The URL can be used to link to this page

Home My WebLink About200-121 ' • STATE OF ALASKA 0 ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG El Other ❑ Abandoned LTJ Suspended[ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory E GINJ E WINJ E WAGE WDSPL ❑ No. of Completions: y-tS "- Service Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp., or ,.... 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aban> 4/10/2016 ' 200-121 /315-538 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 September 9,2000 , 50-029-22970-60-00 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 30, 2000 > MPJ-23L1 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 12,126'MD/3,719'TVD N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 541573 y- 6015264 Zone- 4 N/A 1,800'MD/1,672'TVD 5. Directional or Inclination Survey: Yes (attached) No E 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 RECEWEE, APR 2 2 2016 " OGCC 23. CASING, LINER AND CEMENTING RECORD 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 8,590' 12,126' 3,775' 3,783' 6-1/8" Cementless Slotted Liner 24.Open to production or injection? Yes il No Ei 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. APR 2 9 2011 Was hydraulic fracturing used during completion? Yes El No El SCOW U 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 ........- Flow ♦Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (torr): Press. 24-Hour Rate —i Form 10-407 Revised 11/2015 C NTI UED ON PAGE 2 Submit ORIGINIAL only YV z 2( IC, *4 411-ti fb RBDMS Ute- APR 2 b 2016 y • 1 2 8.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: es ❑ No ❑✓ 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 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: sporhola(C�hiIcorp.com Printed Name: Bo YorkTitle: Operations Manager Signaturd1'rkW3 O--- 1/4-iv!' �v `v!IL Phone: 777-8345 Date: 1011-2-/2_o (� 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 1 a: 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 . . , H H . • Milne Point Unit Well: MPU J-23/J-23L1 SCHEMATIC Abandoned: 4/17/2016 I�ilcoru Alaska,LLC PTD: 200-120/200-121 Orig.KBElev=63.2'GLElev.35.8' CASING DETAIL L, Size Type Wt/Grade/Conn Drift ID Top Btm 1:: 20" Conductor 54.5/K-55/WeldedN/A Surf 108' -20. 7" Surface 26/L-80/Btrc. 6.151 Surf 8,892' i u. i 4.Abandoned.l �' 4-1/2" Liner L1 12.6/L-80/IBT 3.833 8,590' 12,126' i 4-1/2" Liner 12.6/L-80/IBT 3.833 8,798' 12,062' P TUBING DETAIL ro, t 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.867 7,892 7,937' A JEWELRY DETAIL No Depth Item 1 7,800' Cement Retainer ' -' 2 7,892' 3-1/2"Tubing Cut Joint ra x 3 7,900' Baker S-3 Packer 1 A 4 7,937' WLEG e '#:. I OPEN HOLE/CEMENT DETAIL Ab 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 V Retainer cement retainer t GENERAL WELL INFO AP I:50-029-22970-00/(60)-00 Drilled and Cased by Doyon 141-10/8/2000 P&A'd by Doyon 14—4/17/2016 i i* a t A i 1 ei t T Ar'0 t, r r "" : r: TD=12,062'(MD)/TD=3,783'(TVD) PBTD=7,800'(MD)/PBTD=3,571'(TVD) Created By:STP 4/19/2016 Hilctp Energy Company Compositeport Well Name: MPJ-23/L1 Field: Milne Point County/State: ,Alaska i(LAT/LONG): evation(RKB): API#: Job Name: MPJ-23 Decomplete Contractor AFE#: 1511739D AFE$: Activity Date Ops Summary 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 L/D 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 L/D 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 L/D 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 CIO 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'.L/D 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,5/0 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 A 7800'allows:Pump 10 bbls fresh water.Test lines to 3500 psi__ Mix and P,Jmp 295sx/60 bbls 15.8 ppg EM(TM)SYSTEM CMT na 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 t Go 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 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/1700 psi,1-6IC wnM PI In,M1H1 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 mill in gauge.Load out BHA,clear rig floor.Load Geo-steer tools to rig floor. 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 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 1/8008'-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. OF T�� • . e`', �j� s THE STATE Alaska Oil and Gas of LAc TA Conservation Commission Wet et __ :_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1 433 FALAS� Fax. 907 276 7542 www.aogcc alaska.gov SCONE° Paul Chan Senior Operations Engineer n C - Hilcorp Alaska, LLC V 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ-23L1 Sundry Number: 315-538 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, Cathy P. Foerster Chair DATED this day of September, 2015 Encl. RBDJ SEP 0 4 2015 RECEIVED AUG 2g 2015 STATE OF ALASKA A i7"S 9 J 21 IS ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request' Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate ❑ Other Stimulate Li Alter Casing ❑ Change Approved Program❑ Plug for Redril 0` Perforate New Pool ❑ Repair Well ❑ Re-enter Suap Well ❑ Other. ❑ 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development ❑✓ 200-121' 3.Address: 6.API Number. Stratigraphic ❑ Service ❑ 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 50-029-22970-60-00 7.If perforating: pjlaj 8.Wel Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 477.US MPJ-23L1 • Will planned perforations require a spacing exception? Yes ❑ No O 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 TVD(ft): Plugs(measured): Junk(measured): 12,126' • 3,719' • 12,126' 3,783' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 8,865' 7" 8,892' 3,83g 7240 5410 Liner(L1) 3,536' 4-1/2" 12,126' 3,719' 8430 7500 Liner Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(R): Vat) '" i 40irk 3-1/2"9.3# L-80 28'-7937' Slotted Liner 8,59 ' 12"{26'MD L1 Slotted Liner 3,788'-3,719'ND L1 4-1/2"12 6# L-80 8573'-8614' Packers and SSSV Type: 3-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(It): 7,900'MD/3,579'TVD Baker ML Torque Master Packer 8,595'MD/3,773'ND 12 Attachments: Descnption Summary of Proposal ❑✓ 13.Well Class after proposed work: �/ Detailed Operations Program ❑✓ BOP Sketch ❑1 Exploratory ❑ Stratigraphic❑ Development[J] Service L 14.Estimated Date for 15.Well Status after proposed work: _n 10/10/2015 r/ S Commencing Operations OIL ❑ WINJ L WDSPL ❑ Suspended IJ 16 Verbal Approval Date: GAS ❑ WAG [.1 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan Email pchanehilcorp_con't Pnnted Name Title Paul Chan Senior Operations Engineer Signature Phone 907-777-8333 Date (Zfii) COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number. 3! - Plug Integrity ❑ BOP Test 47 Mechanical Integrity Test ❑ Location Clearance ❑ UX Other: ‘ - Oft,D 54- &,( (r s.F ( /IAA-S/ :_ (Z oz, r-i-c--/) f A( . ,at. t P/4ce.. �nptc.�-e...0 , zo A4_6_,A4_6_, Z5,0Z.(.._Z) Spacing Exception Required? Yes ❑ No ll Subsequent Form Required: / O — ( 0 7 APPROVED BY Approved by: a(,,f47P COMMISSIONER THE COMMISSION DateQ-3-(/ ,Sr --1---`' ....- ORIGINAL 1/1C RBDMS SEP 0 3 2015 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-Ria 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 and PPPOT-T O 3. CMIT T x IA. MIT OA 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-%" 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#3 Rig. 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. C ' gency:)(If the tubing hanger won't pressure test due to either a penetrator leak or 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. 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. cat ovr. 7�i,' �,. l ti4f r�� m'! !al ftJ draffr^� � gotF g1t, -e'f C vo.f r ?9,P6, / 1 wet/ ' 1"Galln// f�bv/d Q4-' / 'r i'4119A '00 lecc,•e7, be" h'elg4 71/j/ 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-W 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 e-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. /pc, (Pi" ' Pump hbl 15.8 ppg Class G cement plug (from Baker flow guide at 8573' to cement i--'c" 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_ I►A P1-23 KB elev.=63.20' Wellhead:11"x 11"5M tb• g.spool, FMC Horizontal treetModel 120 DF elev.=62.20' 11"x 3.5"8 rd EUE(top&bottom) H GL elev.=35.80' FMC TBG HNG w/3.5"'H'BPV profile. 20" 110' A (} Tam port collar 1005' 0 l 3.5"9.3#ppf,L-80 EUE 8rd tubing Camco 3.5"x 1" 2636' (drift ID=2.992",cap.=0.0087 bpf) sidepocket KBUG GLM 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' sidepocket KBUG GLM "Reverse Circulation'Jet Pump Configuration Produced Fluid i LL �� Baker"CMU"sliding sleeve I € w/2.81"X nipple profile 7840' (' 1 Baker sentry gauge(3567'tvd) 7854' iI Baker S-3 packer(3.97"ID) 7900' 1 ) / V ./, / 1 N 3.5"HES"XN"Nipple 7925' N 2.813"packing/2.75"No- — - WLEG 7937' Reaerunir Firm Baker guide shoe' RA tag at 8456' In Short joint 8539'(29.73') 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') 4 id Baker HR setting sleeve 8590' Baker 7"ML torque master pkr 600-47 8595' WLEG 8614' 111r : % 4.5"12.6#,L-80 IBT tubing. z / Baker Float shoe at 12062' Baker HR sleeve w extension 8798' 41 Baker HMC liner hanger - - 8807' _ _ Halliburton float collar 8809' — — — Halliburton float shoe 8892' 111 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, 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' (} 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. CCement Retainer @-7,800' "Tubing Cut(u` 7,891' • Baker S-3 packer(3.97"ID) 7900' 3.5"HES"XN"Nipple 7925' 2.813"packing/2.75"No- • WLEG 7937' Co 0 8 C.IAX Baker guide shoe' RA tag at 8456' Short joint 8539'(29.73') 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 - 4 Baker HR setting sleeve 8590' Baker 7"ML torque master pkr 600-47 8595' (: - - WLEG 8614' 4.5"12.6#,L-80 IBT tubing. Baker Float shoe at 12062' Baker HR sleeve w extension 8798' Baker HMC liner hanger - - - 8807' - - - _ Halliburton float collar 8809' - _ - - Halliburton float shoe \ - - - - - 8892' `111 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. Organizing RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~.WINDY Scanning Preparation ~ x 30 = _ O · n Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other III Illllllllll II III BY: BEVERLY ROBIN VINCENT SHERYL ~NINDY DATE: Isl Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA,~~ERE FOUND: RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked 12/10102Rev3NOTScanned.wpd .