Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-149
STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 2 2017 WELL COMPLETION OR RECOMPLETION REPORT AN149Scc 1a.Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAc 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC CA6and.: 12/19/2016 . 200-149/316-461 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 October 9,2000 50-029-22976-00-00 ' 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 2713'FSL,3402'FEL,Sec 28,T13N,R10E,UM,AK October 21,2000 MPU J-24 ' Top of Productive Interval: 9.Ref Elevations: KB: 62.8 17.Field/Pool(s):Milne Point Unit N/A GL:36.3'BF:36.3' Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MDITVD: 18.Property Designation: 4`6 5172'FSL,2663'FEL,Sec 30,T13N, R10E,UM,AK 7,560'MD/3,628'TVD 01SS'/7. ADL 025515 2.3-yb(o 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 551914 y- 6015110 Zone- 4 11,975'MD/3,858'TVD N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 542071 y- 6017508 Zone- N/A -2,000'MD/-1,800'TVD 5.Directional or Inclination Survey: Yes ❑(attached) No 0 13.Water Depth,if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 agcl,afkAC 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 incTtia ,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED Ar T :, . 211 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20" 92# H-40 Surface 108' Surface 108' 30" 260 sx 7" 26# L-80 Surface 8,664' Surface 3,918' 9-7/8" 1025 sx 4-1/2" 12.6# L-80 8,554' 11,975' 3,912' 3,858' 6-1/8' Uncemented Slotted Liner 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MDITVD) Size and Number): N/A . 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. I-, Was hydraulic fracturing used during completion? Yes❑ No 0 12 'I' I t tQ Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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 .m.� Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate =.► Form 10-4 7 Revis d 1 /2015 CONTINUED ON PAGE 2 RBDMS �, FEB ' J 2017 Submit ORIGINIAL ort 3/��1, -- ,"z 2, -f7 • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑., Sidewall Cores: Yes ❑ No ❑I 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 ND Well tested? Yes LI 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: Wellbore Schematic, Decomplete Reports 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: Cody Dinger Email: cdinger@hilcorp.com Printed Name: Cod Din•er Title: Drilling Tech Signature: i Phone: 777-8389 Date: Z�Ze 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 lb: 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 ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Milne Point Unit Well: MPU J-24/L1 Schematic Abandoned: 12/19/2016 Hilcorp Alaska,LLC PTD: 200-149/200-150 Orig.KB Elev=66.5'GL Elev.36.3' CASING DETAIL RKB—Tbg Hngr:21.3'(Nabors 3S) Size Type Wt/Grade/Conn Drift ID Top Btm tto ? t 20" Conductor 92/H-40/Welded N/A Surf 108' WA 7" Surface 26/L-80/BTC 6.151" Surf 8,664' j 4-1/2" Liner L3 12.6/L-80/IBT 3.833" 8,284' 11,987' r« 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' TUBING DETAIL 0 ES Cementer 2,397 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" 7,891 8,208' ll 0 'ai. JEWELRY DETAIL No Depth Item g 1 7,577' Cement Retainer(Squeeze 46 bbl(193 sx)of 15.8 ppg Cement below) ,t, 2 7,891' Cut 4-1/2"Tubing ` 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) 27 V 4 8,073' Baker S-3 Packer 9Cr k 641 5 8,136' HESX Nipple-3.813"ID 6 8,196' HES XN Nipple—3.725"ID it 7 8,207' WLEG 14 44 8 8,296' Baker ML Torque Master Packer ke 9 8,315' WLEG 10 8,563' Baker HMC Liner Hanger c'4 Window for J- 11 11,964' OA Lateral 4-1/2"Pack-off Bushing 4A@7'560' 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe i, 13 11,952' OB Lateral 4-1/2"Pack-off Bushing 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe OPEN HOLE/CEMENT DETAIL .- ;a 9, .� ,.• 2 `T"Z 20" 260 sx Arctic Set cmt to surface ' *»?- 7" 1600 sx Cement,2 stages,cmt to Surface :4, 1 1 1 3 ,2 ' 1 GENERAL WELL INFO ` API:50-029-22976-00/(60)-00 Drilled and Cased by Doyon 141-11/9/2000 * >.�:" it ,d j 4 ESP Installed by Nabors 4ES—11/21/2000 `.. ESP Replaced by Nabors 4ES—5/20/2005 1'4,1 '' ESP Replaced by Nabors 4ES—9/01/2005 t . ESP Replaced by Nabors 4ES—9/10/2006 Mn ID 3.725' I�Ir, • ,' Pi ESP Replaced by Nabors 3S-7/02/2007 l' „t, Convert to Jet Pump by Nabors 35—4/15/2008 ' Decomplete/Abandon by Innovation Rig— IRA Tag Tv t �'kr P tt 12/19/16 S FS tz si-21L1 NI t0 f 13 14 1,Z44 TD=11,975'(MD)/TD=3,858'(1VD) PBTD=11,975'(MD)/PBTD=3,858'(TVD) Downhole Proposed Updated By:CJ0 2/02/2017 • • Hilcorp Energy Company Composite Report Well Name: MP J-24A Field: Milne Point County/State: ,Alaska Location(LAT/LONG): Elevation(RKB): 26.04 API#: Spud Date: Job Name: 1511740D MP J-24A DRILLING Contractor AFE#: AFE$: Activity Date Ops Summary 12/9/2016 Cont T/prep derrick T/scope down.Unhook both derrick asst.cables f/top of cat walk,unhook geronimo line f/roof of pipe shed,p/u blocks stage bridle line's @ sheave and install sheave guide bolts.;Unplug top section derrick lights and crown saver.P/U t/80k visual check bridle lines,p/u t/130k,s/o U110k,massage derrick work f/120k-t/145k multiple times,p/u U150k and hold,cont.t/massage;Set over pull U140k and work,stage up over pull U142k and p/u @ faster rate.Wt will climb U147k,p/u off dogs,pull dog pins,visual inspect dogs out,scope derrick down s/o=130k,p/u=140k.;lnstall tong sheave extension,fill pipe shed jet heat day tanks w/fuel.Asst.White Star rep.w/replumbing internal bearing lube system on m.p.#2,refill m.p.