" * 12.6# L-80 IBT-Mod 3,500' 8,650'~3,784' 12,15073,730' Tubing 3-1/2" Jet 9.3# L-80 EUE-Mod 7,900' 30'~30' 7,900'/3,581' Pump *Note: 4-112" slotted liner is a contingency completion. Present plans are for open hole completions in the horizontal intervals. Cement Calculations ICasing Size 17" 26 Ib/ft L-80 BTC-M I BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost I' Tam Port Collar at 1000'md as a contingency in case cement does not circulate to surface in single stage I Total Cement Volume: Spacer 75 bbls of B45 Viscosified Spacer Weighted to 10.5 ppg Lead 915 sx 723 bbl 10.7 lb/gal Arctic Set III Light Tail 525 sx 109 bbl 15.8 lb/gal Class G' Temp BHST -80° F from SOR, BHCT 85° F estimated by Dowell Casing Spaceout: 1. Space 7" casing out with pups and long/short joints as required to place the top of a long full joint at the actual top of the OA sand .to allow for the window to be' milled just below the top of the OA sand and in the middle of a full joint of casing. Run full casing joints across the OA sand. Any casing pup joints required for spaceout should be placed below the base of the OA sand. . Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required spaceout.~"~7,...,~,,,~,~[~V~[-~![~ ['C~ ~[~ ' "~ ~ask~ 07~ & Gss Co~'~s. CommJssior~ .Anchorage Centralizer Placement: 1. Do not run centralizers on the 2 joints of 7" casing spaced across the upper OA sand. 2. With the exception stated above, straight blade rigid centralizers should be run floating in the middle of each joint of casing from the 7" casing shoe up to 7500'md (500' above NA sand. Zonal isolation with cement is required between the top of the OA and base of the N sands. Other Cement Considerations: Survey and Logging Program 9-7/8" Hole Section: Open Hole: Cased hole: 6-1/8" Hole Sections: Cased Hole: MWD I GR/Res I PWD - (Resistivity over @roduction interval only) None MWD I GR/Res I PWD I ABI / ABGR - (ABGR may re run if available) None Perforating: None Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzle I Flow Rate K-Rev's Hours Number and Section 9-7/8" 0 - 8~950 Milltooth 600 gpm 6-1/8" 8~950' - 12~200' PDC 250+ gpm ~ ~ Motors and Required Doglegs BHA Motor Size and Motor Flow Rate RPM's Required Doglegs Number Required 6.75" Sperrydrill 7/8, 3 stg Slow 600 gpm 170 4 degree initial build Speed~ 1.5° adj w/9.6" sleeve 8 degree final build 4 s~, Sperrydrill 4/5, 6.3 stg Slow 250 gpm 250 Build out of window at 10- Speed~ 1.5° adj w/5.8" sleeve 12°/100 to horizontal. ( MP J-23 Operations Summary Pre-Rig Operations 1. Install 20" conductor 2. Secure MP J-20 well for close approach issue. Procedure 1. MIRU Doyon 141, NU diverter on 20" conductor, PU 5" drill pipe 2. MU BHA with 9-7/8" milltooth bit, 6-3/4" Sperry MWD/LWD(GR-Res)/PWD and 5" drill pipe. Drill 9-7/8" surface hole as per directional plan. Tangent angle 74 degrees. Surface hole landed on OB at 88 degrees. 3. Wiper trip as required, condition mud with lubes and spot casing running lube pill prior to running 7" casing 4. Run 7" casing to TD. Cement casing to surface. Be prepared to use top drive weight to assist running casing. Tam Port Collar will be run as a contingency in case cement does not circulate to surface on first stage. 5. Install FMC 11" 5m wellhead. NU 13-5/8" 5m BOP. Test BOP to 200/250 psi. 6. Lay down 5" drill pipe, PU 3-1/2" drill pipe . MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3-1/2" drill pipe. Drill out float equipment. Displace hole to 9.1 lb/gal Bara Drill mud Drill 20' of new hole and perform FIT to 11.0 lb/gal 8. Drill 3200' 6-1/8" OB lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. 9. Wiper trip at TD. Displace OB lateral with clean Bara Drill mud. 0. Make 7" casing scraper to trip to 7" casing TD prior to setting Baker ML packer. 11. 12. 13. 14. Run 7" Baker ML packer on 3-1/2" drill pipe with drill pipe setting tool and RA marker tag Rig up Schlumberger 1-11/16 GR. Log packer on depth to place window at top of the OA interval. Set packer Run in hole with MWD to determine orientation of ML packer . .. Make up Baker Window Master milling assembly with retrievable whipstock and MWD. Install whipstock in ,,ML packer. Ver, lfywhipstockorientaionwith MWD' Shear~off,~nd millwindow.' MU BHA with 6-1/8 PDC bit, 4-3/4 MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3~1/2 drill pipe. RIH. Displace hole to clean Bara Drill mud. Drill 3500 ' OA horizontal lateral' 15. Wiper trip at TD. Displace OA lateral with clean Bara Drill mud. 16. MU whipstock retrieving tool and MWD. RIH. Orient and jet whipstock face. Engage and pull whipstock free. 17. MU 2-7/8" tubing stinger. RIH and wash down thru ML packer. 18. MU Baker flow thru hollow guidestock and MWD. RIH and set guidestock in ML packer. Verify guidestock orientation with MWD. 19. Displace 7" casing to 9.1 lb/gal completion fluid. L/D 3-1/2" drill pipe. 20. Run 3-1/2" tubing and packer completion. Space out packer with the tailpipe 50' above the NA sand Freeze protect tubing and annulus. Drop ball and set packer. Completion will include sliding sleeve (for jet pump application), Baker Sentry gauge and 1/4" TEC wire to surface. 21. Set tubing plug and BPV. ND BOP. Install and test tree. 22. RDMO .Formation Inte.qrity Test Procedure: 1. Determine the required surface pressure. 2. In the case of a surface casing shoe, a PPG EMW should be sufficient unless the well plan notes differently. 