~ ,~::-:-~~',~ . MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 20012t0 MD 12127 . ""- 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. MILNE PT UNIT SB J-23LI Operator BP EXPLORATION (ALASKA) INC 3718 ~ Completion Dat 10/7/2000 ,,,'"- Completion Statu 1-OIL _ Current Status 1-OIL APl No. 50..029-22970..60..00 REQUIRED INFORMATION Mud Log N._~o Sample N.._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Interval Log Log Run Name Scale Media No Start Stop 43 12073 (data taken from Logs Portion of Master Well Data Maint OH I Dataset CH Received Number Comments Open 8/10/2001 10265 "43-~207~ L L L L D D ~R R ic c 43 12073 MD GPJ ROP/RES 5 FINAL 10161 10387 TVD GP-J RES 5 FINAL 8848 9005 ,,1~ 1 FI NAL 43 12073 (-~Vefificafion FINAL ;~ FINAL 43 12073 Open OH OH OH OH oh 8/2/2001 5/1/2001 5/1/2001 8/2/2001 8/2/2001 8/20/2001 10201~t/3-12073 10161-10387 BL, Sepia 8848-9005.91 10201 ~4'~-12073 Digital Data LIS/Verification, Paper Copy 10265 ~'-12073 digital data Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis ~ Re.c.~.iv~.d ? Interval Start Stop Sent Received Daily History Received? Formation Tops Dataset Number (N Comments Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 10, 2001 RE: MWD Formation Evaluation Logs - MPJ-23 L1, AK-MM-00178 MPJ-23 LI: LIS Data / Digital Log Images: 50-029-22970-60 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 69.00 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 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 L1, 1 LDWG formatted Disc with verification listing. APl#: 50-029-22970-60 August 1, 2001 AK-MM-00178 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 AU0 0 Z 001 alada Oil a Oas C~. Commis~n STATE OF ALASKA ALASK ,JIL AND GAS CONSERVATION COM ~,5' ION 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. 200-121 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~-----.-.,._ 50-029-22970-60 4. Location of well at surface :":":'"': ..... T,'.'°'~' . vt~,,r.~ I. Unit or Lease Name 2685' NSL, 3390' WEL, SEC. 28, T13N, R10E, UM ~ ,r-:;' -- ~-; '~ Milne Point Unit At top of productive interval 2924' NSL, 4982' WEL, SEC. 29, T13N, R10E, UM .../-O_~ At total depth i ....' ~;?~3-~:" i '~; . ;~. Well Number 2997' NSL, 3250' WEE, SEC. 30, T13N, R10E, UM ' '""' ''-''''' ....- -~3 MPJ-23L1 1'~1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Milne Point Unit / Schrader Bluff KBE = 62.30' ADL 025517 12. Date Spudded 9/28/2000 113' Date T'D' Reached 114' Date COmp'' Susp'' Or Aband' 9/30/2000 10/7/2000 115' water depth' if OffshOre N/A MSL I' 16. No. of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 12127 3718 FTI 12127 3718 FTI [] Yes [] NoI N/A MOI 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 2o" 54.5# K-55 28' 108' 30" 260 sx Arctic set (Approx.) 7" 26# L-80 / N-80 29' 8569 9-7/8" 1100 sx Articset III, 542 sx Class 'G', 260 sx Arcticset Lite III 4-1/2" 12.6# L-80 8590' 12126' 6-1/8" Uncemented Slotted Liner 24. Perforations pp. en to, P.roducti.or~ (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s~ze ana number) ,, 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 8680' - 12082' 3788' - 3719' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8595' Set Whipstock Packer 8595' Set Guide-stock on top of Packer 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 I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 2~. 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. C0mmissior Anchorage 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' RECEIVED DEC 0 7 2000 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foreg~.°ing is true and correct to the best of my knowledge Signed TerrieHubb,e,~j~' ~ Title TechnicalAssistant Date MPJ-23L1 200-121 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 AN~) 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 .. EL. E I.V E IJ' · . . · , BP . Page I of 12 AMOCO DEC 0 7 2000 .. Operations sum.ma Report " ... '- . . ~laska 0il & Gas Cons. Commissar. Legal Well Name: MPJ-223 A,~horug~ Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/712000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ................ ... , ..... , , . . ..... . . :.i...;.;.!i:::D~te'..~:.......~:..:=.,.F~'~..~':~:. :..;.~u~., .;":.~aSk: :: cS(~dbe.:: P. haS~':.=. "i':.': '=. ~':..".:.".'::' .:' :: ':-:. '. "..DesCripti0r~ of. Operations' '..' .-.'.'i:'i ;::-:.. ::.; ." ~:".' ". 9/7/2000 18:00 - 00:00 6.00 MOVE PRE Rig down - Move rig Milne Point F-Pad to Milne Point J-pad 918/2000 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 918100 - 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 NT1 Pm-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 9/912000 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 9-718" Hughes MXC-IMill tooth bit and Sperry 6?" motor wi 9-5/8" stablizer sleeve - Adjust motor to 177 BH - Pick up Sperry MWD ! 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? 1100 below 700' - Continue Directional drill to 1875' at 00:00 hrs - Art 7.5 hrs, Ast 7.0 hrs, Average Rop 122 ffJhr - maintain Viscosity 120 to 150 sec/qt - maintain mud wt. < 9.2 ppg 9110/2000 00:00 - 02:30 2.50 DRILL INT1 Directional drill from 1875' to 2216' building angle at 3.571100 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 BI-IA - 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 Ki:Li- i V i-ij . BP AMOCO Page 2 of 12 DEC 07 000 Operations Summa Report Alaska 0il & Gas Cons. C0mmissi(': Legal Well Name: MPJ-223 An~hU[~'tJu 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 i.Task, c,S'(~db,e' :.'PhaSe. ':. ::'i ." .;mi m:~ ..' ' ' m, 1' ' ' :' :DeScdpti0n.of.Operati0ns'=l'..::.::':: .-; .:':'.' i:; .:':'.." '.'.' "!::. 9110/2000 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 I GR I 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 0.501 DRILL INT1 Finish cutting bad ddll 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 BI-IA. Stood back MWDILWD and motor. 03:00 - 03:30 0.50 DRILL OTHR INT1 Pick up 9-718" Smith roller cone hole opener & 9-718" 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 BI-IA. 16:30 - 18:00 1.50 DRILL INT1 Make up BHA~ Change jets in Bit to 3118's 1110 - Program Sperry GR ! Res I PWD / MWD - Orient MWD - Sperry motor 6? with 9 518'° 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, Pst .5 hrs, Average Rop 255 ft/hr - Pumping 600 gpm 2200 psi, 100 rpm with 10,000 fi/lb torque - Maintain mud wt. <9.2 ppg 9112/2000 00:00 - 05:00 5.00 DRILL INT1 Continue Directional ddlling 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: 11/28/20(X) 8:42:57 ,Nd · BP AMOCO I~ E C E IV.E~ ~ o, ~ · . Operations .Summa Report. D[C 0'7 t00'0 .' .... . Legal Well Name: MPJ-223 '~,laska 0il & Gas Cons. Col~m~ss, Well Name: MPJ-223 Spu~.a~jl9/2000 Common Event Name: DRILL+COMPLETE Start: 9/712000 End: 10/712000 Contractor Name: DOYEN Rig Release: Group: RIG Rig Name: DOYEN 141 Rig Number: "Date" 'FrOm TO,.:.: =Hou~:: :':.Task.:'. 'SUb' :.~phaSe!'.~;i.':..';.,'.::..::':.:";".':!..:':' :.:: :.:: '.. :.Description °f'.O'pemfi.onS'. ' :. .'. ' ::'Code · '. ' ' 9/12/2000 09:00 - 14:30 5.50 DRILL INT1 Directional 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 INT1 'Continue directional drilling 5944 to 6475' - Pumping 596 gpm 2500 psi - Torque 15,000 fi/lb 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 roam 6125-5945, 5715-5620, 5430-5145' - due to tight hole & swabbing, Drag 30K - No problem above 4860' - Normal plu 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 Bamid 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 Rep 196 fi/hr 9113/2000 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 ft~ 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 Cimulate high vis weighted fiber sweep around - Cimulate 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 - Plu 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, Ast 2.0 hrs, Average Rep 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? 1100 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 mt 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 9115/2000 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 roaming from 4,000' to 8,902'- Torque at TD did not decrease 17:00 - 20:00 3.001 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 KELi:iVi:U . BP AMOCO DEC .0 -'7r. U'~00nPage 4 of 12 · ".' .. ·Operations Summary Report · '~,laska 0il & Gas C0,s. c0mmms o, Legal Well Name: MPJ-223 Ancho~u Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/712000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ......::i:Date:.: :..,:.:i. From..L..TO. -H'ours ;:~:Task; ~b~'i :':...Phase.' .... i'..: :.:-... .. DescriPtion of oPerationS..:~ :.. ':. i:.::..:: .:-'..... .. .: '~1~1 ..:.:... ". ...": .,!, . ., ' . .. ...... . ..... .. . .. ...-"'. 9115/2000 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 9116/2000 00:00 - 01:00 1.00 DRILL INT1 Lay down Hole opener BI-IA & 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/ex 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 Tam 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 9117/2000 100:00 - 01:00 1.00 CEMT INTI Finish cementing with 260 sx ASIII lite mixed at 10.7 ppg - Yield 4.44 cflsx - 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 BOPSUI; 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 BOPSUI; 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 its 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 I tLEiVt: ' ' BP AMOCO : Page'5:of 12 DEC 07 tO00 Operations Summary Report. · ,~1~.~.1~ 13il R, ~as COl'IS. C01~lmissl(, Legal Well Name: MPJ-223 Anchorage Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/712000 End: 10/7/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: .... . Sub ... '.PhaSe :' ' Description.::of 0pemti'o~s· :: .'. :.: .:.;. :' .:'- .:.:'. ,. ::~; :.:.. ...:Date''. . ... '":From.~To... ... ... .HoUrs.::: ..~..... .... .... :.....;:TaSk'". Code..... ..,.. ... ''......... ,...... .: ........:......~.::.......~.....:,...:...~::..:.~....::...::~:;.r.;~:.:. · .....:.::::..:,.....::.~...:. 911812000 08:00 - 11:00 3.00 DRILL PROD1 Pick up Sperry 4?" ABI motor wi 1.507 BH - MAI Sperry 4? GR I Res I MWD I PWD - Orient and program logging tools - Make up Smith 6 118" 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' 7VD with 9.0 ppg mud in hole - EMVV 11.0 ppg - Ok 23:00 - 00:00 1.00 DRILL PROD1 Pump 35 bbl$ 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 911912000 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 tt 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 dean 15:30 - 16:30 1.00: DRILL I 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 f~ lbs torque. 9/21/2000 00:00 - 02:30 2.50 DRILL PROD1 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 tt 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 Cimulate 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 stands in open hole. In cased hole data was mcoreded 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 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 MVVD. 