#2 w/gear oil;Open suction caps#1 mud pump,hard to remove,Whitestar Rep.present,found that sealing surfaces were gaulled,investigating reason for gaulling. Inspect#2 same(good).;Blow down water throughout rig. Offload cutting box to vac and send for disposal. Offload 160 bbls water from pits for disposal. Lay herculite and mats on well J-24. Install BPV.;Scope derrick,138k to 155k up. R/U tongs and adjust lines. Inspect sheave clearance during scoping operations(ok). Attempt to pull pins but linkage failed to pull pins.;;Manually pull pins. Scope derrick down. Install shipping pins in derrick and tq tube. Take on 2K gal fuel. Install 80 psi regulator for blowing down steam system. Blowdown and drain water heater.;Freeze protect washer machines,blowdown water heaters. R/D welding hooch. Remove peripheral equipment from around rig and prep for rig move. Coil and stage wt bucket w/Geronimo lines on sub.;Shut in steam. Remove steam traps from system and blowdown same. Lay herculite and mats on J-24. Install BPV and remove upper tree. Double stack master valves and blind off. Secure well. 12/10/2016 Continue rigging down service lines and prepping rig for demob. Lift and secure landings and stairs.;PJSM for rig move. Demob rig and stage on location. Pick up and demob mats. Clean up containment and discard. Demob equipment from around entrance of pad. Remove blinds from master valve.;Move rig F/D pad T/J pad(7.9 miles). est 4 MPH avg. No issues during rig move. Road and route prep was done prior to move. Work included removing guardrails and signs. Scarifier corners.;Remove rear tires on sub. Remove traveling hitch from sub. Walk sub 90°and prep to walk back over J-24 well. Spot both Geo Skids on rig. Spot mats for other modules.;Slowly walk rig back over well J-24 and ctr. Lower stairs and install landing inside sub.;Spot catwalk. Set pit module and adjust alignment w/catwalk. Continue installing landings and setting stairways as modules get spotted.;Notify AOGCC of upcoming rig inspection and BOP test. 12/11/2016 Spot power module,remove jeep.Plug in power from sub to pits.Set up floor plates and roof hatches.;Mobilize company man/Toolpusher camp to J-pad and spot.Lay liner and matting boards for cuttings tank.Spot cuttings tank utilizing roads and pads front end loader.Plug in power from pits to power;Begin do fluid end on#1 mud pump.Take on fuel to rig.Con't insulating rig.Take on 587 bbls of sea water to pits 3,4 and 5.Berm cuttings tank.Stage sub base tires by jeeps. Assist canrig tech;Install chain on tong arm extensions for secondary retention,load outriggers,cont,install pump mod.In m.p.#1 dress pump w/5"liners and swabs,m.p.#2 pull all swabs inspect liners.;Change out swabs in pod 2,3&4. Perform pre scope derrick inspection. Install drag chain belt.Pump through all centrifugal pumps,ready centrifuge's,r/u steam Ucutting box.,Charge water header t/pits. R/U steam Upit#5 and t/140 degree's. Install cmt line chixson. Spot drilling connex and warmup shack.;Attempt to scope derrick. 140k initial up wt. Pulled heavy towards the last 2'prior to pin(160k). Cycle derrick several times with little to no change in final up wt.:Add light oil to reduce friction.Continue scope and pin w/final up wt 158k. Plug in lights and crown saver. Continue insulating around rig and rigging up peripheral equipment on location. 12/12/2016 Continue Canrig install.Troubleshoot and fix intercom system.Continue labeling and bonding electrical.Ran mud pumps,completed interlocks/shutdown checklist.;Monitor mud pump inverters cooling/air flow(ok).Continue heating seawater in pits maintaining 140°F. Stage welding equipment on floor. Repair derrick pin latch.;Fix leak on drawworks HPU. Re-wire plug on catwalk. Dress shakers w/140's(API).;Stage mud product in hopper room. Finish commission pumps(ok). Swap to hi-line©14:30 hrs. R/U"T"bar and pull BPV. R/U to kill well taking returns back to flowback tank.;Scope derrick up to free scoping pins (152K up). Function derrick pin latch(ok). Secure derrick w/scoping pins and relax bridle line.;R/D bridle line and equipment.;Walk lines and verify valve alignment to flowback tank(ok). Line up and blow air through choke line and both manual chokes(ok). Wet lines with 8.5 ppg heated seawater.;P/T lines w/250 low and 2000 high(ok). Blowdown line and lineup to pump down 4-1/2"tbg and take returns from 7"x4-1/2"annulus to flowback tank. Verify chart recorder vs rig standpipe gauge(ok).;Bring pump#2 on @ 1 bpm/34 psi(1/2 open choke pos). Saw gas first 2 bbls then straight crude. Increase pump 2 bpm/102 psi(full open choke pos). Stage up to 5 bpm/425 psi w/partial returns.;Saw transition from oil to water @ 157 bbls pumped(est 90 bbls oil return). Continue circulating 140°F,8.5 ppg seawater dn tbg. Pump 454 bbls total w/265 bbls return(58%returns).;Shut down pump. Tbg and annulus on very slight vac. Blowdown lines. R/U hole fill on annulus(pump 20 bbls every hour dn annulus). N/D 1502 tree flange and install TWC as per plan.;N/D tree and set back on rig mats. Graphite pack hanger for BOP test. Dummy run hanger XO to TC-II(8 rds-Ok).;N/U BOP equipment. Install 11"x 13-5/8"5M DSA. N/U Class IV stack 5M stack. Dress upper and lower rams w/VBR's(2-7/8"x 5-1/2"). Blind rams in middle.;Hauled 0 bbls to B-50 for total=430 bbls 12/13/2016 Finish torqueing DSA,Choke&Kill flanges to spec.Cont filling annulus with 20 bbl per hr seawater.Build 40 bbl batches to maintain 300 bbl volume. P/U weatherford 9 5/8 casing tongs to test fit.,Bring 4.5 weatherford tongs and test on rig hydraulic system. Flushed 10 gallons through tongs before taking returns to rig. Take RKB measurements.Pressure up accumulator.Bump test rams&annular;good. Fix Hyd leak on HCR Kill. Change plumbing on annular to clear mouse hole. Finish N/U BOPs. TWC leaking in to BOPs. Close blinds and pressure up to 500 to seat popit.;ACE assist Canrig,Mud Module,drive lineup and added covers