3. Test the casing prior to drilling out the float collar. i) Run the mud pump at a constant 0.25~0~5 bpm and record results. One-stroke pressure readings are recommended, but in all cases record pressures in at least five-stroke increments. If the pressures are increasing rapidly enough to make this reading too large, take pressure readings at 30-second intervals. Plot the results for reference during the following LOT. ii) When the required test pressure is reached, suspend pumping and hold the test pressure for thirty minutes. Check that the test is being accurately recorded on ~, chart. 4. Drill remaining cement, float collar, float shoe and 20-ft to 50-ft of new hole. 5. Circulate and condition mud to a constant mud weight and rheology. 6. Pull into the casing shoe. 7. Close a blowout preventer. 8. Run the mud pump at a constant 0.25 to 0.5 bpm. 9. Match the pump rate to the one used during the previous casing pressure test. 10. Stop the pump when the required test pressure is reached. 11. Close appropriate valves if surface leaks are suspected. 12. Hold and record the pressure every 30 seconds for 10 minutes minimum. 13. In the event that the pressure continues to bleed off without becoming C.O. nstant continue to hold and record the pressures at 30 second intervals for another 5 minutes. Surface equipment should be checked for leaks and if any found the test redone. ..14. Check to ensure that the chart recorder is accurately recording the test. Bleed back mud from the well and compare with the volume pumped. Record volume in trip tank or cement tanks. 15. Document the FIT results on the IADC sheet and on next morning report. For consistency among rigs, use the Excel spreadsheet LOT Version 5.0 (on the Drilling File Server in the LOT folder) to plot the casing and leak off tests. Immediately send the leak-off test plot and pressure recorder charts to the office to be stored with the rest of the reports in the well file. If them is any question about the interpretation of the FIT results, inform the drilling superintendent before drilling ahead WELLHEAD: FMC Horizontal 11" 5M tbg. head KB. ELEV -- 66.00' 11" x 3-1/2", EUE (btm) Cellar Box ELEV -- 35.50' · FMC tbg. hanger, 'H' BPV profile 8. I 1~0' I 20,, 92 ib/ft, H_40 Welded ~, ~ · I 3-1/2", 9.3 lb/fi, L-80, EUE-M Coupling OD: 4.5" :,~_, ~= r~- ~ ~ [ ',~. ~' ~-,=. ~ -'~ Drift/ID · 2.867"/2.992" :~ ~ ~,.' ~ ~ f ~ BakerTEC Wire I I Selective X Nipple 2.813" ID I Jet Pump Installed in Sliding Sleeve ~ Baker CMU Sliding Sleeve with 2.813 ID Selective X Profile ~ . Baker Sent~ Pressure Gauge (Internal Pressure) ~'.=: ~ Baker S3 Packer ~ 7,~ ~ .. 7", 26~, L-80, BTC-M ~... :' .= '~ No Go XN Nipple 2.75" ID Casing Drift: 6.151" .... Casing ID: 6.276" Wireline Ent~ Guide Multi-Lateral Junction 8,~' 6-1/8" CA Lateral TD 1~ ~ 6-1/8" OB Lateral TD ~~, Window in 7" casing ~ 8,635' I Well Inclination ~ Window = 74 DegreesJ -~~ ......... O~ 8ori~on~l Flow lhru Hollow ~uido Stock I ~ ....................... Multi-lateral Paekor ~ ~ ~-1/8" Holo k~ft as Opon Holo Gomplotion 4-1/2" 81o~d kinor a~ Contingency {~lop & Drop) 7" Casin~ Shoo ~ 8,0SO' ~ " Woll Inclination ~ Shoo ~ 88 Do~ro~i ~ ~ ~~ " ~tomne~ Dim~ional ~lan WP4 ~-1/8" Holo Lo~ a~ Open Holo ~omplotion ~ I ~ 4-1/2" 81o~od kinor & Han~or a~ ~ontin~on~y · ~ I I DATE REV. BY COMMENTS Milne Pnint ~nit WBLL: J-~ ML 7/1~0 FJ Level 2 Multi-~teral, ~1~" Jet Pump Compl~ion - BP Exploration (Atask~) North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-23 ] .DrillQuest' o Scale: linch = 1400ft Eastings -9800 -8400 -7000 -5600 -4200 -2800 -1400 0 I I I I I I I I I End DIr: 11407.66ff MD. 3810.11ff'I'VD J~r.P./-2$.. 38.=° ,~ / I .oo~ Oir. 4.o~o~ :t~.~j~ll~ll~j~9~...~g~ ~(,.7~4,~.31'W F:nd Dir: 1891.47h MD. 1730.01fl TVD I I _j._uegln Ulrg4.UUO'/1UfJII:IUr~I4.UUIIMU ;~82U:~Glt IVl) fl'n ir O° ' 1 · - . , - Be_i D 4.000 I100fl. 2061.47ft MD, 842.32fl TVD I .b-.37;e~mJ3aso~ ~ ~ 7" Casing - 9300 MD End Dir: 2700.13fl MD, 2146.45ft TVD , I IMPJ-23 T4. 3~97.20 TVD 27t[09 N, 9705.26 W 1281.39 N~ 10465.24 W Begin Dir O 1.500°1100ft: 330.001! MD~ 330.00fl TVD I I I I I I I I -9800 -8400 -7000 -5600 -4200 -2800 - 1400 0 Scale: I inch = 1400ft Eastings Reference is True North Proposal Data for MPJ-23 Wp4 Ve~cal Origin:MPJ-ML3 I-Io~iz~tlaJ Oligin: MPJ-ML3 Measurement Units: It Nodh Reference: Tree No~h Dogleg seve~y:Degrees per VstGcal SecUon A~muth: 271.540' Verlical Section DescdpUon: MPJ-ML3 Ve~cal Secl]on Origin: 0.00 N.O.00 E ~ a'~ ~ ["" t % ~'~i''~'''~.'"~ .....,.d ,.~. ~. v.,..., N~,... ~....,. V.~.., ~'~..~= ~ "-i .. g-'~ ~ ~-~ ~ 1'. ~' ~'P"' o,p., s..,o. R.ts 0.~0 0.000 0.399 0.00 u.oo N o.l~ I.~ ~.00 ~0.~0 0.0~00.3~9 .~0.~0 0.~0 N o.~m I.;0.00 5~0.00~.0~027~.~9 ~-9.91 0.49 N .%21 W .~.22I.~O ! ] ,~.,~ ._.~ ¢'~ ~ n n '~, 18~1.4~ 4L65Z275.~ 17.~O.01 ~.O?N 561.51 W.n~_?4.~.~0 6~&.n? W 6~.0~ N 2~61.47 4L652 2700.1]7].9~2 271.SJJ2146.45 ~6.]? N IZ4J.27 W1~5.41 4.OOO 0 .~l , ~a.--A~:~.. ~'~.~.~ ~ .~'"~."x.~~- :%~.~,& ]~e,~.~]~A]~ 95&]~ aL]Il27].~2 ]~?.~J 257.29N ?J~2~W ?~.~ 4.~ f j/ g]l~l] ~.s~ ~?o.}74~Jo.?] 2~SON 741~.~ W 7417.~?4.~ ~e Dir Rate O 2 5~/1~ 530 ~ MD 529 91fl ~ / ii .................................. ~ ]~?.~6 9135]~?o.~ ~l~a.~ ~?o.x~ N / l/ 11~76 91.175 270.3~ 3~10.~ 276.W N ~05.26 W~)?w).17 / ~0.~ I !~7.~~.~ 270.3~ ~SI0.11 27~l) N S~lO. 15 W 9714.