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. ^rt-5.0 Printed: 11/28/2000 8:42:57 AM O? Summa R port · ~laska 0il & Gas Cons. ~mrn~ss,, Legal Well Name: MPJ-223 Anc~0mge Common Well Name: MPJ-223 Spud Date: 9~9~2000 Event Name: DRILL+COMPLETE Sta~: 9~/2000 End: 10~/2000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON t41 Rig Number: . . .... . · . . . ......... ...Date'::'.:..:... 'Fro~ ~'~To: .;H'ou~': Task .. i.~e ~.Phase..'' .: ;: '.....~??.;..'..~:...:.: :.':DeScription.Of'Opemti0ns....': ....... ..:... ... · .. . .=,-'.. :'~ . '.::~':~ .. . ' . 9~2~000 ~:00 - 15:00 11.00 DRILL PROD1 hm, ~t-2.0 hm. Rop=97 Fph. 250 gpm with 3150 psi, 60 ~m, 7,000 ff lbs toque. 15:00 - 17:00 2.00 DRILL PROD1 Cimulate hole clean. Two boEoms up. 17:00 - 19:00 2.00 DRILL PROD1 Mon~or ~ll-static. Trip out of hole to ~sing sh~. Maximum drag ~10,~0. No problems. 19:~ - 20:30 1.50 DRILL PROD1 Drop ESS and pump down THp in hole ~97' and take che~ shot ~r jo~s. 20:30 - 23:00 2.50 DRILL PROD1 Mad pass 8900'-8300' for ~ffing packer and whipsto~. Maximum s~ 300 ~h. '2~:00 - 00:00 1.00 DRILL PROD1 Pump d~ job and pooh. 9~3~000 00:~ - 03:00 3.00 DRILL PROD1 Pooh to bha. Do, load MWd. 03:00 - ~:00 1.00 DRILL PROD1 ~ ~D and motor. No ESS suwey. ~:00 - 05:00 1.00 DRILL PROD1 ~U hole o~ner bha. 05:00 - 09:00 4.00 DRILL PROD1 Tih ~th hole opener assembly to ~sing shoe. 09:00 - 10:30 1.50 DRILL PROD1 .Cut drill line and sewi~ top drive. 10:~0 - 21:00 10.50, DRILL PROD1 Wash and roam to boEom with hole opener. The last 2000' the toque increased from 5~,000 ff lbs to 8-9,000 ff lbs. Rotated at 100 roms, 400-500 ~h, ~0 gpm w~h 3500 psi. 21:00 - 23:30 2.50' DRILL PROD1 Pump s~ep around and circulate hole clean(no ex~ssive cuttings). Spot 300 bbls new mud in open hole. 23:30 - 00:00 0.50~ DRILL PROD1 Monitor well-static. Pooh m~ing data(up, down, rotating ~) eve~ 5 ;stands. No hole problems, no ex~ssive drag. 9/24~000 00:00 - 01:30 1.50 DRILL PROD1 Finish pooh to ~sing sh~ m~rding data. No hole problems. 01:30 - 03:30 2.~ DRILL PROD1 Drop ESS and take ~eck shot at 97~'. Pooh to ~sing shoe. 03:30 - 08:00 4.50 DRILL PROD1 Pump d~job and pooh m~ing data( up, down, and m~ting ~) i eve~ 10 stands. 08:00 - ~:30 1.50 DRILL = PROD1 ~D hole o~ner bha and mt~eve ESS. Go~ suwey. 09:30 - 11:00 1.50 DRILL PROD1 Pick up and s~nd ba~ 21 4-3~4" drill ~llam. 11:00 - 12:00 1.00 CASE PROD1 Rig up to mn 4-1~" sloEed liner. Pm job sa~ meeting. 12:00 - 14:00 2.00 ~SE PROD1 ~Make up and mn 81 j~ sloE~ liner. 14:~ - 19:00 5.~' CASE PROD1 ~Change e~vatom a~ run 2-7~8" inner string, spa~ out and make up Baker liner hanger. 19:00 - 19:30 0.50 CASE PROD1 Cir~late ~ci~ of liner. 19:30 - 00:00 4.50 CASE PROD1 Run 4-1~" liner on 3-1~" drill pipe at 90 ~m. Sta~ed geffing sti~y on boffom while running drill ~llam. Only mn 3 s~nds of d~ll ~llam and sw~ched back to drill pipe-~king too long with dog ~llam and ba~ing out I~ sub. 9/25~2000 00:00 - 00:30 0.50 CASE PROD1 Finish mnnning liner and land on boffom. 00:30 - 01:30 1.00 CASE PROD1 Break cimulation with good mtutrns and drop ball. 01:30 - 02:00 0.50 CASE PROD1 Set liner hanger with 1800 psi and release seffing tool at 2800 psi. AEempt to shear out ball but circulated with 4000 psi at 7bpm. 02:00 - 11:00 9.00 CASE PROD1 Pump d~ job and pooh. ~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 ~SE PROD1 Pull test plug and set wear ring. 16:30 - 18:00 1.50 CASE PROD1 Make up Baker Toque Master Pa~er ~sembly and running tool 18:00 - 22:00 4.00 CASE PROD1 Trip in hole with pa~er assembly 22:00 - 00:00 2.00 ~SE PROD1 Rig up Schlumbe~er and Hh with GR logging tool. Could not get below 80' ~h the mllem. Pulled o~ of hole and removed mllem. THp ba~ in hole with GR I~ging tool. Sat down at 2700'. 9~6~000 00:00 - 02:00 2.00 CASE PROD1 Affempt to pump down Gr logging tool. Pumped at 1 bpm with 330 psi. The tool only moved down hole from 2500'-2700'. Did not want to in.ease pump rote for fear of seffing the pa~er off depth. Discussed Printed: 11/28/2000 8:42:57 AM RE£EiYE[3 : BP AMOCO Page 7 of 12 Operations. Summary Report DFC 0 7 2000 .. 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: 9126/2000 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 1.001 CASE OTHR PROD1 Slip and cut drill line. 11:00 - 14:00 3.001 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, 4-112" 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 1-7116" 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 i 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 3-112" 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 1 OK right hand troque in string to free mill. 14:30 - 18:00 3.50 CASE PROD1 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 ' ' Operations Summary Report DEC 0 7 2000 Alaska ~il 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 444 Ri9 Number: ... . . . .... ...... . ........ : . .. :..'". ::.~'Date'i .... From ', To '.Hours Task "Sub' ., .Phase'.:. '.' :':.:.."..i.:'.-:. :.'.":'.'?.:.::'. :."i'.'::~'.: D~S'cription".0f,.oPerati'on's.~'::.'~ '.:.... i.'?" · '. (:;ode: ' ~:~:::":::..:.. :"'-.. i".. ' ":.":.'.: .' .... ,:.. "' . ..... 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 - 22i30 2.50 CASE PROD1 Observe well. Pump slug and pulled out of hole with milling assembly. Stood back drill collars and laid down milling assembJy. 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 1.5'7, 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 BI-IA #11. 01:30 - 04:00 2.60 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. VVOB 3-6K 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 (~ 2600 psi, 60 RPM at 5500 ffibs torque. Displaced hole with new mud at 9000' while drilling ahead. Rot hrs 7.10 hfs Sliding hfs 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 9616' to 8540' (Top of whipstock at 8599'). No problems. 19/29/2000 00:00 - 19:00 19.00 DRILL PROD2 Directional drill from 9615'- 11049' as per geologist. WO9 1-5K, 60 RPM at 6500 ffibs torque, 250 gpm at 2700 psi. 19:00 - 20:30 1.50 DRILL. PROD2 Pumped 26 bbls high vis sweep and circulated hole clean. Significant . increase across shakers with sweep. 20:30 - 22:00 1.50 DRILL PROD2 Made a 16 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, 260 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, 260 gpm at 3040 psi. ART 7.6 hfs 4.10 hrs. 17:30 - 20:00 2.60 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 Kf.L iV i BP AMOco Page 9 of 12 DEC 07 2000 Operations Summa Report. Cons. '. Alaska 0il & Gas Legal Well Name: MPJ-223 ,Common Well Name: MPJ-223 Spud Date: 9/9/2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/712000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: · ' ';Datei:i~ ?:.~.ii. Fr~m'.~'!'To.'.:.H0u~::: !,i~.T~sk':' 'c.S,_~dbe. :~' Phase :'..:....i"~: ..... . .:.. ~' .: ~.::' Descdpfi0nof. Operations :'..i... :'..= .' i.'=: .:...i...:':'. ' ':" ".':i":'" ' .":" "' !' . i.:,..'?:'.:":'.- .' ; ':'.::-!:.':.' ":.' ':L." ·: ".~ '. "U :......, :.... i: ' ..... .... ' . . '.".. 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 9564' 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. 1011/2000 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 'Tdp 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 fUbs 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. i 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 1-314" 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 4-112" 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 3/8" thick. Laid down tubing and rigged down tongs. Printed: 11/28/2000 8:42:57 AM KLLLiYLi BP AMOCO ,,,~P.a.ge 10 of 12 .DEC07zu00 . · .. Operations Summary Report ... Alaska 0il & Gas Cons. C0~llaJSS10r 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'..:.'''':... :....~.:..............Fr0m',.To... ...... ..... 'Hours..:. Task .... cS°Udbe;. Ph'ase ' ..='" . ..... "DeScriptiOn'Of:OperatiOns.' ..i: ~':!:.. .: :' .:..:.. :'::'= :.. ' :.. .". . 10/2/2000 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 12000 psi high for 110 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. 10/3/2000 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 87 jts 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 jts of 2-718" Fox tubing for interstdng. 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 3-1/2" 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 1-114" ball and pumped down at 3 bpm and sloweri 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 & 2 318" 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 hrs 1014/2000 00:00 - 01:00 1.00' CASE PROD2 Continue Pooh with Baker HR liner running tool and 2-718" interstring - stand back 3-1/2" drill pipe 01:00 - 04:00 3.00 CASE PROD2 Lay down running tool and 110 its interstring - Clear dg 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 2.00i FISH PROD2 TIh with Fishing Assembly to +1- 2200' - Fill pipe and shallow test MWD - MWD failed Printed: 11/28/2000 8:42:57' AM B.P AMOCO DFC 0 7 ~e 11 of'12 Operations Summary Report Alaska 0il & Gas Cons. CommlSSlon 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,..' '".:':,'...." i:i'....".' Description of oPeratiOns..... .... :..... .COde: ... ~. ~,,.. ...... '.,. ..... 1014/2000 07:00 - 08:00 1.00 FISH BI-IA PROD2 Pooh for MWD failure 08'00 - 09:30 1.50 FISH BHA PROD2 Change out Spen7 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 jars & 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 3-1/2" S-135 drill pipe - +/- 6000' at 00:00 hrs 10/5/2000 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 4-314" collars. 03:30 - 04:00 0.50 STWHIPI 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 1016/2000 00:00 - 06:30 6.50 CLEAN COMP Finish Pooh lay down 3 112" drill pipe and drill collars 06:30 - 07:00 0.50' RUNCO~ 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 RUNCO~I COMP Safety meeting with drill crew on running completion 09:00 - 18:00 9.00 RUNCOI~ ~1 COMP Make up Baker 7" x 4 1/2" S-3 packer & tail pipe assembly - Install Baker Sentry ternp & pressure gauge one jt above packer - Run in Hole with completion, install LaSalle clamp every connection around 114" I TEC cable 18:00 - 18:30 0.50 RUNCOI~ ~ COMP I Safety meeting with night ddll 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 jts 7,777.3' ,,, Printed: 11/28/2000 8:42:57 AM BP AMOCO· [,L" (.i [ ~(,iP.,a~ge.. 12 of 12 ,~j t.. ,., ,.Ii ' .Operations Summa Report Na ka Oil & Gas Conu. A', I _~.. Legal Well Name: MPJ-223 ,Common Well Name: MPJ-223 Spud Date: 9~9~2000 Event Name: DRILL+COMPLETE Start: 9/7/2000 End: 10/712000 Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: · . .. .i'..Date': :: ··From.