for the open busway,tested the air flow in the MP cabinets,Run MPs and monitor temps,test and fine tune catheads,C/O PLC program.;Note: 24hr notification for initial BOP test sent to AOGCC @ 14:03 PM on 12/13/2016;Leave blinds closed to fix leak on pitcher nipple. Open blinds and monitor well. Static.Annulus on vac. Canrig continues to R/U,Calibrate/test PVT system and gas alarms.,P/U mouse hole f/cat walk and install,test rotating mouse hole functions,M/U test equipment w/4 1/2"test jt. Note:monitor I/A,continues on vac;Top drive functions not working,trouble shoot top drive,fault shown on main power panel, drill console alarm showed low oil press,coolant fault and VFD fault,ACE rep came to help trouble shoot.;Found coolant pump locked out,Top drive is operational.;Decision made Ushut down and not operate top drive,notify NOV in the morning.;Install test joint,flood stack and lines w/water,PJSM,review BOP testing procedure Note:monitor I/A,continues on vac,fill @ 10-15 bph;Pre test BOPE,choke manifold valves to 250 psi low,5000 psi high 5 min ea.Chart all tests.Attempt accumulator drawdown,manifold pressure bleeding off 200 psi after pumps shut down.;Perform electric and manual choke bleed test.;Daily losses to well,459 bbls 8.5 ppg seawater for total=459 bbls. Hauled 0 bbls to B-50 for total=430 bbls • • 12/14/2016 Test bops annular with 4.5 test joint. Trouble shoot annular leak @ 2500-4000 psi. Brought up annular pressure from 850 to 1500 psi as per Manufacture recommendation. C Retested 250 5000 psi good.;Tested Both manual and Hyd TD valves to 250/5000 psi. Performed accumulator test. D td 5 V 3050 psi Starting pressure v 1725 psi Pressure after shut in 200 psi increase in 19 sec. 71 sec to full recovery.;Functioned top rams twice to simulate closing blinds.;Work on installing safety cables on interconnects. Continue filling annulus with 10 bph seawater. Reprogram accumulator controls for Remote operation on the annular pressure adjustment.Good.;Canrig finished installing and calibrating rig floor PVT screen and pit sensors. Calibrate flow meter,Gain loss&alarms.Good.;ACE: wire and test gen kill,Test utility going online f/blackout scenario, adjust accumulator PLC-add master supply valve to annular increase/decrease,Modify data logger software.;Lable ram size upper and lower on BOP control in dog house and on accumulator. Label accumulator bottles and nitrogen bottles.;Training w/Total Safety on rig alarm's and sensors.R/U and test flow sensor on flow line, calibrate same.Continue installing hose hangers around rig.;Continue w/rig acceptance check list,R/U hard line f/cellar trash pump t/flow line,continue w/general house keeping and ready rig for AOGCC inspection.;Continue to R/U hard line plumbing f/cellar pump Uflowline,stage WFD 4.5"elevator's on rig floor and inspect,paint plumbing on test pump.;Place lower section of block hang line behind derrick gurt,blow air through MP#1 pop off line.Stage liner and dunnage for pipe racks. Continue hole fill down I/A 10 bph w/8.5 ppg seawater.;Daily losses to well,144 bbls 8.5 ppg seawater for total=574 bbls. Hauled 0 bbls to B-50 for total=430 bbls Hauled 0 bbls to ORT for total=190 bbls. 12/15/2016 Conduct Pre spud safety meeting with both drilling crews at Milne point. Keep Toolpusher on rig to monitor. Note:accept rig on J-24A @ 06:00.;R/U to test BOPE. Fill stack and lines with fresh water. Perform rig inspection with Chuck Scheve with the AOGCC. Good.;Test BOPE to 250/5000 psi all valves and blow out equipment as per sundry. Test annular to 250/3500.All test pass.Perform accumulator drawdown. Monitor I/A,Continue 10 bph hole fill w/8.5 ppg SW.;3000 psi starting pressure, 1700 after starting,200 psi Increase in 9 sec.Full pressure attained in 62 sec. 2300 psi average on 6 bottles.;Close I/A valve.R/D test equipment,Blow down top drive,choke manifold and lines.;Finish hot work projects on rig floor.R/U hole fill and bleeder line.Pull TWC per wellhead rep,pump 20 bbls 8.5 ppg SW down annulus.Close blind ram. Note:tbg on vac.;Conduct training with both crews operating rig ESD blacking out rig and bringing back online.;PJSM with crew,WFD and wellhead rep.M/U landing jt and XOs.BOLDS,unseat hanger @ 92k,P/U 3 times staging up wt to 115k parting tbg @ 7900'(@ jet cut depth) continue 10 bph hole fill w/8.5 SW.;Pull hanger to rig floor.L/D hanger,blast rings,pup jt and landing jt.C/0 to 4 1/2"elevators,Ready FOSV.;P/U 85k,POH L/D 4 1/2"IBT 12.6#L-80 tbg f/7875'to 1300'(starting off slow as hands get familiar with operation and equipment)165 jts out Note:UD 2 pup jts and GLM @ jt#72.;Note:use double displacement hole fill on trip out.;Conduct valve drill @ 7660'(AAR:valve handle mixed with others on tool rack,use strap to stab FOSV so chain on hoist doesn't bind up when M/U,test run any XOs on FOSV);Daily losses to well,230 bbls 8.5 ppg seawater for total=744 bbls. Hauled 0 bbls to B-50 for total=430 bbls Hauled 0 bbls to ORT for total=190 bbls. 12/16/2016 POOH F/1300'T/Surface. L/D 199 joints total+31.16 cut joint. One GLM with Pups.;R/D Weatherford casing Equipment. Clean rig floor.;Flush oil out of stack.R/U Test equipment.M/U 4"Test joint&Test Plug. Set Test plug.,Test BOPE with 4"test joint.Lower Rams,Upper Rams,&Annular to 250/3000 psi. All tests good.;Found leak on TD.Inspect TD&Found leaking hydraulic filter tattle tell leaking at connection. L/0 TD&Repair bad 0 ring.;R/D test joint.Pull test plug.;PJSM,install 9"ID wear bushing,RI4LDS,clean and clear rig floor.PJSM for M/U BHA.;M/U Cleanout BHA#1,6 1/8"Mill tooth bit,BS,6.151 upper window mill,DPS,7"scraper,BS,Jar,XO,20 jts 4"HWDP=632.94' Note: 1 jt HWDP would not drift;Drift,P/U and single in the hole with 4"XT-38 DP f/633'to 6195' (177jts ran) Use 5 bph hole fill on trip in. Note:Conduct valve drill @ 695',1 min 40 sec to secure well.;Daily losses to well,139 bbls 8.5 ppg seawater for total=883 bbls. Hauled 0 bbls to B-50 for total=430 bbls Hauled 0 bbls to ORT for total=190 bbls. 12/17/201,, P/U DP F/6321'T/7891'. Tag top of tubing stump 2K.UP/DN 105/70k.;POOH F/7891'T/7644'.Circ 1.5 DP volumes to clear pipe. Work pipe across planned ( setting area @ 7585'.Reciprocate F/7600'T 7560'.;POOH with 4"DP F/7644'T/BHA 632'.Stand back HWDP out of the way. L/D Cleanout BHA. Clean and clear the rig floor. Fill hole with double pipe displacement while tripping.;PJSM,M/U running tool and XO,Dummy run same thru stack,M/U 7"EZ DRILL SVB . 