(~4.(~] 1400 - ~ ~~in Dir O 4.~'/1~: 2~1.47ff MD, 1~2.32ff ~ ~ ~ -- Base Perm(~rost . ..................... ~-.~:.~,~;~.~ ............................................................................................................................................ 1~5.20 ~ / 0 . · -~ ,~2~~ 2800 - ~ . ' _~a~ ,, .................................................................................... ~ ................................................ o~;~~s ~ .......................... ....... ....... ~ ~;~"~;;~;;;~;~;;~;;;;~;;~;~;~;~;~;;;;;;~;~;;~~"~;~;~;~;~ .... ":;~;~ .... ~'~': .......;;;~ .................................. ~ ~ ~j' ........ ~ .... ~'t~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......................................................................... :: :-~ .... ::::::: ..... ::::::::: :::::::::::::::::::::::::: ::::::::~;~, .. = ..................................................................................................................................... -.- :..,:::: ......... ~ .... .~..1~...~, ..... ~. ...... --~ ' ............................. 7~---;C~lng ................................... - 9~ MD ='" ~tPJ.~)~.~2~' ...... ' '= =''*=:B;se(IA..MIZ~O~ Sr~eder OB- J~4t2~IVI)) Scale: linch = 1400ft I I I I 1400 2800 4200 5600 Vertical Section .]BI 39 N i~155.~4 W Base OB · JW. 20 TVI) MPJ. Z3 TI. 3~0.20 ~D MP/-23 ~ - 38Z&20 ~D MP].2S ~ . 381~20'~' TOt~ D~pth: 121~.87fl MD. 3797 2~ 2S~7~IW 27~77N, a941.2aW ZT~OeN_eTO~2~W 4 1/2" Uher - 12162.87 MD, 3797.~D I I 7000 8400 9800 Section Azimuth: 271.540° (True North) North Slope Alaska Measured Depth Incl. Azim. (ft) 0.00 0.000 0.000 65.20 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 330.00 0.000 0.000 400.00 1.050 275.399 500.00 2.550 275.399 530.00 3.000 275.399 600.00 4.750 275.399 700.00 7,250 275,399 730.00 8.000 275,399 Sub-Sea Depth (~) -65.20 0.00 34.80 134.80 234.80 264.80 334.80 434.74 464.71 534.55 633.99 663.72 Sperry-Sun Drilling Services Vertical Depth (~) 0.00 65.20 100.00 200.00 300.00 330.00 400.00 499.94 529.91 Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 599.75 699.19 728.92 800.00 10,450 275.399 732.81 798.01 900.00 13.950 275.399 830.54 895.74 1000.00 17.450 275.399 926.79 991.99 1100.00 20.950 275,399 1021.22 1086.42 1200.00 24,450 275.399 1113.46 1178.66 1300.00 27.950 275.399 1203.17 1268.37 1400.00 31.450 275.399 1290.02 1355.22 1500.00 34.950 275,399 1373.68 1438.88 1600.00 38.451 275.399 1453.85 1519.05 1700.00 41.951 275.399 1530.21 1595.41 1800.00 45.451 275.399 1602.50 1667.70 1891.47 48,652 275.399 1664.81 1730.01 1900.00 48.652 275.399 1670.45 1735.65 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (fi) 0.00 N 0.00 E 6015082.55 N 551g26.g5 E 0.00 N 0.00 E 6015082.55 N 551g26.g5 E 0.00 N 0.00 E 6015082.55 N 551g26.g5 E 0.00 N 0,00 E 6015082.55 N 551926.95 E 0.00 N 0.00 E 6015082.55 N 551926.95 E 0.00N 0.00 E 6015082.55 N 551926.95 E 0.06 N 0.64W 6015082.60 N 551926.31E 0.36 N 3.77W 6015082.88 N 551923.18 E 0.49 N 5.21W 6015083.00 N 551921.73 E Dogleg Rate (°/100~) o.ooo 0.000 0.000 0,000 0,000 1.500 1.500 1.500 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 0.00 0.00 0.00 0,00 0.00 0.00 0.64 3.77 5.22 0.94 N 9.92W 6015083.41N 551917.02 E 2.500 9.94 1.92 N 20.33W 6015084.33 N 551906.61E 2.500 20.37 2.30 N 24.29W 6015084.67 N 551902.64 E 2.500 24.34 3.35N 35.46W 6015085.65 N 551891.46 E 3.500 35.54 5.34N 56.50W 6015087.49 N 551870.41E 3.500 56.62 7.89 N 83.43W 6015089.85 N 551843.46 E 3.500 83.61 10.98 N 116.17W 6015092.72 N 551810.70E 3.500 116.42 14.61N 154.58W 6015096,08 N 551772.26 E 3.500 154.92 18.76N 198.53W 6015099.93 N 551728.29 E 3,500 198.96 23.43N 247.85W 6015104.24 N 551678.94 E 3.500 248.39 28.58N 302.36W 6015109.01 N 551624.40E 3.500 303.01 34.20 N 361.84W 6015114.22 N 551564.87E 3.500 362.63 40.27N 426.09W 6015119.85 N 551500.58 E 3.500 427.02 46.77N 494.87W 6015125.87 N 551431.77E 3.500 495.94 53.07N 561.51W 6015131.70 N 551365.08 E 3.500 562.74 53.67N 567.89W 6015132.26 N 551358.70E 0.000 569.13 Comment Be~in Dir @ 1.500°/100ft: 330.00ft MD, 330.00ft TVD Increase in Dir Rate @ 2,500°/100ft: 530.00ft MD, 529.91ft TVD Increase in Dir Rate @ 3.500°/100ft: 730.00ft MD, 728.92ft TVD End Dir: 1891.47ft MD 1730.01ft TVD ' Continued... 19 July, 2000- 10:40 - 1 - DrillQuest 1.05,05 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 2000.00 48.652 275,399 1736.51 2061.47 48.652 275,399 1777.12 2096.59 50.042 275,124 1800.00 2100.00 50.176 275.098 1802,18 2200.00 54,136 274.373 1863.52 2300.00 58.099 273.718 1919.26 2400.00 62.065 273.117 1969,13 2500.00 66,034 272.558 2012,88 2600.00 70.005 272.033 2050,30 2700,00 73.977 271.534 2081,21 2700,13 73.982 271.533 2081,25 2800,00 73.982 271.533 2108.81 2900,00 73.982 271,533 2136.40 3000,00 73.982 271.533 2163,99 3100.00 73,982 271.533 2191.59 3200.00 73,982 271.533 2219.18 3300,00 73.982 271.533 2246.77 3400.00 73.982 271.533 2274,37 3500.00 73.982 271,533 2301,96 3600.00 73.982 271.533 2329.55 3700.00 73.982 271.533 2357.15 3800.00 73.982 271.533 2384.74 3900.00 73.982 271.533 2412.33 4000.00 73.982 271.533 2439.93 4100.00 73.982 271.533 2467.52 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 1801.71 60.74 N 642.63 W 1842.32 65.08 N 688,57 W 1865.20 67.52 N 715.10 W 1867,38 67.75 N 717.71 W 1928.72 74.26 N 796,39 W 1984.46 80.10 N 879.18 W 2034.33 85.26 N 965.69 W 2078,08 89,70 N 1055.48 