·- To' .HoUm' 'Task:I' '~oUdbe Phase' ...: Description of OPerations .i:.' i:i. . :'. ::.':....".':. .. .' ' .. ' . '.. .": ' .... . . · ' .: 1016/2000 23:00 - 00:00 1.00 RUNCOI~ ! COMP 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~ ~ 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 1 114" ball on rod with roller with 2 718" 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~ COMP Rig Up HES .105 wireline unit 06:00 - 08:00 2.00 RUNCO~ 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~I COMP Pooh with slick line - Recovered ball & rod - PJD 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 11:30 - 13:00 1.50 RUNCOI~! COMP Nipple down and set back 13 518" BOP stack 13:00 - 18:00 5.00 RUNCOI~ COMP Nipple up FMC Schrader Bluff 11" 5K x 3 1/8" 5K tubing head adapter & 3 118" 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 RUNCOlt I 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~ t COMP Install BPV with lubricator - Rig down lines - Secure well - Rig Released at 24:00 hrs 10/7100 Printed: 11/28/2000 8:42:57 AM 10202597454 North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-223 L 1 Surveyed: I October, 2000 SURVEY REPORT 17 October, 2000 Your Rsf: API-500292297060 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: svy9629 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8485.58 73.270 271.090 3678.64 3740.94 8570.00 72.750 271.820 3703.31 3765.61 8583.25 73.820 271.960 3707.12 3769.42 8610.53 76.500 272.250 3714.11 3776.41 8645.92 80.230 272.960 3721.24 3783.54 8678.24 84.268 272.581 3725.60 3787.90 8705.44 87.909 269.849 3727.46 3789.76 8739.93 92.524 273.370 3727.33 3789.63 8772.75 93.265 273.734 3725.67 3787.97 8801.24 91.662 273.905 3724.45 3786.75 8836.04 89.572 277.864 3724.07 3786.37 8868.73 89.446 276.813 3724.35 3786.65 8896.61 89.572 278.306 3724.59 3786.89 8932.73 88.955 275.804 3725.05 3787.35 8966.10 90.308 273.526 3725.27 3787.57 8994.55 90.680 272.957 3725.02 3787.32 9030.61 91.170 271.325 3724.44 3786.74 9060.52 90.000 269.583 3724.14 3786.44 9095.00 90.863 265.007 3723.88 3786.18 9122.00 91.108 264.153 3723.41 3785.71 9155.37 90.864 264.153 3722.84 3785.14 9184.26 91.909 264.733 3722.14 3784.44 9252.41 94.133 265.817 3718.55 3780.85 9280.51 94.005 2671018 3716.55 3778.85 9315.48 93.391 266.073 3714.30. 3776.60 240.15 N 6792.90 W 6015275.05 N 545132.54 E 242.20 N 6873.61 W 6015276.54 N 545051.82 E 242.62 N 6886.29 W 6015276.87 N 545039.13 E 243.59 N 6912.64 W 6015277.65 N 545012.78 E 245.17 N 6947.26 W 6015278.99 N 544978.14 E 246.71 N 6979.24 W 6015280.31 N 544946.15 E 247.29 N 7006.36 W 6015280.70 N 544919.03 E 248.26 N 7040.83 W 6015281.43 N 544884.56 E 250.29 N 7073.54 W 6015283.23 N 544851.83 E 252.18 N 7101.94 W 6015284.93 N 544823.42 E 255.75 N 7136.55 W 6015288.25 N 544788.79 E .259.92 N 7168.97 W 6015292.20 N 544756.34 E 263.59 N 7196.60 W 6015295.68 N 544728.68 E 268.03 N 7232.44 W 6015299.86 N 544692.81 E 270.74 N 7265.70 W 6015302.34 N 544659.54 E 272.35 N 7294.10 W 6015303.75 N 544631.12 E 273.70 N 7330.13 W 6015304.85 N 544595.08 E 273.93N 7360.04 W 6015304.88 N 544565.18 E 272.31 N 7394.47 W 6015303.01 N 544530.76 E 269.76 N 7421.34 W 6015300.27 N 544503.90 E 266.36 N 7454.53 W 6015298.64 N 544470.74 E 263.56 N 7483.28 W 6015293.65 N 544442.01 E 257.96 N 7551.10 W 6015287.57 N 544374.23 E 256.20 N 7579.07 W 6015285.62 N 544346.27 E 254.10 N 7613.91 W 6015283.28 N 544311.45 E Dogleg Rate (°/lOOft) 1.031 8.139 9.878 10.721 12.548 16.720 16.829 2.515 5.658 12.863 3.238 5.374 7.134 7.940 2.389 4.725 7.016 13.505 3.290 0.731 4.137 3.629 4.288 3.218 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 6796.90 6877.63 6890.32 6916.69 6951.34 6983.35 7OLO.48 7044.95 7o77.71 71o6.15 714o.84 7173.36 72Ol.O9 7237.03 7270.35 7298.79 7334.84 7364.74 7399.12 7425.91 7459.00 7487.66 7555.30 7583.22 7617.98 Tie-on Survey Window Point Continued... 17 October, 2000 - 23:39 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth. Northings ° Eastings Northings Eastings (ft) - (~t) (~t) (~t) (~t) 9348.04 93.018 266,239 3712,48 3774,78 . 9377,36 92,835 265,855 3710,98 3773,28 9409.42 92,280 266,381 3709,55 3771,85 9442,38 93.136 266,405 3707,99 3770,29 9470,85 93.016 265,588 3706,46 3768,76 9504,40 92,837 266,142 3704,75 3767,05 9537,34 91,725 266,028 3703,44 3765,74 9565,79 90,492 267,642 3702.89 3765,19 9596.81 91,110 268,550 3702,46 3764,76 9633,40 90.246 269.577 3702,02 3764,32 9662.19 89,937 269,329 3701,98 3764,28 9696,66 91,291 268.464 3701,61 3763,91 9729.43 91.354 269,151 3700,85 3763,15 9758,41 90,863 268,787 3700,29 3762,59 9792,92 89,874 268,156 3700,07 3762,37 9825,43 91.172 268,216 3699,77 3762,07 9854.25 91.479 268,752 3699,11 3761,41 9888,75 92,155 271,413 3698,01 3760,31 9921,43 91.662 269,521 3696,92 3759,22 9949,84 91,046 269,017 3696,25 3758,55 9984,91 91,108 269,911 3695,59 3757,89 10017.89 91.045 270,226 3694,97 3757,27 10046,51 90,183 270.520 3694,67 3756,97 10080.64 90,246 271,280 3694,54 3756.84 10113,59 89,754 271,099 3694,54 3756,84 251,92N 7646,34W 6015280,87N 544279,03 E 249,90 N 7675,55W 6015278,65 N 544249,84 E 247.73N 7707,51W 6015276,26 N 544217.90 E 245,66 N 7740,37W 6015273,96 N 544185.06 E 243,68 N 7768,72W 6015271,78 N 544156,71 E 241.26 N 7802,14W 6015269.13 N 544123.31 E 239,02N 7834,98W 6015266,65 N 544090,49 E 237,45N 7863,38W 6015264.88 N 544062,10 E 236~1N 7894,38W 6015263,64N 544031.11 E 235,82N 7930,96W 6015262,78 N 543994.53 E 235,54N 7959,75W 6015262,31N 543965.75 E 234,88 N 7994,21W 6015261,40 N 543931,29 E 234,20 N 8026,96W 6015260,49N 543898,54 E 233,67N 8055,93W 6015259,77 N 543869.58 E 232,75N 8090,43W 6015258,61N 543835,09 E 231,73N 8122,92W 6015257,36 N 543802,61 E . 230,96N 8151,72W 6015256,39 N 543773,81 E 231,01N 8186,20W 6015256,20 N 543739.33 E 231,28 N . 8218,86W 6015256,24N 543706,67E 230,92 N 8247,26W 6015255,68 N 543678,27 E 230,59 N 8282,32W 6015255.11N 543643,22 E 230,63 N 8315,30W 6015254,92 N 543610,24 E 230,81N 8343,92W 6015254,90 N 543581,62 E 231,35N 8378,04W 6015255,20 N 543547,50 E 232,03 N 8410,98W 6015255,66 N 543514,55 E Dogleg Rate (°/~00ft) 1.254 1.449 2.384 2.598 2.896 1.733 3,393 7,138 3,541 3,668 1.376 4.661 2.105 2.109 3.399 3.997 2,143 7,954 5,980 2,801 2,555 0.974 3.182 2.234 1.591 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 7650.35 7679,50 7711.38 7744.17 7772.47 7805.81 7838.57 7866,92 7897,88 7934,43 7963,20 7997.64 8030,36 8059,30 8093,76 8126.22 8154,99 8189,46 8222,11 8250,49 8285,53 8318.49 8347,10 8381,23 8414,18 Comment Continued,.. 17 October, 2000 - 23:39 .3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10141.05 90.862 271.527 3694.39 10174.34 91.536 272.848 3693.69 10206.86 90.554 272.895 3693.10 10236.51 89.817 270.952 3693.01 10269.38 89.509 271.622 3693.20 10302.34 89.263 271.824 3693.55 10331.59 89.874 271.385 3693.77 10365.45 90.309 272.929 3693.72 10398.24 90.000 272.907 3693.63 10427.03 90.800 272.984 3693.43 10459.76 90.617 272.553 3693.02 10492.22 91.599 272.787 '3692.40 10522.95 91.601 272.864 3691.54 10556.89 92.772 273.104 3690.24 10587.28 92.464 273.341 3688.86 10617.67 92.712 274.794 3687.48 10650.92 92.218 273.438 3686.05 10684.22 92.093 273.318 3684.80 10713.69 91.357 270.721 3683.91 10747.39 91.600 273.692 3683.04 10779.72 91.480 273.317 3682.17 10808.42 91.172 273.451 3681.51 10843.13 90.680 272.320 3680.95 10874.93 90.372 272.366 3680.66 10904.78 91.481 271.332 3680.18 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3756.69 232.66 N 8438.44W 6015256.09 N 543487.09 E 3755.99 233.93N 8471.69W 6015257.13 N 543453.83 E 3755.40 235.56 N 8504.17W 6015258.54 N 543421.34 E 3755.31 236.56 N 8533.80W 6015259.32 N 543391.71 E 3755.50 237.30 N 8566.66W 6015259.83 N 543358.84 E 3755.85 238.29 N 8599.60W 6015260.59 N 543325.89 E 3756.07 239.11N 8628.84W 6015261.21N 543296.65 E 3756.02 240.38 N 8662.67W 6015262.25 N 543262.81E 3755.93 242.05 N 8695.42W 6015263.69 N 543230.05 E 3755.73 243.53 N 8724.17W 6015264.97N 543201.29 E 3755.32 245.11N 8756.86W 6015266.32 N 543168.59 E 3754.70 246.62N 8789.28W 6015267.61N .543136.16 E 3753.84 248.14 N 8819.96W 6015268.91N 543105.47E 3752.54 249.90 N 8853.83W 6015270.44N 543071.59 E 3751.16 251.61N 8884.14W 6015271.93 N 543041.27 E 3749.78 253.76 N 8914.42W 6015273.87 N 543010.97 E 3748.35 256.15 N 8947.55W 6015276.03 N 542977.82 E 3747.10 258.11N 8980.77W 6015277.76 N 542944.59 E 3746.21 259.14 N 9010.21W 6015278.59 N 542915.15 E 3745.34 260.44N 9043.87W 6015279.65 N 542881.48 E 3744.47 262.42N 9076.13W 6015281.40 N 542849.21 E 3743.81 264.11N 9104.77W 6015282.90 N 542820.56 E 3743.25 265.86 N 9139.43W 6015284.40 N 542785.88 E 3742.96 267.16 N 9171.20W 6015285.48 N 542754.10 E 3742.48 268.12 N 9201.03W 6015286.24N 542724.27 E Dogleg Rate (°/lOOft) 4.326 4.454 3.023 7.009 2.243 0.966 2.572 4.737 0.945 2.792 1.431 3.110 0.251 3.522 1.278 4.846 4.337 0.520 9.156 8.843 1.217 1.170 3.553 0.979 5.079 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 8441.64 8474.92 8507.43 8537.o7 8569.94 86o2.90 8632.15 8666.Ol 8698.79 8727.57 8760.29 8792.73 8823.44 8857.35 8887.69 8918.o2 8951.21 8984.47 9o13.92 9047.60 9079.90 9108.58 9143.27 9175.07 9204.91 Continued... 17 October, 2000 - 23:39 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref'. API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 10939.54 91.047 271.654 3679.41 10972.20 91,971 271.095 3678.55 11001.83 91.971 271.860 3677.53 11035.82 91.781 270.313 3676.42 11065,39 91.600 271,461 3675.54 11094.04 90,246 270.559 3675.08 11126.06 88.954 271.227 3675.31 11158.84 87.967 269,614 3676.19 11191.11 88,644 271,230 3677.14 11224.92 87.600 270,878 3678.25 11257.81 86,610 271,189 3679.91 11286.42 86.308 270.265 3681.68 11320.80 87,105 270.033 3683.65 11354.28 88.156 269.110 3685.04 11382.03 88.520 269.353 3685.84 11416.28 90.863 268.864 3686.03 11449.25 91.171 271.006 3685.44 11476.89 91.781 271.776 3684.73 11511.97 91.727 271.853 3683.65 11544.84 92.216 272.178 3682.52 11573.87 91.908 272.224 3681.48 11609.42 91,972 273.629 3680.28 11640.59 90.246 274.065 3679.67 11669.09 90.063 273.499 3679.60 11702.32 92.217 275.458 3678.93 Global Coordinates Northings Eastings (ft) (ft) 3741.71 269.03N 9235.77W 6015286.90 N 542689.52 E 3740.85 269.81N 9268.41W 6015287.45 N 542656.88 E 3739.83 270.57 N 9298,01W 6015288.01N 542627.27 E 3738.72 271.22 N 9331.98W 6015288.42N 542593.31 E 3737.84 271.67N 9361.53W 6015288.67N 542563.75 E 3737.38 272.18 N 9390.17W 6015288.98 N 542535.11 E 3737,61 272.68 N 9422.18W 6015289.25 N 542503.09 E 3738.49 272.92N 9454.95W 6015289.26 N 542470.32 E 3739.44 273.