41-1 cement retainer,retainer only=2.65',OA=14.16' C/ Note:use 10 bph hole fill;RIH with stands of 4" DP from derrick to 3156',fill pipe,Discoverd leak on TD gooseneck connection. Note:use 5 bph hole fill on trip in.;Tighten gooseneck connection,pressure test mudline to top drive to 500/3000 psi,good.Blow down top drive.;Continue to RIH SL` f/3156'to 6994'(111 stds DP)Single in with 19 jts DP to 7585',P/U 94K,SIO 69K. Fill pipe @ 6000'.;M/U top drive,Pump 20 bbls seawater 3 bpm,200 psi to clear any debris @ set depth,see returns @ 13 bbls away.Blow down top drive.;M/U pump in sub,FOSV closed with 5'pup loaded with DP wiper ball,M/U top drive,P/U 13'to set depth matching old RKB 6.28'difference.;Set retainer per Haliburton rep,apply 35 turns to right,stage up to 141k @ shear @ 50K Over pull, P/U 7'and unsting,apply 25 turns to right.;R/U lines to test 7"csg. With new RKB top retainer set @ 7576.1.;Daily losses to well,189 bbls 8.5 ppg seawater for total=1072 bbls. Hauled 0 bbls to B-50 for total=430 bbls Hauled 0 bbls to ORT for total=190 bbls.;Hauled 300 bbls from 6 mile lake for total=300 bbls. 12/18/2016 R/U to test casing.Break circ and fill well up. Close Top rams and pump down DP&Kill line. Test casing to 1500 psi..Monitor Lower annulus.Pressure came up to 1500 psi also.Hold for 10 Min Good;PJSM,Cmt job. Sting in to retainer @ 7576'DP Measurement, Corrected Depth with RKB Difference 7580'top of Retainer. Set down 15K. Pump 2 bbl with rig to verify injection.;Swap to cmt unit&batch mix cmt. Pump 20 bbl fresh water and 46 bbl(193 sx)15.8 ppg Class G cmt.Displace with Halliburton 20 bbl H2O&66 bbl seawater. 2 bbl over calculated displacement.;Final injection pressure @ 1360 @ 4 bpm.Unsting from t✓ retainer and see pressure drop. Swap to rig and clear lines pumping 20 bbl. Shut in cmt line and swap to TD.Pump down wiper ball. CIP @ 10:00.;Circ STS&never saw wiper ball or cmt to surface.Shut down and monitor well.Static.Blow down surface equipment.;L/D single,POOH U 6800' while looking in to lower annulus communication. Found old workover report that showed well head changed out.Both upper and lower valves are on the 7" casing.;Test 7"casing T/1500 psi for 30 min.Straight line.Good.Blow down all surface equipment.;POOH T/6400'.Found leak on TD.;Inspect TD&fixed leak on TD.Tighten hyd fittings behind diving board. Note:load pits w/580 bbls 8.9 ppg BARADRIL-N Drlg mud.;Continue POOH f/6400'to surface,inspect and L/D and load out running tool. Note:correct displacement on trip out.;Service top drive,crown and drawworks.;PJSM,M/U cleanout BHA 3-6 1/8"Window mill, 5 7/8"Lower string mill,flex jt, 6.151"upper WM mill,1 jt 3 1/2"HWDP,XO,20 jts 4"HWDP=656.97',RIH w/4"stds DP f/derrick to 7070'.;Note:correct displacement on trip in.;Daily losses to well,146 bbls 8.5 ppg seawater for total=1218 bbls. Hauled 0 bbls to B-50 for total=580 bbls Hauled 0 bbls to ORT for total=190 bbls.;Hauled 640 bbls from 6 mile lake for total=940 bbls 12/19/2016 RIH F/7070"T/7577'. Tag top of retainer.2K.;Circ&condition 3 bpm 275 psi while prepping for displacement.;Displace well from seawater to 8.9 ppg Baradrill N. Pump 23 bbl high vis sweep ahead.Circ @ 10 bpm 2400 psi. Reciprocate while circulating. Displacement came back early from calculated strokes.;Sweep came back 200 strokes early. Build and pump dry job. Monitor well.Good.;POOH F/7577'T/5371'.TD started leaking oil.Shut down and look for leak.;Trouble shoot leak and tighten fitting.;POOH F/5371'T/Surface standing back the HWDP.;PJSM,M/U Whipstock.Remove shipping bolt. Remove 3 of 6 shear pins. 3563#Each shear for the anchor. Set to shear @ 10695#. P/U Whip stock scribe whipstock to tool face @ 100 Deg offset.;RIH slow @ 90 fpm w/10 stds 4" HWDP,WS BHA=697.25',shallow hole test MWD tools,good. Note:very easy in and out of slips.;RIH slow @ 90 fpm with stds 4"DP from 697'to 7488'(Test MWD @ 6340'good) Note:very easy in and out of slips/fill DP every 3000' No issues on trip in,correct displacement.;M/U trop drive,fill pipe,225 gpm @ 1150 psi orient 51 deg Left TF,reciprocate string several times working out torque f/7488'to 7549'. Pump on P/U 104K,S/0 60K,pumps off P/U 117K,S/0 60K.;M/U stand 110 and top drive, work out torque,check tool face,holding 51 Left.S/0 tagging retainer @ 7577.18',set down 12k shearing anchor,P/U 10K over pull confirming anchor set.;Over pull 12k,set down 40k several times until shearing WS shear Bolt.P/U 20',reset bit depth 17.63'shorter. PU/SO/ROT 117/60/76,80 rpm 8K free TQ,230 gpm,1190 psi,SPR 1 &2 MP.;Ditch magnets in place, S/O to top of WS with light wt and low torque.Mill window per BOT rep f/7560'to 7571'.220 gpm,WOM 2-4K,80 rpm,8.2-10K TQ.MW in/out 8.9 ppg,vis 44.;Collect metal from milling operations.,Daily losses towel0 bbls mud for total=0 bbls Hauled to 0 bbls to B-50 forrtotal=580 bbls �/ Hauled 0 bbls to ORT for total=190 bbls.;Hauled 150 bbls from 6 mile lake for total=1090 bbls l/ `,of Tye, y \� I//j,�i. THE STATE Alaska Oil and Gas F -tom p f Conservation Commission -_- _-------,=-=. 