W 2115,50 93.41 N 1148.11 W 2146,41 96,36 N 1243.15 W 2146,45 96,37 N 1243.27 W 2174,01 98.94 N 1339.23 W 2201.60 101.51 N 1435.32 W 2229,19 104,08 N 1531.40 W 2256.79 106.65 N 1627.48 W 2284.38 109.22 N 1723,57 W 2311.97 111,79 N 1819,65 W 2339,57 114,36 N 1915.73 W 2367,16 116.93 N 2011.82 W 2394.75 119.51 N 2107.90 W 2422.35 122.08 N 2203.98 W 2449,94 124,65 N 2300.06 W 2477.53 127.22 N 2396,15 W 2505.13 129.79 N 2492.23 W 2532.72 132.36 N 2588.31 W Global Coordinates Northings Eastings (ft) (ft) 6015138.80 N 551283,91 E 6015142,82 N 551237.94 E 6015145.08 N 551211.39 E 6015145.30 N 551208.78 E 6015151.25 N 551130,06 E 6015156.52 N 551047,22 E 6015161.07 N 550960.69 E 6015164.89 N 550870.87 E 6015167.95 N 550778.21 E 6015170,24 N 550683.15 E 6015170.25 N 550683,03 E 6015172.15 N 550587,06 E 6015174.05 N 550490.96 E 6015175.95 N 550394,86 E 6015177.85 N 550298.76 E 6015179,75 N 550202.66 E 6015181,65 N 550106,56 E 6015183.56 N 550010,46 E 6015185,46 N 549914.36 E 6015187.36 N 549818.27 E 6015189.26 N 549722.17 E 6015191,16 N 549626.07 E 6015193.07 N 549529.97 E 6015194.97 N 549433.87 E 6015196.87 N 549337.77 E Dogleg Rate (*/lOOft) o.ooo 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 644.03 690.07 716.66 719.27 798.10 881.02 967,63 1057,51 1150,21 1245.29 1245.41 1341.41 1437,53 1533.64 1629,76 1725,88 1822,00 1918,11 2014,23 2110.35 2206,47 2302.58 2398,70 2494,82 2590,94 Comment Be(3in Dir @ 4.000°/100ft: 2061.47ft MD, 1842.32ft TVD Base Permafrost End Dir' 2700.13ft MD, 2146.45ft TVD Continued... 19 July, 2000 - 10:40 - 2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) 4200.00 73,982 271.533 2495.11 2560.31 4300.00 73.982 271.533 2522.71 2587.91 4400.00 73,982 271,533 2550.30 2615.50 4500,00 73,982 271,533 2577,89 2643.09 4600.00 73.982 271.533 2605.49 2670.69 4700.00 73,982 271.533 2633.08 2698.28 4800.00 73.982 271.533 2660.67 2725.87 4900.00 73,982 271.533 2688.27 2753.47 5000.00 73,982 271.533 2715,86 2781.06 5100.00 73,982 271.533 2743,45 2808.65 5200.00 73.982 271.533 2771.05 2836.25 5300.00 73.982 271.533 2798.64 2863.84 5400.00 73.982 271,533 2826.23 2891.43 5500.00 73,982 271.533 2853,83 2919.03 5600,00 73,982 271.533 2881.42 2946,62 5700,00 73,982 271.533 2909.01 2974.21 5800.00 73,982 271.533 2936,61 3001.81 5900.00 73.982 271.533 2964,20 3029.40 6000.00 73.982 271.533 2991.79 3056.99 6100.00 73.982 271.533 3019.39 3084.59 6200.00 73.982 271.533 3046.98 3112.18 6294.29 73.982 271.533 3073.00 3138.20 6300.00 73.982 271.533 3074.57 3139.77 6400.00 73.982 271.533 3102.17 3167.37 6500.00 73.982 271.533 3129.76 3194.96 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 134.93 N 2684.40 W 6015198.77 N 549241.67 E 137.51 N 2780.48 W 6015200.67 N 549145.57 E 140.08 N 2876.56 W 6015202.57 N 549049.47 E 142.65 N 2972.65 W 6015204.48 N 548953.38 E 145.22 N 3068.73 W 6015206.38 N 543857.28 E 147.79 N 3164.81 W 6015208,28 N 548761.18 E 150.36 N 3260.90 W 6015210.18 N 548665.08 E 152.93 N 3356.98 W 6015212.08 N 548568.98 E 155.51 N 3453.06 W 6015213.99 N 548472.38 E 158.08 N 3549.15 W 6015215.89 N 548376.78 E 160.65 N 3645.23 W 6015217.79 N 548280.68 E 163.22 N 3741.31 W 6015219.69 N 543184.58 E 165.79 N 3837.40 W 6015221.59 N 548088.49 E 168.36 N 3933.48 W 6015223.49 N 547992.39 E . . 170.93 N 4029.56 W 6015225.40 N 547896.29 E 173.51 N 4125.65 W 6015227.30 N 547800.19 E 176.08 N 4221.73 W 6015229.20 N 547704.09 E 178.65 N 4317.81 W 6015231.10 N 547607.99 E 181.22 N 4413.90 W 6015233.00 N 547511.89 E 183.79 N 4509.98 W 6015234.90 N 547415.79 E 186.36 N 4606.06 W 6015236.81 N 547319.70 E 188.79 N 4696.66 W 6015238.60 N 547229.08 E 188.93 N 4702.15 W 6015238.71 N 547223.60 E 191.51 N 4798.23 W 6015240.61 N 547127.50 E 194.08 N 4894.31 W 6015242.51 N 547031.40 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 2687.05 2783.17 2879.29 2975.41 3071.53 3167.64 3263.76 3359.88 3456.00 3552.11 3648.23 3744.35 3840.47 3936.58 4032.70 4128.82 4224.94 4321.05 4417.17 4513.29 4609.41 4700.04 4705.53 4801.64 4897.76 Comment Top Ugnu Continued.,. 19 July, 2000 - 10:40 - 3 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth fit) (ft) (ft) 6600,00 73.982 271.533 3157.36 3222,56 6700,00 73.982 271.533 3184,95 3250.15 6800.00 73.982 271.533 3212,54 3277.74 6900.00 73,982 271,533 3240.14 3305.34 7000.00 73.982 271,533 3287.73 3332,93 7100.00 73.982 271.533 3295.32 3360.52 7127.82 73.982 271.533 3303.00 3368.20 7200.00 73.982 271.533 3322.92 3388.12 7300.00 73.982 271.533 3350.51 3415.71 7400.00 73.982 271.533 3378.10 3443.30 7500.00 73.982 271.533 3405.70 3470.90 7600.00 73.982 271.533 3433.29 3498.49 - 7700.00 73.982 271.533 3460.88 3526.08 7800.00 73.982 271.533 3488.48 3553.68 7900.00 73.982 271.533 3516.07 3581.27 8000.00 73.982 271.533 3543.66 3608.86 8001.22 73.982 271.533 3544.00 3609.20 8095.45 73.982 271.533 3570.00 3635.20 8100.00 73.982 271.533 3571.26 3636.46 8200.00 73.982 271.533 3598.85 3664.05 8207.79 73.982 271.533 3601.00 3666.20 8300.00 73.982 271.533 3626.44 3691.64 8302.02 73.982 271.533 3627.00 3692.20 8400.00 73.982 271.533 3654.04 3719.24 8497.72 73.982 271.533 3681.00 3746.20 Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 Local Coordinates Global Coordinates Northings Eastings NOrthings Eastings (ft) (ft) fit) (ft) 196.65 N 4990.40 W 6015244.41 N 546935.30 E 199.22 N 5086.48 W 6015246,32 N 546839.20 E 201.79 N 5182.56 W · 6015248.22 N 546743,10 