~6 N 9487.20W 6015289.28 N 542438.07E 3740.55 273.78 N 9520.99W 6015289.66 N 542404.28 E 3742.21 274.37N 9553.83W 6015290.03 N 542371.43 E 3743.98 274.73 N 9582.39W 6015290.19 N 542342.88 E 3745.95 -274.82N 9616.71W 6015290.04 N 542308.56 E 3747,34 274.57N 9650.16W 6015289.56 N 542275.11 E 3748.14 274.20 N 9677.89W 6015288.99 N 542247.38 E 3748.33 273.67N 9712.14W 6015288.22 N 542213.14 E 3747.74 273.63 N 9745.10W 6015287.95 N 542180.18 E 3747.03 274.30 N 9772.72W 6015288.43 N 542152.55 E 3745.95 275.41N 9807.77W 6015289.30 N 542117.50 E 3744.82 276.56 N 9840.60W 6015290.22 N 542084.66 E 3743,78 277.68 N 9869.59W 6015291.14 N 542055.66 E 3742.58 279.49N 9905.07W 6015292.70 N 542020.17 E 3741.97 281.58 N 9936.16W 6015294.58 N 541989.06 E 3741.90 283.46 N 9964.60W 6015296.26 N 541960.61 E 3741.23 286.06 N 9997.72W 6015298.62 N 541927.48 E Dogleg Rate (°/100ft) 1.555 3.306 2.580 4.583 3.929 5.678 4.542 5.767 5.427 3.258 3.155 3.392 2.414 4.176 1.577 6.988 6.563 3.553 0.268 1.786 1.073 3.954 5.711 2.087. 8.761 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 9239.66 9272.31 9301.93 9335.89 9365.45 9394.09 9426.11 9458.87 9491.12 9524.91 9557.76 9586.31 9620.62 9654.05 9681.77 9715.98 9748.93 9776.56 9811.63 9844.48 9873.48 9909.00 9940.14 9968.62 10001.79 Continued.,. 17 October, 2000- 23:39 -5- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (fi) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11737,38 92.587 275.254 3677.47 3739.77 289.33 N 10032.59 W 11766.47 92.403 275.880 3676.20 3738.50 292.15 N 10061.52 W 11800.05 93.633 276.168 3674.43 3736.73 295.67 N 10094.87 W 11832.35 93.880 275.731 3672.31 3734.61 299.01 N 10126.92 W 11861.91 93.816 275.793 3670.33 3732.63 301.97 N 10156.27 W 11895.97 94.502 275.630 3667.86 3730.16 305.35 N 10190.07 W 11927.21 94.808 274.258 3665.33 3727.63 308.03 N 10221.09 W 11959.02 94.746 273.994 3662.68 3724.98 310.31 N 10252.71 W 11991.62 92.649 273.557 3660.57 3722.87 312.45 N 10285.17 W 12021.97 92.278 273.027 3659.27 3721.57 314.20 N 10315.44 W 12049.08 91.973 273.195 3658.26 3720.56 315.67 N 10342.49 W 12127.00 91.973 273.195 3655.58 3717.88 320.01 N 10420.24 W 6015301.65 N 541892.58 E 6015304.27 N 541863.63 E 6015307.55 N 541830.26 E 6015310.67 N 541798.18 E 6015313.43 N 541768.82 E 6015316.57 N 541734.99 E 6015319.04 N 541703.96 E 6015321.10 N 541672.32 E 6015323.01 N 541639.85 E 6015324.54 N 541609.57 E 6015325.83 N 541582.51 E 6015329.62 N 541504.72 E 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 12127.00ft., The Bottom Hole Displacement is 10425.16ft., in the Direction of 271.759° (True). Dogleg Rate (°/lOOft) 1.205 2.241 3.762 1.552 0.301 2.070 4.486 0.850 6.570 2.130 1.284 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 10036.75 1OO65.74 I O099.17 1O131.30 10160.72 10194.60 10225.68 10257.34 10289.85 10320.16 10347.24 10425.08 Comment Projected Survey i'1-1 Continued... 17 October, 2000 - 23:39 - 6 - DriflQuest 1,05,05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 Your Ref: AP1-$00292297060 Surveyed: I October, 2000 North Slope Alaska Alaska State Plane 4 Milne Point IdPJ Comments Measured Depth (fi) 8485.58 8570.00 12127.00 Station Coordinates TVD Northinge Eastings (~t) (ft) (ft) 3740.94 240.15 N 6792.90 W 3765.61 242.20 N 6873.61 W 3717.88 320.01 N 10420.24 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (fi) (ft) 0.00 0.00 Measured Vertical Depth Depth (ft) (ft) 12127.00 3717.88 Survey Tool Description AK-6 BP_IFR-AK 17 October, 2000- 23:39 - ?- DrillQuest 1.05.05 I IIIIIIl~ll~l~ll~l~lllllllll~llll~llllli~llll 10~02507457 North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-223 L 1 MWD Surveyed: I October, 2000 SURVEY REPORT 17 October, 2000 Your Ref: API-500292297060 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) D I iq ! E SurveyRef:svy9612 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Fastings Northings Fastings (ft) (ft) (ft) (fi) (ft) 8485.58 73.264 272.379 3680.16 3742.46 8570.00 72.750 271.820 3704.83 3767.13 8583.25 73.820 271.960 3708.64 3770.94 8610.53 76.500 272.250 3715.63 3777.93 8645.92 80.230 272.960 3722.77 3785.07 8678.24 84.268 274.096 3727.12 3789.42 8705.44 87.909 271.040 3728.98 3791.28 8739.93 92.524 271.681 3728.85 3791.15 8772.75 93.265 273.160 3727.19 3789.49 8801.24 91.662 275.015 3725.97 3788.27 8836.04 89.572 277.385 3725.59 3787.89 8868.73 89.446 275.785 3725.87 3788.17 8896.61 89.572 280.214 3726.11 3788.41 8932.73 88.955 276.707 3726.58 3788.88 8966.10 90.308 273.664 3726.79 3789.09 8994.55 90.680 272.851 3726.55 3788.85 9030.61 91.170 270.407 3725.96 3788.26 9060.52 90.000 267.758 3725.66 3787.96 9095.00 90.863 264.278 3725.40 3787.70 9122.00 91.108 263.907 3724.93 3787.23 9155.37 90.864 264.823 3724.36 3786.66 9184.26 91.909 265.320 3723.66 3785.96 9252.41 94.133 267.916 3720.07 3782.37 9280.51 94.005 268.542 3718.08 3780.38 9315.48 93.391 266.505 3715.82 3778.12 218.54N 6791.45W 6015253.45 N 545134.14 E 221.50N 6872.13W 6015255.84 N 545053.44E 221.92N 6884.81W 6015256.17 N 545040.75 E 222.88 N 6911.16W 6015256.96 N 545014.40 E 224.46N 6945.78W 6015258.29 N 544979.77 E 226.43N 6977.74W 6015260.04N 544947.80 E 227.65N 7004.84W 6015261.07N 544920.69 E 228.47N 7039.31W 6015261.65 N 544886.21E 229.85 N 7072.06W 6015262.80 N 544853.45 E 231.88 N 7100.45W 6015264.63 N 544825.05 E 235.64N 7135.04W 6015268.15 N 544790.44E 239.38 N 7167.51W 6015271.67N 544757.94 E 243.26 N 7195.11W 6015275.36 N 544730.31E 248.58 N 7230.83W 6015280.42 N 544694.56 E 251.59N 7264.06W 6015283.21N 544661.31 E 253.21N 7292.46W 6015264.63 N 544632.90 E 254.23 N 7328.50W 6015285.40 N 544596.85 E 253.75 N 7358.40W 6015264.71N 544566.95 E 251.36 N 7392.79W 6015282.08 N 544532.58 E 248.58 N 7419.64W 6015279.11N 544505.75 E 245.31N 7452.85W 6015275.6t N 544472.57 E 242.83N 7481.62W 6015272.92 N 544443.81E 238.81N 7549.55W 6015268.43 N 544375.92 E 237.94N 7577.56W 6015267.37 N 544347.91 E 236.44N 7612.43W 6015265.62 N 544313.06 E Dogleg Rate (°/lOOft) 0.879 8.139 9.878 10.721 12.970 17.458 13.509 5.035 8.601 9.080 4.909 15.892 9.858 9.979 3.142 6.912 9.681 10.398 1.646 2.840 4.005 5.012 2.268 6.072 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 6794.87 6875.60 6888.29 6914.66 6949.31 6981.31 7008.43 7042.91 7075.68 7104.12 7138.80 7171.36 7199.05 7234.90 7268.20 7296.63 7332.68 7362.56 7396.88 7423.64 7456.75 7485.44 7553.24 7581.22 7616.03 Tie-on Point Window Point Continued... 17 October, 2000- 12:03 -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (~t) 9348.04 93.018 265.320 3714.00 9377.36 92.835 264.804 3712.50 9409.42 92.280 265.948 3711.07 9442.38 93.136 266.195 3709.51 9470.85 93.016 265.421 3707.99 9504.40 92.837 267.268 3706.27 9537.34 91.725 265.330 3704.96 9565.79 90.492 268.379 3704.41 9596.81 91.110 269.675 3703.98 9633.40 90.246 268.978 3703.55 9662.19 89.937 270.311 3703.50 9696.66 91.291 266.635 3703.13 9729.43 91.354 268.269 3702.37 9758.41 90.863 269.558 3701.81 9792.92 89.874 269.145 3701.59 9825.43 91.172 268.281 3701.29 9854.25 91.479 267.694 3700.63 9888.75 92.155 272.070 3699.53 9921.43 91.662 267.278 3698.44 9949.84 91.046 269.361 3697.77 9984.91 91.108 270.336 3697.11 10017.89 91.045 271.253 3696.49 10046.51 90.183 271.990 3696.19 10080.64 90.246 271.049 3696.06 10113.59 89.754 270.551 3696.06. Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (~t) (ft) (~t) 3776.30 234.12 N 7644.85W 6015263.08 N 544280.65 E 3774.80 231.60 N 7674.02W 6015260.36 N 544251.49 E 3773.37 229.02N 7705.95W 6015257.55 N 544219.59 E 3771.81 226.76 N 7738.79W 6015255.07 N 544186.76 E 3770.29 224.68 N 7767.15W 6015252.79 N 544158.42 E 3768.57 222.55 N 7800.58W 6015250.42 N 544125~00 E 3767.26 220.42N 7833.43W 6015248.07 N 544092.17 E 3766.71 218.86 N 7861.82W 6015246.31N 544063.79 E 3766.28 218.33 N 7892.84W 6015245.57N 544032.78 E 3765.85 217.90 N 7929.42W 6015244.88 N 543996.20 E 3765.80 217.73N 7958.21W 6015244.50 N 543967.41 E 3765.43 216.81N 7992.66W 6015243.34 N 543932.97E 3764.67 215.35 N 8025.39W 6015241.66 N 543900.25 E 3764.11 214.80 N 8054.35W 6015240.91N 543871.29 E 3763.89 214.41N 8088.86W 6015240.28 N 543836.79 E 3763.59 213.68 N 8121.36W 6015239.32 N 543804.29 E 3762.93 212.67N 8150.15W 6015238.11N 543775.51E 3761.83 212.60 N 8164.63W 6015237.80 N 543741.03 E 3760.74 212.41N 8217.28W 6015237.38 N 543708.38 E 3760.07 211.58 N 8245.67W 6015236.35 N 543680.00 E 3759.41 211.49 N 8280.73W 6015236.02 N 543644.94 E 3758.79 211.94N 8313.70W 6015236.24 N 543611.97E 3758.49 212.75 N 8342.31W 6015236.85 N 543583.36 E 3758.36 213.66 N 8376.43W 6015237.52 N 543549.23 E 3758.36 214.12 N 8409.37W 6015237.75 N 543516.28 E Dogleg Rate (°llOOft) 3.810 1.865 3.963 2.703 2.747 5.524 6.779 11.558 4.628 3.034 4.753 11.364 4.989 4.759 3.106 4.796 2.298 12.828 14.733 7.644 2.785 2.787 3.963 2.763 2.125 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) Comment 7648.38 7677.48 7709.32 7742.o9 7770.38 78o3.75 7836.52 7864.87 7895.85 7932.41 7961.19 7995.60 8028.27 8057.22 8o91.7o 8124.17 8152.93 8187.39 8220.02 8248.38 8283.42 8316.4o 8345.Ol 8379.14 8412.o9 Continued... 17 October, 2000 - 12:03 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. 10141.05 90.862 271.271 10174.34 91.536 271.387 10206.86 90.554 271.844 lO236.51 89.817 273.381 10269.38 89.509 27o.791 10302.34 89.263 27o.196 10331.59 89.874 272.137 10365.45 90.309 273.153 10398.24 90.000 273.937 10427.03 90.800 274.394 10459.76 9o.617 271.318 10492.22 91.599 272.653 10522.95 91.601 272.002 10556.89 92.772 272.212 10587.28 92.464 271.896 10617.67 92.712 274.268 10650.92 92.218 273.308 10684.22 92.093 273.634 10713.69 91.357 275.125 10747.39 91.600 275.499 10779.72 91.48o 271.979 10808.42 91.172 274.287 10843.13 90.680 269.992 10874.93 90.372 273.422 10904.78 91.481 269.969 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 3695.91 3695.22 3694.62 3694.53 3694.72 3695.07 3695.29 3695.24 3695.15 3694.95 3694.54 3693.92 3693.06 3691.76 3690.38 3689.00 3687.57 3686.32 3685.43 3684.56 3683.70 3683.03 3682.47 3682.18 3681.69 3758.21 3757.52 3756.92 3756.83 3757.02 3757.37 3757.59 3757.54 3757.45 3757.25 3756.84 3756.22 3755.36 3754.06 3752.68 3751.30 3749.87 3748.62 3747.73 3748.86 3746.00 3745.33 3744.77 3744.48 3743.99 Global Coordinates Dogleg Northings Eastings Rate (ft) (fi) (°ll00ff) 214.55 N 8436.83W 6015238.00 N 543488.83 E 215.33N 8470.10W 6015238.54 N 543455.55 E 216.24N 8502.60W 6015239.23 N 543423.04 E 217.59N 8532.22W 6015240.37N 543393.42E 218.79 N 8565.07W 6015241.34 N 543360.56 E 219.07N 8598.02W 6015241.39 N 543327.61 E 219.67N 8627.26W 6015241.79 N 543298.36 E 221.23 N 8661.09W 6015243.11N 543264.53 E 223.26 N 8693.81W 6015244.91N 543231.79 E 225.35 N 8722.53W 6015246.80 N 543203.06 E 226.98 N 8755.21W 6015248.21N 543170.37E 228.11N 8787.64W 6015249.10 N 543137.93 E 229.35 N 8818.34W 6015250.14 N 543107.23 E 230.60 N 8852.23W 6015251.15 N 543073.33 E 231.69 N 8882.57W 6015252.02 N 543042.98 E 233.32N 8912.88W 6015253.45 N 543012.66 E 235.52N 8946.03W 6015255.41N 542979.50 E 237.53 N 8979.24W 6015257.19 N 542946.27 E 239.78N 9008.61W 6015259.24 N 542916.88 E 242.90 N 9042.15W 6015262.12 N 542883.32 E 245.01N 9074.40W 6015264.00 N 542851.06 E 246.57N 9103.05W 6015265.37 N 542822.40 E 247.87N 9137.72W 6015266.43N 542787.72 E 248.82 N 9169.50W 6015267.15 N 542755.94 E 249.70 N 9199.33W 6015267.83 N 542726.10 E 4.812 2.054 3.331 5.749 7.935 1.953 6.957 3.264 2.570 3.200 9.414 5.105 2.118 3.505 1.451 7.840 3.245 1.048 5.640 1.323 10.890 8.111 12.453 10.829 12.148 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 8439.55 8472.83 8505.34 8534.99 8567.85 8600.80 8630.05 8663.90 8696.67 8725.43 8758.15 8790.60 8821.31 8855.23 8885.58 8915.93 8949.12 8982.38 9011.8o 9045.42 9077.71 9106.38 9141.08 9172.87 9202.71 0 Continued... 