1-�LAS�E�;A 'Witt_=`_ 333 West Seventh Avenue " !' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *+'' Main: 907.279.1433 °g$Q' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCANNED inY �g 1["' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-24 Permit to Drill Number: 200-149 Sundry Number: 316-461 Dear Mr. York: 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, alC16P)-1-17 """-N., Cathy P. Foerster Chair 6DATED this day of October, 2016. RBDN%S v,k- ba t 6 1016 • STATE OF ALASKA • E ALASKA OIL AND GAS CONSERVATION COMMISSION EP 0 9 201c APPLICATION FOR SUNDRY APPROVALS 197S I .� / 6 20 MC 25.280 AO 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate EI Repair Well ❑ t6 6s shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing [ J `� Change Approved Program❑ Plug for Redrill E, Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing El Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development . Q 200-149 3.Address: Stratigraphic ElService ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 50-029-22976-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A / MPU J-24 Will planned perforations require a spacing exception? Yes ❑ No El / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025515/025517/025906 • Milne Point Unit/Schrader Bluff ON Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): 'Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): . 11,975' • 3,858' . 11,975' • 3,858' 1,173 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 psi 520 psi Surface 8,664' 7" 8,664' 3,920' 7240 psi 5410 psi Intermediate Production Liner 3,421' 4-1/2" 11,975' 3,858' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,657'-11,954' 3,920'-3,859' 4-1/2"/12.6# L-80 8,208' Packers and SSSV Type: Baker S-3/Baker Torque Master Pkr Packers and SSSV MD(ft)and ND(ft): ' 8,073'MD/3,798'ND(S-3) 8,293'MD/3,862'ND(Torque Master) 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ElBOP Sketch ElExploratory ❑ Stratigraphic El Development D. Service El 14.Estimated Date for 15.Well Status after proposed work: 10/15/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended Cl. 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ El OP Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhda Email sporhojat hilcorp.com Printed Name k :;. I V(VL Title k. S \''\ p Signatu / PhoneTO- Date 1111 COMMISSION USE ONLY • Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\t.— 1-I(e t Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: -4 '3 C)DL) r:' ;: ii'1.L f i ,t 6i.')e ' +- a-- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ' Subsequent Form Required" /0-- L{07 RBDMS V OCT 1 0 2016 APPROVED BY Approved by:=7/, ,..6.44......._, COMMISSIONER THE COMMISSION Date: 7 —4 _/ AaLfor Subin Form ane Fom�O-403Cevi�ed;1/�015y / v 1 12 months from the date of approval. ��i Attachments� in Duplicate • • Well Prognosis Well: MPU J-24 Ililcorp Alaka,1.1) Date:9/6/2016 Well Name: MPU J-24 API Number: 50-029-22976-00 Current Status: SI Oil Well [Jet Pump] Pad: Milne Point J-Pad Estimated Start Date: October 15th, 2016 Rig: I - .- r Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: E Regulatory Contact: Tom Fouts Permit to Drill Number: 200-149 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,573 psi @ 4,000' TVD (Last BHP measured 7/17/2008) Maximum Expected BHP: 1,573 psi @ 4,000' TVD (No new perfs being added, EMW= 7.6 ppg) MPSP: 1,173 psi (Based on 0.10 psi/ft gas gradient) —j Brief Well Summary: MPU J-24/1-24L1 was drilled in 2000 using Doyon 141 and completed as a duaI-IdLC, .. ... _. Schrader Bluff OA and OB sands with an ESP using Nabors 4ES. The completion was pulled and the ESP completion changed out in 2005, 2005, 2006 using Nabors #4ES and 2007 using Nabors #3S. The completion was pulled and changed out in 2008 using Nabors#3S to replace the 2-7/8" tubing ESP completion with a 4-1/2" tubing Jet Pump completion. The well produced fill and large solids and has not produced since( he tubing was cut using coil tubing in August 2 16. I " yr' i 4024 Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 75.4° @ 5,273'). • Casing last tested to 3,000 psi for 30 min down to 8,073'on 8/04/2016. f • Jet Pump is pulled and the sliding sleeve closed. • Deviation at pump is 71.3°. • Deviation at upper window into the OA lateral is 74.1°. • Deviation at liner hanger into the OB lateral is 83.3°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 3.725"thru XN profile. • Last Fill Depth: 8,280'CTM tagged on 8/05/2016. Objective: The purpose of this work/sundry is to plugback the well in preparation for sidetracking the well. / Brief Procedure: Rig Procedure: 1. Pull BPV.Circulate well w/8.5 pig sea water and monitor well. Set TWC. 2. MIRU Innovation Rig(I-rig) and spot ancillary equipment. Fill source tank w/8.5 ppg sea water, 3. ND Tree. NU BOPE. -3t.c,o SW 105` 301' ' '- elG "-5-1-,7k- 4. Test BOPE to 250 psi Low/5,11=Frsi High, annular to 250 psi Low/ ,yao psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. The initial test of all Li ; / � • i Well Prognosis Well: MPU J-24 IliIcorp Alaska,LL Date:9/6/2016 rams, chok manifold, kill li - . es,standpipe equi ment,floor& top, ive valves will be to 250/5000 r F t, psi(Annuls to 250/3500 psi0 per •Pl RP 5317.3,2:2 p 'or to the equitpmen being put into a rational service. S bsequenttests of the 8e' equipment will be o 250/3000 psi for 5 min�(annular t 50% rated WP, 500,psi on the high test • initial and subse ent,.tests). a. Notify AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test rams on 4" and 4-1/2"test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV ' profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure ,,Gt, c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor , -1 t)&1 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. 