E 204.36 N 5278.65 W 6015250.12 N 546647.00 E 206.93 N 5374,73 W 6015252.02 N 546550.90 E 209.51 N 5470.81 W 6015253.92 N 546454.81 E 210.22 N 5497.55 W 6015254.45 N 546428.07 E 212.08 N 5566.90 W 6015255.82 N 546358.71 E 214.65 N 5662.98 W 6015257.73 N 546262.61 E 217.22 N 5759.06 W 6015259.63 N 546166.51 E 219.79 N 5855.15 W 6015261.53 N 546070.41 E 222.36 N 5951.23 W 6015263.43 N 545974.31 E 224.93 N 6047.31 W 6015265.33 N 545878.21 E 227.51 N 6143.39 W 6015267.24 N 545782.11 E 230.08 N 6239.48 W 6015269.14 N 545686.02 E 232.65 N 6335.56 W 6015271.04 N 545589.92 E 232.68 N 6336.73 W 6015271.06 N 545588.74 E 235.10 N 6427.27 W 6015272.85 N 545498.19 E 235.22 N 6431.64 W 6015272.94 N 545493.82 E 237.79 N 6527.73 W 6015274.84 N 545397.72 E 237.99 N 6535.21 W 6015274.99 N 545390.23 E 240.36 N 6623.81 W 6015276.74 N 545301.62 E 240.41 N 6625.75 W 6015276.78 N 545299.68 E 242.93 N 6719.89 W 6015278.65 N 545205.52 E 245.45 N 6813.78 W 6015280.50 N 545111.62 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section 4993.88 5090.00 5186.11 5282.23 5378.35 5474.47 5501.21 5570.58 5666.70 5762.82 5858.94 5955.05 6051.17 6147.29 6243.41 6339.53 6340.70 6431.27 6435.64 6531.76 6539.25 6627.88 6629.82 6724.00 6817.92 Comment Top Ugnu M Schrader NA Schrader NB Schrader NC Schrader NE Schrader NF Continued... 19 July, 2000 - 10:40 - 4 - DrillQuest 1.05.05 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (it) (it) 8500.00 73.982 271,533 3681,63 8600.00 73.982 271.533 3709.22 8624,56 73.982 271.533 3716.00 8700.00 73.982 271.533 3736.82 8758,61 73.982 271,533 3752.99 8800.00 77.087 271.533 3763.33 8900.00 84.587 271.533 3779.24 8945.51 88.000 271.533 3782.18 8953.28 88.311 271.542 3782.43 9000.00 88.311 271.542 3783.81 9040.37 88.311 271.542 3785.00 9100.00 90.476 270.543 3785.63 9110.11 90.844 270.374 3785.51 9200.00 90.844 270.374 3784.19 9300.00 90.844 270.374 3782.72 9400.00 90.844 270.374 3781.25 9500.00 90.844 270.374 3779.77 9600.00 90.844 270.374 3778.30 9700.00 90.844 270.374 3776.83 9800.00 90.844 270.374 3775.35 9900.00 90.844 270.374 3773.88 10000.00 90.844 270.374 3772.41 10100.00 90.844 270.374 3770.94 10200.00 90.844 270.374 3769.46 10300.00 90.844 270.374 3767.99 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (it) (it) (~) (it) (it) 3746.83 245.51 N 6815.98 W 6015280.55 N 545109.42 E 3774.42 248.08 N 6912.06 W 6015282.45 N 545013.32 E 3781.20 248.71 N 6935.66 W 6015282.92 N 544989.72 E 3802.02 250.65 N 7008.14 W 6015284.35 N 544917.22 E 3818.19 252.16 N 7064.46 W 6015285.47 N 544860.90 E 3828.53 253.23 N 7104.52 W 6015286.26 N 544820.84 E 3844.44 255.87 N 7203.14 W 6015288.21 N 544722.20 E 3847.38 257.08 N 7248.53 W 6015289.11 N 544676.80 E 3847.63 257.29 N 7256.29 W 6015289.26 N 544669.04 E 3849.01 258.55 N 7302.97 W 6015290.20 N 544622.35 E 3850.20 259.63 N 7343.31 W 6015291.00 N 544582.00 E 3850.83 260.72 N 7402.92 W 6015291.67 N 544522.38 E 3850.71 260.80 N 7413.04 W 6015291.68 N 544512.27 E 3849.39 261.38 N 7502.91 W 6015291.64 N 544422.40 E 3847.92 262.04 N 7602.90 W 6015291.60 N 544322.41 E 3846.45 262.69 N 7702.88 W' 6015291.55 N 544222.42 E 3844.97 263.34 N 7802.87 W 6015291.51 N 544122.43 E 3843.50 263.99 N 7902.86 W 6015291.46 N 544022.44 E 3842.03 264.65 N 8002.85 W 6015291.42 N 543922.45 E 3840.55 265.30 N 8102.83 W 6015291.37 N 543822.46 E 3839.08 265.95 N 8202.82 W 6015291.33 N 543722.47 E 3837.61 266.60 N 8302.81 W 6015291.28 N 543622.48 E 3836.14 267.25 N 8402.79 W 6015291.24 N 543522.49 E 3834.66 267.91 N 6502.78 W 6015291.19 N 543422.50 E 3833.19 268.56 N 8602.77 W 6015291.15 N 543322.51 E Dogleg Rate (°/100fi) 0.000 0.000 0.000 0.000 0.000 7.500 7.500 7.500 4.000 0.000 0.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6820.11 6916.23 6939.84 7012.35 7068.68 7108.76 7207.41 7252.82 7260.58 7307.28 7347.64 7407.26 7417.37 7507.23 7607.19 7707.16 7807.13 7907.10 8007.07 8107.04 8207.00 8306.97 8406.94 8506.91 8606.88 Comment Schrader OA Begin Dir @ 7.500°/100ft: 8758.61ft MD, 3818.19ft TVD Decrease in Dir Rate @ 4.000°/100ft: 8945.51ft MD, 3847.38ft TVD End Dir: 8953.28ft MD, 3847.63ft TVD Begin Dir @ 4.000°/100ft: 9040.37ft MD 3850.20ft TVD Target - MPJ~.'23 T1 End Dir: 9110.1 lft MD, 3850.71ft TVD Continued... 19 July, 2000 - 10:40 - 5- DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (It) Vertical Depth (It) 10400.00 90.844 270.374 3766.52 3831.72 10500.00 90.844 270.374 3765.05 3830.25 10600.00 90.844 270.374 3763.57 3828.77 10634.60 90.844 270.374 3763.06 3828.26 10638.55 91.000 270.399 3763.00 3828.20 10647.36 91.352 270.399 3762.82 3828.02 10700.00 91.352 270.399 3761.58 3826.78 10800.00 91.352 270.399 3759.22 3824.42 10900.00 91.352 270.399 3756.86 3822.06 11000.00 91.352 270.399 3754.50 3819.70 11100.00 91.352 270.399 3752.14 3817.34 11200.00 91.352 270.399 3749.78 3814.98 11300.00 91.352 270.399 3747.42 3812.62 11398.33 91.352 270.399 3745.10 3810.30 11400.00 91.286 270.399 3745.06 3810.26 11402.76 91.175 270.399 3745.00 3810.20 11407.66 90.979 270.399 3744.91 3810.11 11500.00 90.979 270.399 3743.33 3808.53 11600.00 90.979 270.399 3741.62 3806.82 11700.00 90.979 270.399 3739.91 3805.11 11800.00 90.979 270.399 3738.20 3803.40 11900.00 90.979 270.399 3736.49 3801.69 12000.00 90.979 270.399 3734.78 3799.98 12100.00 90.979 270.399 3733.07 3798.27 12162.87 90.979 270.399 3732.00 3797.20 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (It) (It) (It) (It) 