17 October, 2000 - 12:03 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Ref: API.500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 10939.54 91.047 273.245 3680.93 10972.20 91.971 270.425 3680.07 11001.83 91.971 271.103 3679.05 11035.82 91.781 268.806 3677.94 11065.39 91.600 271.769 3677.06 11094.04 90.246 272.243 3676.60 11126.06 88.954 271.860 3676.83 11158.84 87.967 271.017 3677.71 11191.11 88.644 271.232 3678.66 11224.92 87.600 271.136 3679.77 11257.81 86.610 272.674 3681.43 11286.42 86.308 270.588 3683.20 11320.80 87.105 270.993 3685.17 11354.28 88.156 267.571 3686.56 11382.03 88.520 270.422 3687.36 11416.28 90.863 269.340 3687.55 11449.25 91.171 270.098 3686.96 11476.89 91.78i 270.224 3686.25 11511.97 91.727 273.985 3685.17 11544.84 92.216 271.037 3684.04 11573.87 91.908 271.432 3683.00 11609.42 91.972 275.751 3681.79 11640.59 90.246 275.719 3681.19 11669.09 90.063 273.185 3681.11 11702.32 92.217 275.064 3680A5. Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3743.23 250.67 N 9234.06W 6015268.56 N 542691.36 E 3742.37 251.72N 9266.69W 6015269.38 N 542658.73 E 3741.35 252.11N 9296.30W 6015269.57 N 542629.12 E 3740.24 252.09 N 9330.27W 6015269.30 N 542595.15 E 3739.36 252.23 N 9359.82W 6015269.24 N 542565.59 E 3738.90 253.24 N 9388.45W 6015270.05 N 542536.96 E 3739.13 254.38 N 9420.45W 6015270.97 N 542504.95 E 3740.01 255.21N 9453.20W 6015271.57 N 542472.19 E 3740.96 255.64N 9485.45W 6015271.97N 542439.94 E 3742.07 256.54N 9519.24W 6015272.44 N 542406.15 E 3743.73 257.63 N 9552.07W 6015273.30 N 542373.32 E 3745.50 258.44N 9580.61W 6015273.91N 542344.77 E 3747.47 258.92N 9614.93W 6015274.15 N 542310.45 E 3748.86 258.50 N 9648.37W 6015273.50 N 542277.01 E 3749.66 258.01N 9676.10W 6015272.82 N 542249.28 E 3749.85 257.94N 9710.35W 6015272.51N 542215.03 E 3749.26 257.78 N 9743.31W 6015272.12 N 542182.07E 3748.55 257.86 N 9770.94W 6015272.00 N 542154.44E 3747.47 259.14 N 9805.98W 6015273.04N 542119.40 E 3746.34 260.58 N 9838~9W 6015274.25 N 542086.58 E 3745.30 261.21N 9867.80W 6015274.68 N 542057.57E 3744.09 263.43N 9903.25W 6015276.65 N 542022.10 E 3743.49 266.55 N 9934.26W 6015279.55 N 541991.07 E 3743.41 268.76 N 9962.67W 6015281.57 N 541962.65 E 3742.75 271.15 N 9995.80W 6015283.73 N 541929.50 E Dogleg Rate (°ll00ff) 9.505 9.083 2.287 6.777 10.035 5.007 4.209 3.959 2.201 3.101 5.556 7.353 2.599 10.684 10.353 7.535 2.481 2.254 10.717 9.086 1.725 12.143 5.538 8.914 8.601 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 9237.46 9270.11 9299.72 9333.67 9363.22 9391.86 9423.88 9456.65 9488.90 9522.69 9555.54 9584.09 9618.41 9651.83 9679.54 9713.77 9746.72 9774.34 9809.40 9842.24 9871.25 9906.75 9937.83 9966.29 9999.48 Comment Continued... DrillQuest 1.05.05 17 October, 2000 - 12:03 - 5- Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Ref: API-500292297060 Surveyed: I October, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11737.38 92.587 273.718 3678.98 3741.28 273.83 N 10030.73 W 11766.47 92.403 275.881 3677.72 3740.02 276.26 N 10059.68 W 11800.05 93.633 276.560 3675.95 3738.25 279.89 N 10093.02 W 11832.35 93,880 274.129 3673.83 3738.13 282.90 N 10125,11 W 11861.91 93.816 274.784 3671.85 3734.15 285.19 N 10154.51 W 11895.97 94.502 276,413 3669.38 3731.68 288.50 N 10188.32 W 11927.21 94.808 277,283 3666.84 3729.14 292.21 N 10219.23 W 11959.02 94.746 272.863 3664.19 3726.49 295.02 N 10250.80 W 11991.62 92.649 275.737 3662.09 3724.39 297,46 N 10283.24 W 12021.97 - 92.278 271.909 3660.79 3723.09 299.48 N 10313.48 W 12049.08 91.973 276.533 3659.78 3722.08 301.47 N 10340.50 W 12127.00 91.973 276.533 3657.10 3719.40 310.33 N 10417.86 W 6015286.16 N 541894.55 E 6015288.39 N 541865.58 E 6015291.79 N 541832.22 E 6015294.57N 541800.11E 6015296.66 N 541770.69 E 6015299.74N 541736.86 E 6015303.23 N 541705.92E 6015305.82 N 541674.34 E 6015308.03 N 541641.89 E 6015309.84 N 541611.62E 6015311.65 N 541584.60 E 6015319.97 N 541507.17 E 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 12127.00ft., The Bottom Hole Displacement is 10422.48ft., in the Direction of 271.706° (True). Dogleg Rate (°/lOOft) 3.978 7.455 4.183 7.549 2.221 5.178 2.943 13.848 10.898 12.660 17.082 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 10034.46 1O063.48 10096.90 10129.05 10158.51 10192.39 10223.40 10255.03 10287.52 10317.81 10344.86 10422.44 Pr~ected Suwey Continued... 17 October, 2000- 12:03 -6- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-223 L 1 MWD Your Reft API-500292297060 Surveyed: 1 October, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Comments Measured Depth (ft) 8485.58 8570.00 12127.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 3742.46 218.54 N 6791.45 W Tie-on Point 3767.13 221.50 N 6872.13 W Window Point 3719.40 310.33 N 10417.86 W Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) o.oo o.oo To Measured Vertical Depth Depth (ft) (ft) 12127.00 3719.40 Survey Tool Description MWD Magnetic 17 October, 2000.12:03 -7- DrillQuest 1.05.05 ALASIIA OIL AND GAS CONSERVATION CO~ISSION Steve Shultz Senior Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 / / / ! / / TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-143,3 FAX: (907) 276-7542 Re: Milne Point Unit J-23L 1 BP Exploration (Alaska) Inc. Permit No: 200-121. Sur.Loc: 2685'NSL, 3390'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 2959'NSL, 3294'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. The permit is for a new wellbore segment of existing well Milne Point Unit J-23, Permit No. 200-120, AP1 50-029-22970-00. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment'(BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) 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. aniel T. Seamount, Jr. Commissioner BY ORDER OF THE_ C~QMMISSION · DATED this 2 ~ day of August, 2000 ' dlf/Enclosures cc: Department of Fish & Gtune, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. ALASK(' 'IL AND GAS CONSERVATION COM(i 3SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory I'1 Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 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 ~.~ Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 · '4. Location of well at surface 7. Unit or Property Name 11. 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 2931' NSL, 5055' WEL, SEC. 29, T13N, R10E, UM MPJ-23L1 Number 2S100302630-277 At total depth 9. Approximate spud date 2959' NSL, 3294' 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, 1949' MDI MPN-01,300' away at 10287' MD 2560 12156' MD / 3730' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8635' MD Maximum Hole Angle 94 ° Maximum surface 1265 psig, At total depth (TVD) 3800'/1700 psig 18. Casing Program Specifications Setting Depth Size T¢ ~p BQ1 ;om Quantitv of Cement Hole Casin(] Wei(~ht Grade CouDlin(] Lan(]th MD TVD MD TVD (include sta(~e 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 ~.,=r.-...~ ~,..,=~.~ .~, ..... ~ %. ~ Liner ORIGINAL o Perforation depth: measured ,~a~.:~ .?,.: ,~,~ ,.,,.~ ...... ,,,,,, ........ ~,,~ ..... ~... , 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 564-5427 Johnson.n., Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoir~lt/.. '1~ truer_. ~dl ~orr( ct to the best of my knowledge , / Signed Steve Shultz ~'"~.~.i~ .~'""~ [~ Title Senior Drilling Engineer ,Dat,e,, ~'/Z/ ~ I API~~ ~o~ ro~.~lDl~ See cover letter Permit N -"/' ~ / 50- '- ~-~-~'~--3 - ,~ i~ for other requirements Conditions of Approval: Samples Required [] Yes ~No Mud Log h~quirect' [] Yes ~ No Hydrogen Sulfide Measures [] Yes ~'No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE '1~2K; [] 3K; r"l 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 Taylor Seamount Su Triplicate I Well Name: IMP J-23 & MPJ-23L1 Well Plan Summary Type of Well (producer or injector): Producer (Multilateral) Surface Location: MPJ-23 OB Target Start: MPJ-23 OB Target End: MPJ-23 L1 OA 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~ Number: I~?xxx I I"'=: I Doyon ~4~ I Estimated Start Date: I Aug. 20, 2000 I I Operating days to complete: I~S MPJ-23 MD 12,160' MPJ-23L1 MD 12156' MPJ-23 TVD: 3800' MPJ-23L1 TVD: 3730' IKBE: 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 fiowpath 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. 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' 1 each 1 each 100 each 50 each 1 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 . m . 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) 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 circulation problems while running and cementing casing. b) 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 circulation but contingency plans should be developed should lost circulation occur. Maintain minimum ECD thru use of proper hole cleaning procedures and PWD monitoring. c) 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 thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. d) 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 1 = [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 offtake 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) The J-23 directional plan has a 6500' interval of high angle(74 degrees) 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. b) Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! c) 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 f(~' e multilateral to be drilled. Sticking the c~,"' g 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. 