6. Bleed any pressure off casing to returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 7. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 8. POOH and lay down the 4-1/2"tubing. Tubing will be junked (entire string).Junk all jewelry. 9. Contingency: (If the tubing is not fully cut). a. MIRU E-line and test lubricator to 3,000 psi. b. RIH and pump tools down to +/-7,650' MD. c. Jet cut 4-1/2"tubing. d. POOH. RD E-line. 10. PU Bit/Boot Baskets/Scraper/String Mill BHA. RIH on 4" Drillpipe. 11. Tag top of 4-1/2"tubing stub at 7,900' MD.Work scraper across kickoff and retainer depths of+/- 7,575'-7,585'. 12. POOH. Rack back 4" drillpipe. LD BHA. • w 13. MU cement retainer. RIH on 4" drillpipe. Set retainer at+/-7�5$S:..M.P �; �'°� C ? 14. Unsting from retainer. Set down 10k to confirm set. P'' � 15. RU cementers. Mix and pump 40 bbl of 15.8 ppg cement below retainer. 1Unsting from retainer. Circ btms up. 17 lose pipe rams and test 7" casing to 1,500 psi for 30 min and chart. iv, 1 '— • G'-s te— Cj 5t'tl`tJ. -v- _ 6utTazor- • Well Prognosis Well: MPU J-24 Iiileurp Alaska,LLDate:9/6/2016 18. POOH. LD retainer setting tool. 19. ***CONTINUE OPERATION ON PERMIT TO DRILL FOR MPU J-24A*** Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 0 • Milne Point Unit Well: MPU J-24 SCHEMATIC Completed: 4/15/2008 Hilcarp Alaska,LLC PTD: 200-149 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev=66.5'GL Elev.36.3' 20" Conductor 92/H-40/Welded N/A Surf 108' RKB-Tbg Hngr:21.3'(Nabors 3S) 7" Surface 26/L-80/BTC 6.151" Surf 8,664' q 4-1/2" Liner Ll 12.6/L-80/IBT 3.833" 8,284' 11,987' 204 ! 1y 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' r". TUBING DETAIL t# 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' s 4" • Pi ES Cementer JEWELRY DETAIL ;,..4 2,397 0 No Depth Item 1 0 2 ° 1 21.3' Tubing Hanger t a; 2 2,838' ST:1 KBG-2 GLM(DGLV 4/24/08) •ai ,e+) 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) f914 1,1 4 8,073' Baker S-3 Packer 9Cr o' 5 8,136' HES X Nipple-3.813"ID 6 8,196' HES XN Nipple-3.725"ID 7 8,207' WLEG 8 8,296' Baker ML Torque Master Packer ri 9 8,315' WLEG 10 8,563' Baker HMC Liner Hanger 11 11,964' OA Lateral 4-1/2"Pack-off Bushing t 1 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe 13 11,952' OB Lateral 4-1/2"Pack-off Bushing %*, 4,1 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe ' �rL OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set cmt to surface It i 7" 1600 sx Cement,2 stages,cmt to Surface iii 9-c GENERAL WELL INFO '1 API:50-029-22976-00/(60)-00 Drilled and Cased by Doyon 141-11/9/2000 Jet Cut Tbg: _ 4 ESP Installed by Nabors 4ES-11/21/2000 7,930� ESP Replaced by Nabors 4ES-5/20/2005 00, ESP Replaced by Nabors 4ES-9/01/2005 Fish.Cod shock absorber+jet ESP Replaced by Nabors 4ES-9/10/2006 cutter head 3 ESP Replaced by Nabors 35-7/02/2007 (Lost cluing cut) ? Convert to Jet Pump by Nabors 3S-4/15/2008 1 oulo:4 5 `' Nin It7 3.725'_4;�, -' 6 ....7, fe Ri 7 i7 RA Tag 44 8,254 x` 11 T, I L--, Fill Cleanout '' 12 8,280'CTM 't e, 0:11 A"q- 8 4 lig 10 • '3' 1--4- ‘I, q \ 13 is . 2 , , 14 7" TD=11,975'(MD)/TD=3,858'(1VD) PBTD=11,975'(MD)/PBTD=3,858'(1VD) Downhole Revised:8/05/2016 Updated By:CJD 9/01/2016 • • Milne Point Unit 14Well: MPU J-24 PROPOSED Completed: 4/15/2008 Hilary Alaska,LLC PTD: 200-149 Orig.KB Elev=66.5'GL Elev.36.3' CASING DETAIL RKB—TbgHngr:21.3'(Nabors 3S) Size Type Wt/Grade/Conn Drift ID Top Btm M4 20" Conductor 92/H-40/Welded N/A Surf 108' 20"4 sl @' fss 7" Surface 26/L-80/BTC 6.151" Surf 8,664' 3" #' F 4-1/2" Liner L1 12.6/L-80/IBT 3.833" 8,284' 11,987' `* 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' TUBING DETAIL ES Cementer 2�T 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' i' , '4 ,,.,. d� JEWELRY DETAIL P' 3f No Depth Item s 1 7,585' Cement Retainer(Squeeze 40 bbl of 15.8 ppg Cement below) 2 7,900' Cut 4-1/2"Tubing _, 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) sf 4 8,073' Baker S-3 Packer 9Cr as ' 5 8,136' HES X Nipple—3.813"ID 1, ''`' 6 8,196' HESXN Nipple-3.725"ID 'A 7 8,207' WLEG ~,4 8 8,296' Baker ML Torque Master Packer 6.4 V 9 8,315' WLEG 10 8,563' Baker HMC Liner Hanger 1 11 11,964' OA Lateral 4-1/2"Pack-off Bushing al ."50.,; 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe 1. ,-I 13 11,952' OB Lateral 4-1/2"Pack-off Bushing r� > 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe k. i i,�.. ; i w A•• '1' OPEN HOLE/CEMENT DETAIL i , ,' 2 20" 260 sx Arctic Set cmt to surface 7" 1600 sx Cement,2 stages,cmt to Surface a !s If . , tc i ti, , GENERAL WELL INFO fi �,� API:50 029 22976 00/(60)-00 w,' 4 ^ ' 4 Drilled and Cased by Doyon 141-11/9/2000 " ESP Installed by Nabors 4ES—11/21/2000 J - ; ESP Replaced by Nabors 4ES—5/20/2005 ` ESP Replaced byNabors 4ES—9/01/2005 ` r ESP Replaced by Nabors 4ES—9/10/2006 Mn ID:3 725" , .A ;; 34 ESP Replaced by Nabors 3S-7/02/2007 i k` ' ,? Convert to Jet Pump by Nabors 3S—4/15/2008 RA Tag: 8,254' r S 1 11'' 11 ;, .r e12 .°rte it't 4w> 4 .›••L4 8 1 In0 Y: \ 13 44 14 AI I TD=11,975'(MD)/TD=3,858'(1VD) PBTD=11,975'(MD)/PBTD=3,858'(1VD) Downhole Proposed Updated By:CJD 9/01/2016 • 0 18.0 B(_)P Schematic Q In mem / —13-5/8"SM Control Technology Annular BOP tail gi TI: Illal Z ® TI i 13 518"5M Contro ® aI Zil Technology Double Ram cti,4 rj 8 TI` 31,'8'Kill Line—. H rr.; , 11*/:i {�.i.v�1�� 0`14%' U ' i`o _ I —3.118 Choke Line lir60 : T ® iI jon Mel T /." TI.1- "--------13-5i8"5M Control I Technology Single Ram 13.5!8"5M X 11"5M OSA C( r 1:,----2.1116"FMC HWO Valve v r - --- Q11"x 11'5M FMC Gen S Tubing Spool u nay! c _----FMC Starting Head I v ------2.1;16"FMC MO Valve u. f / �`j ----20"Conductor 7"Casing i 0 0 19.0 Wellhead Schematic MPJ-24 C4-r 1 ,...,....