269.21 N 8702.75 W 6015291.11 N 543222.53 E 269.86 N 8802.74 W 6015291.06 N 543122.54 E 270.52 N 8902.73 W 6015291.02 N 543022.55 E 270.74 N 8937.32 W 6015291.00 N 542987.96 E 270.77N 8941.28W 6015291.00 N 542984.00E 270.83N 8950.08W 6015291.00 N 542975.20 E 271.20 N 9002.71W 6015291.00 N 542922.57 E 271.89 N 9102.68W 6015291.00 N 542822.60 E 272.59N 9202.65W 6015291.00 N 542722.62E 273.29 N 9302.62W 6015291.00 N 542622.65 E 273.98 N 9402.58W 6015291.00 N 542522.68 E 274.68 N 9502.55W 6015291.00 N 542422.71E 275.38 N 9602.52W 6015291.00 N 542322.73E 276.06N 9700.83W 6015291.00 N 542224.43E 276.07N 9702.49W 6015291.00 N 542222.76E 276.09 N 9705.26W 6015291.00 N 542220.00E 276.13 N 9710.15W 6015291.00 N 542215.11E 276.77N 9802.48W 6015291.00 N 542122.78 E 277.47N 9902.46W 6015291.00 N 542022.79 E 278.16 N 10002.44W 6015291.00 N 541922.81E 278.86 N 10102.43W 6015291.00 N 541822.82E 279.56 N 10202.41W 6015291.00 N 541722.84 E 280.25 N 10302.39W 6015291.00 N 541622.85 E 280.95 N 10402.37W 6015291.00 N 541522.87 E 281.39 N 10465.24W 6015291.00 N 541460.00E Dogleg Rate (°/100fi) 0.000 0.000 0.000 0.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4.000 4.000 4.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (It) 8706.85 8806.82 8906.78 8941.37 8945.32 8954.12 9006.74 9106.69 9206.65 9306.60 9406.55 9506.50 9606.46 9704.74 9706.41 9709.17 9714.06 9806.37 9906.34 10006.31 10106.27 10206.24 10306.20 10406.17 10469.02 Comment Be~in Dir @ 4.000°/100ft: 10634.60ft MD, 3828.26ft TVD Taraet - MPJ-23 T2, 200.00 Radius. End Dir' 10647.36ft MD, 3828.02ft TVD Be~in Dir @ 4.000°/100ft: 11398.33ft MD, 3810.30ft TVD Target - MPJ-23 T3 End Dir: 11407.66ft MD, 3810.1 lft TVD TotaJ Depth: 12162.87ft MD, 3797.20ft TVD 4 1/2" Liner Target- MP U-23C~)~tillued... 19 July, 2000 - 10:40 - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-ML3. Northings and Eastings are relative to MPJ-ML3. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-ML3 and calculated along an Azimuth of 271.540° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12162.87ft., The Bottom Hole Displacement is 10469.02ft., in the Direction of 271.540° (True). Comments Measured Depth (ft) 330.00 530.00 730.00 1891.47 2061.47 2700.13 8758.61 8945.51 8953.28 9040.37 9110.11 10634.60 10647.36 11398.33 11407.66 Station TVD (ft) 330.00 529.91 728.92 1730.01 1842.32 Coordinates Northings Eastings (ft) (It) 0,00 N 0.00 E 0.49 N 5.21 W 2.30 N 24.29 W 53.07 N 561.51 W 65,08 N 688.57 W 2146.45 96.37N 1243.27W 3818.19 252.16 N 7064.46W 3847.38 257.08 N 7248.53W 3847.63 257.29 N 7256.29W 3850.20 259.63 N 7343.31W 3850.71 260.80 N 7413.03W 3828.26 270.74N 8937.32W 3828.02 270.83 N 8950.08W 3810.30 276.06 N 9700.82W 3810.11 276.13 N 9710.15W Comment Begin Dir @ 1.500°/100ft: 330.00ft MD, 330.00ft TVD Increase in Dir Rate @ 2.500°/100ft: 530.00ft MD, 529.91ft TVD Increase in Dir Rate @ 3.5000/100ft: 730.00ft MD, 728.92ft TVD End Dir: 1891.47ft MD, 1730.01ft TVD Begin Dir @ 4.000°/100ft: 2061.47ft MD, 1842.32ft TVD End Dir: 2700.13ft MD, 2146.45ft TVD Begin Dir @ 7.500°/100ft: 8758.61ft MD, 3818.19ft TVD Decrease in Dir Rate @ 4.000°/100ft: 8945.51ft MD, 3847.38ft TVD End Dir: 8953.28ft MD, 3847.63ft TVD Begin Dir @ 4.000°/100ft: 9040.37ft MD, 3850.20ft TVD End Dir: 9110.1 lft MD, 3850.71ft TVD Begin Dir @ 4.000°/100ft: 10634.60ft MD, 3828.26ft TVD End Dir: 10647.36ft MD, 3828.02ft TVD Begin Dir @ 4.000°/100ft: 11398.33ft MD, 3810.30ft TVD End Dir: 11407.66ft MD, 3810.1 lft TVD Continued... 19 July, 2000 - 10:40 - 7- DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Station TVD (ft) Comments (Continued) 12162.87 3797.20 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 Coordinates Northings Eastings Comment (ft) (ft) 281.39 N 10465.24 W Total Depth: 12162.87ft MD, 3797.20ft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 2096.59 1865.20 1800.00 6294.29 3138.20 3073.00 7127.82 3368.20 3303.00 8001.22 3609.20 3544.00 8095.45 3635.20 3570.00 8207.79 3666.20 3601.00 8302.02 3692.20 3627.00 8497.72 3746.20 3681.00 8624.56 3781.20 3716.00 Northings Eastings Formation Name (ft) (ft) 67.52 N 715.10 W Base Permafrost 188.79 N 4696.66 W Top Ugnu 210.22 N 5497.55 W Top Ugnu M 232.68 N 6336.73 W Schrader NA 235.10 N 6427.27 W Schrader NB 237.99 N 6535.21 W Schrader NC 240.41 N 6625.75 W Schrader NE 245.45 N 6813.78 W Schrader NF 248.71 N 6935.66 W Schrader OA Alaska State Plane 4 Milne Point MPJ Continued... 19 July, 2000 - 10:40 - 8 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 Revised: 14 July, 2000 Alaska State Plane 4 Milne Point MPJ Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 12162.87 9300.00 3847.92 12162,87 Targets associated with this wellpath Target Name MPJ-23 T1 MPJ-23 T2 MPJ-23 T3 MPJ-23 T4 Vertical Depth Casing Detail (ft) 3797.20 4 1/2" Liner 3797.20 7" Casing Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3850.20 3785.00 259.63 N 7343.31 W 6015291.00 N 544582.00 E 70° 27' 09.5305" N 149° 38' 10.4233" W 3828.20 3763.00 270.77N 8941.28W 6015291.00N 542984.00 E 70°27'09.6229''N 149° 38'57.3627"W 3810.20 3745.00 276.09 N 9705.26W 6015291.00N 542220.00 E 70° 27' 09.6658"N 149° 39'19.8044"W 3797.20 3732.00 281.39 N 10465.24W 6015291.00 N 541460.00 E 70° 27' 09.7078"N 149° 39' 42.1286"W Target Target Shape Type Point Circle Point Point 19 July, 2000 - 10:40 - 9 - DrillQuest 1.05.05 FI 1 70955 DATE ! CHECK NO. pot 70955 VENDOR AL~,SKASTI,q. O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~62900 ~KO&2900E 100. O0 100. O0 HANDLI~IO INST- PH YERRI HUBBLE X4&28 : A1TACHED CHECK IS IN PAYMENT FOR ITEM5 DESCRIBED ABOVE. 