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 monitored.to 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, 3,800' TVD (estimated) Max Exp Surface Pressure 1,265 psi (.115 psi/ft [las 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 6-118" Production Hole Mud Properties: OB/OA I KCL - CaCO3 Baradril N Mud I Density (ppg) I Funnel visI YP I "T'" I ,' I APl Filtrate I LG Solids 9.1 I 40 - 55 20 - 27 <10 8.0 - 8.5 4 - 6 < 15 p@b 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. Formation Markers Formation Tops MD 'rVDss Pore Psi EMW (ppg) Comments Base Permafrost 2096 1865 Top Ugnu 6294 3138 1383 8.65 Top Ugnu M 7128 3368 1486 8.65 N^ 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 Csg! Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDJTVD 30" 20" 94# H-40 Weld 80' 30'/30' 110'/110' 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' 12,16073,797' 6-1/8" OA 4-1/2"* 12.6# L-80 IBT-Mod 3,500' 8,650'/3,784' 12,150'/3,730' 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 1 7" 26 Ib/ff L-80 BTC-M 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 O^ sand. , Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required spaceout. ~ ~ ~, ~ .. ~ , .... .~ 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 / GPJRes / PWD - (Resistivity over production interval only) None MWD / GPJRes / PWD / 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 3~,, 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. ~_. ,{..'J . ~aska Oii '~ ~' ..... ~'" ......... Anchorage 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 7. 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. X10. Make 7" casing scraper to trip to 7" casing TD prior to setting Baker ML packer. 11. 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 CA interval. Set packer 12. Run in hole with MWD to determine orientation of ML packer 13. Make up Baker Window Master milling assembly with retrievable whipstock and MWD. Install whipstock in ML packer. Verify whipstock orientaion with MWD. Shear off and mill window.' 14. 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 35000' CA horizontal lateral. 15. Wiper trip at TD. Displace CA 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. Cimulate 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 constant 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 Versi6n 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 there is any question about the interpretation of the FIT results, inform the drilling superintendent before drilling ahead A~as~.a O;i,~ & ~s:as (k~n~. WELLHEAD: FMC Horizontal 11,,, 5M ,bg. head P' P S ~ KB. ELEV:66.00' 1 l"x 3-1/2". EUE (btm) ~ Cellar Box ELEV -- 35.50' FMC tbg. hanger. 'H' BPV profile n~ 3-1/2", 9.3 Ib/ft, L-80, EUE-M Coupling OD: 4.5" , · , ~ Drift/ID 2.867"/2.992" ,~ f ~ Baker TEC Wire ~ ~ Selective X Nipple 2.813" ID Jet Pump Installed in Sliding Sleeve III Baker CMU Sliding Sleeve with 2.813 ID Selective X Profile mm=. Baker Sentry Pressure Gauge (Internal Pressure) I, ~ l~I~ ' =' '~ Baker S3 Packer . , . 7", 26#, L-80, BTC-M I'~ .'/ No Go XN Nipple 2.75" ID Casing Drift: 6.151" := Casing ID: 6.276" Wireline Entry Guide Multi-Lateral Junction 6-1/8" CA Lateral TD 6-1/8" OB Lateral TD '12~163' Iwind°w in 7'' casing @ 8'635' I Well Inclination @ Window = 74 Degrees -. ~ ~ -_ _ _ Flow Thru Hollow Guide Stock ... ' Multi-Lateral Packer --, .._ 6-1/8" Hole Left as Open Hole Completion 4-1/2" Slotted Liner as Conti,n.genc~,(P[op,~D,r.c~) 0 " ...... " ~... ~::,:..~...'.i 7" Casing Shoe @ 8,950' · Well Inclination @ Shoe = 88 Degrees ~ ~,,,~ Reference Directional Plan WP4 ~~....-. OB Horizontal 6-1/8" Hole Left as Open Hole Completion PBTD I I 4-1/2" Slotted Liner & Hanger as Contingency ~"' I I DATE REV. BY COMMENTS Milna Paint Llnit i WELL'. J=~3 ML 7116/00 FJ Level 2 Multi-Lateral, 3-1/2" Jet Pump Completion BP Exploration (Alaska) North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-23 I DrillQuest .... Scale: linch = 600it -10200 -9600 ~ I I O o 600 o ~ -M~J-23-Wp~. L] Z "~ ~l~-~r")'4. 3230.20 0 281.38 ~ I~ W I -10200 -9600 Scale: linch = 600it Eastings -9000 -8400 -7800 -7200 ~:.2~ t./ r i. 3780.20 rvD 600 ~o End Dir: 10645.14ft MD, 3774.89fl TVD 257.:3 N, 704L3~oW II ~ I i Begin Dir O 4.000"ll00ft: 10619.24ft MD, 3775.42ft TVDMpj.23 Li 7'2. 377.7~,11:I,3~-"~'~'~ .~.'~C' '~ I I 233.3~ ~, 7W~r~w" '~ '7l/IPJ.23 LI T3.3775.20 TV~ - End Dir: 8885.~.8f, t~, 3795.35fl TVD -~'- - 1 ~\-- /\ ~ .~ 27877N, SJM128WDecmaseinDiERate.~ 4~0q0-- °~Ji~I~.-_'[I~'~..~I[lYlg,,3Z.96.tglI.'[Y.~-: \\ /\ ' ; ' I:~B I~lr I~. ~,l~'l'l~d'~ ' I~I~Z~I.~ZR MO, ;~[~lf.D;glI I VU .\ 1% ~ '~-~ End Dir: 8783.821t'MD. 3800.41 ft TVD /O I~rea~ ~bOiJ~Rale · 14.000'liO01t: 8665.00fl M[~, 379i.$01l TVD \ ~ I I I I -9000 -8400 -7800 -7200 Eastings Reference is True North 7OOO I I I 7500 8000 8500 /t~6~,.,~ 19,~4 I 1~3 ~ MPJ-2$ LI 23.3775.20 tvd 270.77 ~ 894I~8 W I I 9000 9500 2m~217 281.38 Al, 10464.24 W temp (lower) I 10000 10500 Scale: linch = 500it Vertical Section Section Azimuth: 271.540° (True North) North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 8635.00 73.982 271.533 3718.88 8665.00 77.369 272.794 3726.30 8700.00 82.268 272.691 3732.49 8783.82 94.000 272.450 3735.21 8800.00 94.000 272.450 3734.08 8823.82 94.000 272.450 3732.42 8852.45 92.000 270.399 3730.92 8885.98 90.659 270.415 3730.15 8900.00 90.659 270.415 3729.99 9000.00 90.659 270.415 3728.84 9100.00 90.659 270.415 3727.69 9200.00 90.659 270.415 3726.54 9300.00 90.659 270.415 3725.39 9400.00 90.659 270.415 3724.24 9500.00 90.659 270.415 3723.09 9600.00 90.659 270.415 3721.94 9700.00 90.659 270.415 3720.79 9800.00 90.659 270.415 3719.64 9900.00 90.659 270.415 3718.49 10000.00 90.659 270.415 3717.34 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 L 1 Revised: 14 July, 2000 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (°/100ft) 3784.08 248.98 N 6945.69 W 6015283.12 N 544979.69 E 3791.50 250.08 N 6974.73W 6015284.01 N 544950.64 E 12.000 3797.69 251.72 N 7009.13 W 6015285.42 N 544916.23 E 14.000 3800.41 255.47 N 7092.68 W 6015288.59 N 544832.66 E 14.000 3799.28 256.16 N 7108.80 W 6015289.17 N 544816.53 E 0.000 3797.62 257.18 N 7132.54 W 6015290.02 N 544792.78 E 0.000 3796.12 257.89 N 7161.12 W 6015290.53 N 544764.20 E 10.000 3795.35 258.13 N 7194.64W 6015290.53 N 544730.68 E 4.000 3795.19 258.23 N 7208.66W 6015290.53 N 544716.66 E 0.000 3794.04 258.95 N 7308.65W 6015290.56 N 544616.67E 0.000 3792.89 259.68 N 7408.64W 6015290.59 N 544516.68 E 0.000 3791.74 260.40N 7508.63W 6015290.62 N 544416.68 E 0.000 3790.59 261.12 N 7608.62W 6015290.64 N 544316.69 E 0.000 3789.44 261.85N 7708.61W 6015290.67 N 544216.70E 0.000 3788.29 262.57N 7808.60W .;~. 60152.90.70 N 544116.70E 0.000 3787.14 263.30N 7908.59W 6015290.72 N 544016.71E 0.000 3785.99 264.02N 8008.58W 6015290.75 N 543916.71E 0.000 3784.84 264.74N 8108.58W 6015290.78 N 543816.72E 0.000 3783.69 265.47N 8208.57W 6015290.80 N 543716.73E 0.000 3782.54 266.19 N 8308.56W 6015290.83 N 543616.73E 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6949.87 6978.93 7013.36 7096.98 7113.12 7136.88 7165.46 7198.98 7213.00 7312.97 7412.94 7512.92 7612.89 7712.87 7812.84 7912.81 8012.79 8112.76 8212.74 8312.71 Comment ST Exit @ 12.000°/100ft. 20.000° TF: 8635.00ft MD, 3784.08ft TVD Increase in Dir Rate @ 14.0000/100ft: 8665.00ft MD, 3791.50ft TVD End Dir: 8783.82ft MD, 3800.41ft TVD Be~_ in Dir @ 10.000°/100ft: 8823.82ft MD, 3797.62ft TVD Decrease in Dir Rate @ 4.000°/100ft: 8852.45ft MD, 3796.12ft TVD End Dir: 8885.98ft MD, 3795.35ft TVD Continued... 14 July, 2000- 12:10 - 1 - DrillQuest 1.05.05 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 10100.00 90.659 270.415 3716.19 10200.00 90.659 270.415 3715.04 10300.00 90.659 270.415 3713.89 10400.00 90.659 270.415 3712.74 10500.00 90.659 270.415 3711.59 10600.00 90.659 270.415 3710.44 10619.24 90.659 270.415 3710.22 10632.78 91.200 270.405 3710.00 10645.14 91.694 270.399 3709.69 10700.00 91.694 270.399 3708.07 10800.00 91.694 270.399 3705.11 10900.00 91.694 270.399 3702.15 11000.00 91.694 270.399 3699.19 11100.00 91.694 270.399 3696.24 11200.00 91.694 270.399 3693.28 11300.00 91.694 270.399 3690.32 11400.00 91.694 270.399 3687.37 11500.00 91.694 270.399 3684.41 11600.00 91.694 270.399 3681.45 11700.00 91.694 270.399 3678.50 11800.00 91.694 270.399 3675.54 11900.00 91.694 270.399 3672.58 12000.00 91.694 270.399 3669.63 12100.00 91.694 270.399 3666.67 12156.44 91.694 270.399 3665.00 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 L 1 Revised: 14 July, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 3781.39 266.91 N 8408.55 W 6015290.86 N 543516.74 E 3780.24 267.64 N 8508.54 W 6015290.88 N 543416.75 E 3779.09 268.36 N 8608.53 W 6015290.91 N 543316.75 E 3777.94 269.08 N 8708.52 W 6015290.94 N 543216.76 E 3776.79 269.81 N 8808.51 W 6015290.97 N 543116.77 E 3775.64 270.53 N 8908.50 W 6015290.99 N 543016.77 E 3775.42 270.67 N 8927.74 W 6015291.00 N 542997.53 E 3775.20 270.77 N 8941.28 W 6015291.00 N 542984.00 E 3774.89 270.86 N 8953.63 W 6015291.00 N 542971.64 E 3773.27 271.24 N 9008.47 W 6015291.00 N 542916.81 E 3770.31 271.93 N 9108.42 W - 6015291.00 N 542816.85 E 3767.35 272.63 N 9208.38 W 6015291.00 N 542716.89 E 3764.39 273.33 N 9308.33 W 6015291.00 N 542616.94 E 3761.44 274.02 N 9408.28 W 6015291.00 N 542516.98 E 3758.48 274.72 N 9508.24 W 6015291.00 N 542417.02 E 3755.52 275.42 N 9608.19 W 6015291.00 N 542317.07 E 3752.57 276.11 N 9708.15 W 6015291.00 N 542217.11 E 3749.61 276.81 N 9808.10 W 6015291.00 N 542117.16 E 3746.65 277.51 N 9908.05 W 6015291.00 N 542017.20 E 3743.70 278.20 N 10008.01 W 6015291.00 N 541917.24 E 3740.74 278.90 N 10107.96 W 6015291.00 N 541817.29 E 3737.78 279.60 N 10207.91 W 6015291.00 N 541717.33 E 3734.83 280.29 N 10307.87 W 6015291.00 N 541617.37 E 3731.87 280.99 N 10407.82 W 6015291.00 N 541517.42 E 3730.20 281.38 N 10464.24 W 6015291.00 N 541461.00 E Dogleg Rate (°/lOOft) 0.000 0.000 0.000 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 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) 8412.68 8512.66 8612.63 8712.61 8812.58 8912.55 8931.79 8945.32 8957.68 9012.50 9112.44 9212.38 9312.31 9412.25 9512.19 9612.12 9712.06 9812.00 9911.93 10011.87 10111.80 10211.74 10311.68 10411.61 10468.02 Comment Be~in Dir @ 4.000°/100ft: 10619.24ft MD, 3775.42ft TVD Target - MPJ-23 L1 T3 End Dir: 10645.14ft MD, 3774.89ft TVD Total Depth: 12156.44ft MD, 3730.20ftTVD Target - MPJ-23 L1 T4 Continued... 