-.. . ._ ..; IMMO ..., 11111 . . .11111.. mom 11! 4 1/16 OW Tree i I'0)• ! ' a AIM 1 i i 4 4. .T.4 it " AWL T![ "* ,..;1111 : -1 .7- ElII L.—ion ill r 111: gini,--S. • . I I 1 1111 . 1 kri;:# •it, ... .. „ ,..... .,. L li 4 I 0 1,10,11 . ll p .;40.11 2710MCHWOw, Ili" II UPI; Pi , • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, September 29,2016 10:40 AM To: 'Luke Keller';Quick, Michael J (DOA) Cc: Cody Dinger;Stan Porhola Subject: RE:J-24A(PTD:216-120) Rig Change Luke, Thanks .. I will update the sundries/PTD with new BOP test pressures.( no initial high test pressure needed) . We obviously have the BOPE sketches on file so no issues with rig change. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALIIYNOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Luke Keller [mailto:Ikeller@hilcorp.com] Sent:Thursday, September 29, 2016 10:15 AM To: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Cc: Cody Dinger; Stan Porhola Subject: J-24A(PTD: 216-120) Rig Change Guy/Mike, For the recently submitted MPU J-24A PTD(216-120)and MPU J-24 sundries 316-461 and 316-462 for the parent well P&A,we will be using the Doyon 14 to conduct this work instead of the Hilcorp Innovation. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 1 • • 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 "PlugRedrill" for box Geologist in the 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 Geo 6gist work)the initial reviewer will cross out that erroneous entry and initial �/ then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the"Suspended"box and initial that change. Drilling Engineer 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 Stat Tech for 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 Stat Tech History tab 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 Stat Tech change 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 Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA • RECEIVED AKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SES 0 1. 201h 1.Operations Abandon El Plug Perforations U Fracture Stimulate U Pull Tubing U .f"�OGCCCT FCO U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Coil Tubing Cut 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 200-149 3.Address: Stratigraphic[7] Service ❑ 6.API Number: fri 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22976-00-00 1. , 7.Property Designation(Lease Number): 8.Well Name and Number: (' ADL0025515/0025517/0025906 MILNE PT UNIT SB J-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 11,975 feet Plugs measured N/A feet true vertical 3,858 feet Junk measured 8,243(FILL) feet Effective Depth measured 11,987 feet Packer measured 8,073&8,296 feet true vertical 3,819 feet true vertical 3,798'&3,862 feet Casing Length Size MD TVD . ,Fjj gt Collapse Conductor 108' 20" 108' 108' 1,530psi 520psi Production 8,664' 7" 8,664' 3,920' 7,240psi 5,410psi Liner 3,412' 4-1/2" 11,975' 3,858' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED FEB 1 3201Z True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT-M 8,207' 3,839' Baker S-3 Packer Packers and SSSV(type,measured and true vertical depth) Baker Torque Master N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: NIA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ill Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-384 Contact Stan Porhola Email sporhola(cr�hilcorp.com Printed Name Bo York Title Operations Engineer Signature • /,Z, -,./1"--7. Phone 777-8345 -. Date 9/1/2016 r i (0„c4. i (.0. /01 /pich Form 10-404 Revised 5/2015 RBDMS UvSEP - 6 2016 Submit Original Only • S II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-24A CTU 50-029-22976-00-00 200-149 8/4/16 8/5/16 Daily Operations 8/3/2016-Wednesday No activity to report. 8/4/2016-Thursday Mobilize from F-pad to J-Pad. Wait for LRS to complete MIT-IA.Test annulus to 3,000 psi for 30 min (good test). MIRU Hal CTU equip. Perform BOPE test.Test all rams and valves 250/3,500psi.,praw down test. BOPE test complete no failures. 24hr AOGCC BOPE witness test notification sent 8/3/16 @ 15:10 hrs. MU cleanout BHA. Stab on well and PT quick test sub to 250/3,700psi. Good test. RIH with 2.5" OD DJN taking returns to tank. Tag top of fill at 7,920' CTMD. Clean out down to 8,200' in 50' bites. POOH. Stand back CT injector. Secure well for night. No night activity. 8/5/2016- Friday Arrive on location. PJSM. Fire up equipment. Get on well with CT injector. Stab on well and PT quick test sub to 250/3,800psi. Good test. Open well. RIH with 2.5"jet swirl nozzle. Dry tag top of fill at 8,205' CTMD. Clean out thru the tbg tail (8,207') and into the 7". Lost returns at 8,243'. Regained returns after pulling back. RBIH and dry tag at 8,280' ctmd. Desired CO depth was 8,296'. Hard tag. No over pull on PU.Attempt injection test.Able to inject: lbr m/13.psi WHP 2bpm/280psi WHP-3bpm/385psi WHP. POOH. At surface, shut in well. L/D tools. PJSM. MU Halliburton tubing cutter BHA assembly. Stab on well and PT quick test sub to 3,800psi. Good test. RIH 3.62"tbg cutter. Ck Wt-6.3k at 2,550'/ 17.6k at 7,450'.While RIH tie into IA and pressurize to 500psi with 60/40 meth. Stop RIH at 7,925', Load and launch 1/2" steel. PUH to desired CUT DEPTH -7,900'. Ball on seat at 32.9 bbls.Seat sheared at 4,300psi CTP.Annulus pressure immediately dropped to 110 psi. S/D pump. POOH, pump 38 bbls 60/40 for well freeze protect.While pumping the tubing and IAP X . tracked.At surface. L/D tools. Shock absorbor and cutter left in hole. 1/2" ball recovered. Displace coil with N2 out to flowback tank. Pumped 30,000 scf. Isolate N2 pumper. RD N2. RDMO CT equipment. Well Secure. 8/6/2016-Saturday No activity to report. 8/7/2016-Sunday No activity to report. 