00, ~;,!':!': ip.O~"~:§'6~i::i'!9:~.~.2.'.i~i~i:.:"::;;!li~i:,I ". '."' :: .'.'": · .':~:i'.:!i... .:;::::..:..:~:.,.~..:,...~.~,~.~,,.~..,o :....~,... ;:..:....~:. ..... "'"'"' '~:"~:";'"":'"'":':;:i.:.;:...'.'.i~:i,:.'?. i.li::'::?.:"'AN~?o ~G:~i!!A~B.~i 995'.1..9::661.2 :;:;';:.~:~[~?::~.:::' I ~,a¥~.":,'.: ;..... ON'.~,./~V~~;'?~ .'..:::'....':,...~...: ::...'".......'...: ':..'. '.... '....:?:::,F?....'" ~r.:: :.;?~:?; '...:~;:': ~...." :~";~?: D":.~'.:.. .. "' ..... ~:,~: ::~:.::''. :".~..~ ..',::: :~ ~¢'" '. :: ~..? ~' '.'.':::: :.:.::~;;?,~:.? .'.. 'OA~..' .'.::,~; ~::~ '.'"~'f~ :"::..:~:~?F ,."::: ~':::'~:'"'.' 2/: ~°O:N~'":;':':':'.:".':: "'. "" .; ....'"'""~.'~:::;~.'ml :~;,,:.;:,?~',;,.:..:', '..",....'...:..:':?.':.:,,:., :.'.,~:.,..'.:., .....",':..', .... .',..::: '.,.', ,. ',.." "., ",,'", I I I I ...... ,, : ' ~i:~ :.~:::: :.'... ":..'...::':'~:.".? ;.:....~e,~,.a'~':" ..'~'"~".. .... . ~ '.%'~"~a.~o.'.. ...'.. :WELL PERMIT CHECKLIST COMPANY FIELD & POOL .~,~--~-/Y~) ' INIT CLASS WELL NAME ~,/'...,2,..~ ~ROGRAM: exp. dev ~ redril · serv wellbore seg ann. disposal para req ,~'~),//..-.-- GEOL AREA _~lc~[_~ UNIT, ON/OFF SHORE O,~ · ADMINISTRATION DATE 1. Permit fee attached. 2. Lease number approl~ri~'t~.'~ i i~ ~~,~ ,~.~. -~ ~! 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. .~.~.E 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg .... ..... CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... ' Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet.'.regulation ................ BOPE press rating appropriate; test to .. ~:;3~ ~)sig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY, .. 30. Permit can be issued wlo hydrogen sulfide measures ..... '"'~..~ N" i_ _._/ ' 31. Data presented on potential ovarpressure zones ....... '32. Seismic analysis of shallow gas zones ........... '". · AP, J~R DATE 33. Seabed condition survey (if.off-shore) ............ ~" Y N ' ~ ~,~'O'(~ 34. Contact name/phone for weekly progress reports [expl~,q~ory onlY] Y N. . i[ ANNULAR DISPOSAL35. With proper cementing records, this plan ' . ~ ~'~"~ ~ ~ (A) will contain waste in a suitable receiving zone; ....... Y N "' APpR DATE (B) will not.contaminate freshwater; or cause drilling waste .... Y N. to surface; (c) will not impair mechanical integrity of the well used for disposal; Y N Y N Y N (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY; ENGINEERING: UICl~nnular COMMISSION: Comments/Instructions: c:~nsofflde\wordian~diana~.hecklist (rev. 02/17100) ,,. Well Histo.ry File APPENDIX 'Information of detailed nature that is not particularly germane to the Well Permitting Process 'but is part of the hiStory file. To improve the readability of the Well History file and to simplify finding information, information of this. nature is accumulated at the end of the'file under APPE .N. DIX~ No'special'effort has been made to chronologically organize this category of information. mpj-23.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Jul 30 15:37:01 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/30 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 Date ..................... 01/07/30 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 MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MPJ-23 500292297000 BP Exploration, Alaska Inc. Sperry Sun 17-MAY-01 MWD RUN 1 MWD RUN 3 MWD RUN 4 JOB NUMBER: AK-MM-00178 AK-MM-00178 AK-MM-00178 LOGGING ENGINEER: R. FRENCH R. FRENCH R. FRENCH OPERATOR WITNESS: E. VAUGHN E. VAUGHN C. DIXON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 5 AK-MM-00178 S. LAITILA T. PYRON 28 13N 10E Page 1 FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD mpj-23.tapx 2685 3390 .00 62.30 35.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8892.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. WELL MPJ-23 L1 KICKS OFF FROM MPJ-23 AT 8569' MD, 3765' TVD. MPJ-23 L1 IS PRESENTED SEPARATELY. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 DID NOT GET TO BOTTOM AND IS NOT PRESENTED. 5. MWD RUNS 3-5 ARE DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 4/9/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. 7. MWD RUNS 1, 3, 4, AND 5 REPRESENT THE MWD DATA FOR WELL MPJ-23 WITH API~ 50-029-22970-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12062' MD, 3782' TVD. File Header 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 Page 2 mpj-23.tapx Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 43 5 110 5 3695 0 3695 0 3695 0 3695 0 3695.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12008 5 12061 5 12015 5 12015 5 12015 5 12015 5 12015 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 43.5 3727.0 3 3727.0 8895.5 4 8895.5 11379.5 5 11379.5 12061.5 MERGED MAIN PASS. $ Page 3 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 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 RPX MWD OHMM 4 RPS MWD OHMM 4 RPM MWD OHMM 4 RPD MWD OHMM 4 FET MWD HOUR 4 mpj-23.tapx 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 Name Service Unit Min Max DEPT FT 43.5 12061.5 ROP MWD FT/H 0 4786.71 GR MWD API 13.7 127.51 RPX MWD OHMM 0.39 2000 RPS MWD OHMM 0.39 2000 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.14 2000 FET MWD HOUR 0.0589 117.864 Mean Nsam 6052.5 24037 224.185 23903 68.8171 23931 16.3721 16642 17.9784 16642 25.0604 16642 24.4895 16642 1.28526 16642 First Reading 43.5 110.5 43.5 3695 3695 3695 3695 3695 Last Reading 12061.5 12061.5 12008.5 12015.5 12015.5 12015.5 12015.5 12015.5 First Reading For Entire File .......... 