14 July, 2000 - 12:10 - 2 - DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 L 1 Revised: 14 July, 2000 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 12156.44ft., The Bottom Hole Displacement is 10468.02ft. i in the Direction of 271.540° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (fi) 8635.00 3784.08 248.98 N 6945.69 W 8665.00 3791.50 250.08 N 6974.73 W 8783.82 3800.41 255.47 N 7092.68 W 8823.82 3797.62 257.18 N 7132.54 W 8852.45 3796.12 257.89 N 7161.12 W 8885.98 3795.35 258.13 N 7194.64 W 10619.24 3775.42 270.67 N 8927.74 W 10645.14 3774.89 270.86 N 8953.63 W 12156.44 3730.20 281.38 N 10464.24 W Comment ST Exit @ 12.000°/100ft, 20.000° TF: 8635.00ft MD, 3784.08ft TVD Increase in Dir Rate @ 14.000°/100ft: 8665.00ft MD, 3791.50ft TVD End Dir: 8783.82ft MD, 3800.41ft TVD Begin Dir @ 10.000°/100ft: 8823.82ft MD, 3797.62ft TVD Decrease in Dir Rate @ 4.000°/100ft: 8852.45ft MD, 3796.12ft TVD End Dir: 8885.98ft MD, 3795.35ft TVD Begin Dir @ 4.000°/100ft: 10619.24ft MD, 3775.42ft TVD End Dir: 10645.14ft MD, 3774.89ft TVD Total Depth: 12156.44ft MD, 3730.20ft TVD Continued... 14 July, 2000 - 12:10 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for MPJ-23 Wp4 L 1 Revised: 14 July, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Targets associated with this wellpath Target Name MPJ-23 L1 T1 MPJ-23 L1 T2 MPJ-23 L1 T3 MPJ-23 L1 T4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea LeveVGIobal Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3780.20 3715.0O 3787.2O 3722.00 3775.20 3710.00 3730.20 3665.00 257.53 N 7041.32W 6015291.00N 544884.00E 70° 27' 09.5127"N 149° 38' 01.5524"W 258.36 N 7161.32W 6015291.00N 544764.00E 70° 27' 09.5198" N 149° 38' 05.0773"W 270.77 N 8941.28W 6015291.00N 542984.00E 70° 27' 09.6229" N 149° 38' 57.3627"W 281.38 N 10464.24W 6015291.00N 541461.00E 70° 27' 09.7078" N 149° 39' 42.0992"W Target Target Shape Type Point Point Point Point 14 July, 2000 - 12:10 - 4 - DrillQuest 1.05.05 /~ilne Point 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>> i Name: MP-J223 State Briefing document.doc ~MP-J223 State Briefinq document.doc! Type: Microsoft Word Document (application/msword)l .IEncoding: base64 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 ft/sec range. The 13-15 fi/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 3-112" 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. / DATE CHECK NO. VENDOR AL ........ nLn,.~r,r~, z 'T DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET D6~900 gK062900(~ 100. O0 !00. O0 HANDLI~iO INST' PH I ERRI HUBBLE 14628 AITACHEO CHECK IS IN PAYMENT FOR ~ DESCRIBED ABOVE. ~ 100. OO 1 OO. OO ::'i!,'.':.?,~.'Q:;..';;~;,1"g~'i'2 !:.::ii:.:'"'::;!ili'.~i!!.." . ':..;i;;:i!:. :"i.!ii.:~:,.' A'N~RO~AG'~;i!A~:~!'::' 095'1. 9:6612 ~i:.i;.i!i;!:. :': '/ ~!;:.;. :':.:".:'.'.:~ii;if.:::::.?: ....:;~i;;~. ':: :?.ii!i;!:;?'." . ' ..,:,:"~." · :,:,:,.::...' ,.. . .., .... . .,..., , "'!:ii:,,." . "' .... : ": '" "' " ' ,'::.,.'i" .. ' ...AY',,', .,,..',' ~E;..i~U~RED~:~i!~!&..~i.1.~**.e~.~.*~...~~~.e..~..~.*~.**~.~*~~....~ ,'.'.:,":ii':: .,~i',:?,: ',;:,j.?,.~',,. ' ' ' . '::;.'~,',i?i?:,.,' . '~;j;~:.',,;;,~?:'.:'.'...,~..:',' ..'f;~.,:.:~:~AMOUNT,',"~"~'."' ." .'..'.:,' :',:,.': ..... · ' "" ....... . ".. ,' ,'. ,. '"' "] 06/~9./00..'".,'""'[,: ' .'[~'.~.~:'.:[:,'.:'~..,'.',, I :~::j::.~;;~::;~ .'.LA~'.':' STATE. ~'.'::...'.......... ... ...:.. N~,O'k~a',;'~s ' '. ........... .. ,.... .... .~. ~.~ .,~ . ..." '.':;:~E,.:..~:~..:'~E...:...'R'~E~'.~ .... :.':.'?:',:'.',:,"""":.,,.,:,,,:,.:.,. ,..,.:, .,.:,.,:,,,:,... .... '"':':?'?:""..., ,. :'"'"~'?~::..:,.~,o,.,o~."':":':':::~::":".' :'. ...... '" '"'""..:...'%""' ii' l, ? 0 q 5 B ii' ':0 t, l, EO ::iR q 51: ,, OO&NN · ___ . ' posal para re_q ADMINISTRATION DATE E_NGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate;;"~. ~'~.,.~ 3. Unique well name and'number ............. '.. ~ . . 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in 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 ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ......... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... · 22. Adequate wellbore separation proposed ............. N Y N") Y N,7 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet'regulation ................ 26. BOPE press rating appropriate; test to ~:~'3(~3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY I~)R DATE ANNULAR DISPOSAL35. With proper cementing records, this plan 30. Permit can be issued wlo. hydrogen sulfide measures ..... (~ N~' ,~ / / 31. Data presented on potential overpressure zones '~--~'~'C)~--~4~. ~-/4.~-./" .~_.~-~,~ .~--¥., -.-~'A~ 32. Seismic analysis of shallow gas zones ...... ~ ~ ~ ~..... 33. Seabed condition surve (if off. shore · y . . ) ............. Y .. . 34. Contact name/phone for weekly progress reports [exj~lo'~tory only]. Y N. (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... to surface; (c) will not impair mechanical integrity of the well used for disposal; .. (D) will not damage producing formation or impair recover, from a pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N ENGINEERING: c:~soffice\wordian~diana\checklist (rev. 02117100) Well Histocy 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 APPEN. DIX~ ., No'special'effort has been made to chronologically. organize this category of information. mpj-23-Ll.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jul 31 13:00:17 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/31 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 ..................... 01/07/31 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: F.SL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MPJ-23 L1 500292297060 BP Exploration, Alaska Inc. Sperry Sun 17-MAY-01 MWD RUN 1 MWD RUN 3 MWD RUN 7 AK-MM-00178 AK-MM-00178 AK-MM-00178 R. FRENCH R. FRENCH J. FOLEY E. VAUGHN E. VAUGHN E. VAUGHN 13N 10E 2685 3390 .00 Page 1 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD mpj-23-Ll.tapx 62.30 35.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 6.125 7.000 8592.0 lST 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 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 RUN 3 IS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. MWD RUN 6 IS DIRECTIONAL TO SET THE WHIPSTOCK, WITH TOP AT 8569' MD, 3765' TVD AND BOTTOM AT 8582' MD, 3767' TVD AND DRILLED OUT TO 8594' MD, 3772' TVD. 7. MWD RUN 7 IS DIRECTIONAL WITH DGR AND EWR-4. 8. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 4/9/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. 9. MWD RUNS 1, 3, AND 7 REPRESENT THE MWD DATA FOR WELL MPJ-23 L1 WITH Ami% 50-029-22970-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12127' MD, 3723' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 mpj-23-Ll.tapx SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/31 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 STOP DEPTH 43.5 12073.5 110.5 12126.5 3695.0 12080.5 3695.0 12080.5 3695.0 12080.5 3695.0 12080.5 3695.0 12080.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH 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 Page 3 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 43.5 3727.0 3 3678.0 8593.5 7 8594.0 12126..5 mpj-23-Ll.tapx DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 0 4 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 43.5 12126.5 ROP MWD FT/H 0 4786.71 GR MWD API 13.7 127.51 RPX MWD OHMM 3.65 2000 RPS MWD OHMM 2.19 2000 RPM MWD OHMM 0.57 2000 RPD MWD OHMM 0.28 2000 FET MWD HOUR 0.0589 27.8392 Mean Nsam 6085 24167 223.358 24033 71.8843 24061 18.135 16772 21.8517 16772 22.5117 16772 23.8989 16772 0.638816 16772 First Reading 43.5 110.5 43.5 3695 3695 3695 3695 3695 Last Reading 12126 5 12126 5 12073 5 12080 5 12080 5 12080 5 12080 5 12080 5 First Reading For Entire File .......... 43.5 Last Reading For Entire File ........... 12126.5. File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/31 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 ....... 01/07/31 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 Page 4 GR 43.5 ROP 110.5 $ 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): mpj-23-Ll.tapx 3677.5 3727.0 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 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-Ll.tapx Absent value ....................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T 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 ....... 01/07/31 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 ....... 01/07/31 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 8593.5 FET 3695.0 8593.5 RPM 3695.0 8593.5 RPM 3695.0 8593.5 RPX 3695.0 8593.5 Page 6 RPS 3695.0 ROP 3727.5 $ 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): mpj-23-L1, tapx 8593.5 8593.5 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 Page 7 14-SEP-00 Insite 65.41 Memory 8594.0 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-Ll.tapx 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 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 8593.5 ROP MWD030 FT/H 0 2328.68 GR MWD030 API 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 6135.75 9832 274.745 9733 69.4759 9832 12.9543 9798 13.5974 9798 14.886 9798 18.2598 9798 0.527355 9798 First Reading 3678 3727.5 3678 3695 3695 3695 3695 3695 Last Reading 8593 5 8593 5 8593 5 8593 5 8593 5 8593 5 8593 5 8593 5 First Reading For Entire File .......... 3678 Last Reading For Entire File ........... 8593.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/31 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 ....... 01/07/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 8 ilI mpj-23-Ll.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8594.0 12080.5 R?M 8594.0 12080.5 RPS 8594.0 12080.5 RPX 8594.0 12080.5 GR 8594.0 12073.5 ROP 8594.0 12126.5 FET 8594.0 12080.5 $ 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): Page 9 30-SEP-00 Insite 65.44 Memory 12127.0 72.8 94.8 TOOL NUMBER PB01647HAGR4 PB01647HAGR4 6.125 Water Based 9.20 56.0 10.2 26000 3.7 .160 1.673 .210 .310 64.0 88.0 64.0 64.0 mpj-23-Ll.tapx # 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 MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 8594 12126.5 ROP MWD070 FT/H 0 1073.84 GR MWD070 API 52.65 120.6 RPX MWD070 OHMM 6.82 2000 RPS MWD070 OHMM 8.14 2000 RPM MWD070 OHMM 6.39 2000 RPD MWD070 OHMM 7.39 1081.96 FET MWD070 HOUR 0.2636 3.6422 Mean Nsam 10360.3 7066 154.031 7066 85.0384 6960 25.4135 6974 33.4484 6974 33.2252 6974 31.8214 6974 0.79541 6974 First Reading 8594 8594 8594 8594. 8594 8594 8594 8594 Last Reading 12126 5 12126 5 12073 5 12080 5 12080 5 12080 5 12080 5 12080 5 First Reading For Entire File .......... 8594 Last Reading For Entire File ........... 12126.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Page 10 mpj-23-Ll.tapx Date ..................... 01/07/31 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 ..................... 01/07/31 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 11