43.5 Last Reading For Entire File ........... 12061.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 43.5 3677.5 ROP 110.5 3727.0 $ Page 4 # 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: mpj-23.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED. TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Page 5 10-SEP-00 Insite 65.41 Memory 3727.0 3.5 77.8 TOOL NUMBER PB01650HWG6 9.875 Water Based 9.10 121.0 9.5 400 8.1 .000 .000 .000 .000 .0 61.0 .0 .0 mpj-23.tapx 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 Name Service Unit Min Max Mean Nsam DEPT FT 43.5 3727 1885.25 7368 ROP MWD010 FT/H 0 4786.71 221.938 7234 GR MWD010 API 13.7 118.72 62.5471 7269 First Reading 43.5 110.5 43.5 Last Reading 3727 3727 3677.5 First Reading For Entire File .......... 43.5 Last Reading For Entire File ........... 3727 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 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 ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3678.0 8853.5 RPM 3695.0 8863.0 RPD 3695.0 8863.0 RPS 3695.0 8863.0 RPX 3695.0 8863.0 FET 3695.0 8863.0 ROP 3727.5 8895.5 $ Page 6 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: mpj-23.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Page 7 14-SEP-00 Insite 65.41 Memory 8895.0 71.7 79.7 TOOL NUMBER PB01650HWGV46 PB01650HWGV46 9.875 .Water Based 9.00 68.0 9.4 200 4.8 4.000 3.275 6.000 4.500 70.0 87.0 70.0 70.0 mpj-23.tapx Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 3678 8895.5 ROP MWD030 FT/H 0 2328.68 GR MWD030 A?I 21.63 127.51 RPX MWD030 OHMM 3.65 135.67 RPS MWD030 OHMM 2.19 199.57 RPM MWD030 OHMM 0.57 2000 RPD MWD030 OHMM 0.28 2000 FET MWD030 HOUR 0.0589 27.8392 Mean Nsam 6286.75 10436 266.192 10337 70.2277 10352 12.9176 10337 13.5526 10337 14.7964 10337 18.053 10337 0.525197 10337 First Reading 3678 3727.5 3678 3695 3695 3695 3695 3695 Last Reading 8895.5 8895.5 8853.5 8863 8863 8863 8863 8863 First Reading For Entire File .......... 3678 Last Reading For Entire File ........... 8895.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 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 ....... 01/07/30 Maximum Physical Record..6§535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 Page 8 mpj-23, tapx FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8854 . 0 11327 . 0 FET 8863.5 11334 . 0 RPD 8863.5 11334 . 0 RPM 8863.5 11334 . 0 RPS 8863.5 11334 . 0 RPX 8863.5 11334 . 0 ROP 8896.0 11379.5 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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: Page 9 21-SEP-00 Insite 65.44 Memory 11380.0 80.4 93.5 TOOL NUMBER PB01647HAGR4 PB01647HAGR4 6.125 Baradril-N 9.10 60.0 9.1 28500 4.6 .120 .093 .190 .200 65.0 86.0 65.0 65.0 mpj-23.tapx # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 8854 11379.5 ROP MWD040 FT/H 0 844.19 GR MWD040 API 25.85 105.88 RPX MWD040 OHMM 0.39 2000 RPS MWD040 OHMM 0.39 2000 RPM MWD040 OHMM 0.06 2000 RPD MWD040 OHMM 0.14 2000 FET MWD040 HOUR 0.2844 117.864 Mean Nsam 10116.8 5052 157.677 4968 73.8231 4947 21.1457 4942 25.4482 4941 46.4239 4941 37.2057 4941 2.61579 4942 First Reading 8854 8896 8854 8863.5 8863.5 8863.5 8863.5 8863.5 Last Reading 11379.5 11379.5 11327 11334 11334 11334 11334 11334 First Reading For Entire File .......... 8854 Last Reading For Entire File ........... 11379.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Page 10 mpj-23.tapx Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11327.5 12008.5 RPD 11334.5 12015.5 RPM 11334.5 12015.5 RPS 11334.5 12015.5 RPX 11334.5 12015.5 FET 11334.5 12015.5 ROP 11380.0 12061.5 $ LOG HEADER DATA DATE LOGGED: 22-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12062.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01647HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB01647HAGR4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Baradril-N MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 60.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.300 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.048 86.0 MUD FILTRATE AT MT: 1.400 68.0 MUD CAKE AT MT: 1.160 68.0 Page 11 mpj-23.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 ' OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR Min Max Mean Nsam 11327.5 12061.5 11694.5 1469 0 592.78 159.997 1364 49.59 120.08 73.3729 1363 5.75 2000 25.2632 1363 7.26 90.75 24.4751 1363 9.36 55.65 25.432 1363 10.69 44.67 25.7572 1363 0.3857 25.9424 2.22524 1363 First Reading 11327.5 11380 11327.5 11334.5 11334.5 11334.5 11334.5 11334.5 Last Reading 12061 5 12061 5 12008 5 12015 5 12015 5 12015 5 12015 5 12015 5 First Reading For Entire File .......... 11327.5 Last Reading For Entire File ........... 12061.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/30 Maximum Physical Record..65535 File Type ................ LO Page 12 mpj-23.tapx Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/07/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/07/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 13