8/8/2016- Monday No activity to report. 8/9/2016-Tuesday No activity to report. • Milne Point Unit .11 • Well: MPU J-24 SCHEMATIC Completed: 4/15/2008 llilcorp Alaska,LLC PTD: 200-149 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev=66.5'GL Elev.36.3' 20" Conductor 92/H-40/Welded N/A Surf 108' RKB—Tbg Hngr:21.3'(Nabors 3S) 7" Surface 26/L-80/BTC 6.151" Surf 8,664' i 1 k 4-1/2" Liner L1 12.6/L-80/IBT 3.833" 8,284' 11,987' 20' 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' , ' TUBING DETAIL r'' 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' zs JEWELRY DETAIL �., ES Cementer 2,397 &' No Depth Item 1 2 `0a 1 21.3' Tubing Hanger ,`l '. 2 2,838' ST:1 KBG-2 GLM(DGLV 4/24/08) 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) e, s 4 8,073' Baker S-3 Packer 9Cr � 0 5 8,136' HESX Nipple-3.813"ID (� 6 8,196' HESXN Nipple-3.725"ID 7 8,207' WLEG 18 8,296' Baker ML Torque Master Packer ? 9 8,315' WLEG g 10 8,563' Baker HMC Liner Hanger : n 1 1 11 11,964' OA Lateral 4-1/r Pack-off Bushing 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe 1, 13 11,952' OB Lateral 4-1/r Pack-off Bushing 1$1 P:. 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe OPEN HOLE/CEMENT DETAIL z 20" 260 sx Arctic Set cmt to surface S7" 1600 sx Cement,2 stages,cmt to Surface GENERAL WELL INFO 1 ;x API:50-029-22976-00/(60)-00 / ----- Drilled and Cased by Doyon 141-11/9/2000 Jet � & ESP Installed by Nabors 4ES—11/21/2000 Cut7,900 CTM }*, ESP Replaced by Nabors 4ES—5/20/2005 `a; i . ESP Replaced by Nabors 4ES—9/01/2005 Fish Coil shockESP Replaced by Nabors 4ES 9/10/2006 absorber+let ESP Replaced by Nabors 35—7/02/2007 cutter heads 1, 3 (Lost during cut) tf ,' Convert to Jet Pump by Nabors 3S—4/15/2008 #e p? i1, .ia f r 7! 4 Ii'"; 5 1. Mn ID:3.725"4_, .f,* A 6 ,,„,,,. I , �a a 7 RA Tag: 11 8,254' 71 Fill Oea icut: ',. 12 8,280'CTM3i1 } ?,i? 10 t,,,' c r;:` 13 Al �« ” ........,.,......?:i�i 41 14 TD=11,975'(MD)/TD=3,858'(TVD) PBTD=11,975'(MD)/PBTD=3,858'(WD) Downhole Revised:8/05/2016 Updated By:STP 8/10/2016 • LOF Tit � V% THE STATE Alaska Oil and Gas 7� ofALAsKA Coservati®n Commission *Pt .�w - 333 West Seventh venth Avenue ' "Ir-.11GOVERNOR BILL WALKER +mar--+� •. An h rage, Alaska 99501 3572 Main: 907.279.1433 LAS Fax: 907.276.7542 A www.aogcc.alaska.gov Bo York Operations Manager WED OCT 3 12016 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-24 Permit to Drill Number: 200-14'i Sundry Number: 316-384 Dear Mr. York: 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, Daniel T. Seamount, Jr. Commissioner DATED this 23 day of July, 2016. RBDMS JUL 2 9 2016 • • RECEIVED • STATE OF ALASKA JUL 2 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El CT FCO Qt Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other: Coil-Cut Tubing Q• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: .Cs„.A. 1 Hilcorp Alaska LLC • Exploratory El Development 0• 200-149 • J 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: S 1r 3800 Centerpoint Dr,Suite 1400 50-029-22976-00-00 ® +�- 7.If perforating: 8.Well Name and Number: 11:: :'' y What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05• l ,/•,‘" Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT SB J-24 • l'‘-- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025515/0025517/0025906 • MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11,975' • 3,858' - 11,975' ` 3,858' - 1,173 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 108' 1,530psi 520psi Production 8,664' 7" 8,664' 3,920' 7,240psi 5,410psi Liner 3,421' 4-1/2" 11,975' 3,858' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M 8,208 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker S-3 Packer/Baker Torque Master Packer and N/A • 8,073'(MD)&3,798'(TVD)/8,296'(MD)&3,86Z(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development El ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/8/2016 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Sri Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature / f Phone 777-8345 Date 7/25/2016 COMMISSION USE ONLY - Conditions of approval: Notify Commission so that a representative may witness Sundry I 1-! Plug Integrity ❑ BOP TestL.V. Mechanical Integrity Test ❑ Location Clearance ❑ Other: S �, .-5 or ---f- ( c..._-r) Post Initial Injection MIT Req'd? Yes ❑ No ❑ 11 �/ . S .41 , Spacing Exception Required? Yes ❑ No Subsequent Form Required: /tS .-1/00 1 APPROVED BY 1 I Approved by. COMMISSIONER THE COMMISSION Date: ) 29 1 ,/ ?a 7-/2 -)t . ,J 747t''6 7- 7./4. QpRvticiG, LI Submit Form and Form 10-403 Revised 11/2015 I for 12 months from the date of approval. Attachments in Duplicate RRDMS 1111 7 9 7016 • • Well Prognosis • Well: MPU J-24 Flilcorp Alaska,L1,1 Date:7/22/2016 Well Name: MPU J-24 API Number: 50-029-22976-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point J-Pad Estimated Start Date: August 8th, 2016 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 200-149 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,573 psi @ 4,000'TVD (Last BHP measured 7/17/2008) Maximum Expected BHP: 1,573 psi @ 4,000'TVD (No new perfs being added, EMW= 7.6 ppg) ✓ MPSP: 1,173 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU J-24/J-24L1 was drilled in 2000 using Doyon 141 and completed as a dual-lateral in the Schrader Bluff OA and OB sands with an ESP using Nabors 4ES. The completion was pulled and the ESP completion changed out in 2005, 2005, 2006 using Nabors #4ES and 2007 using Nabors #3S. The completion was pulled and changed out in 2008 using Nabors#3S to replace the 2-7/8" tubing ESP completion with a 4-1/2" tubing Jet Pump completion.The well produced fill and large solids and has not produced since 2008. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 75.4° @ 5,273'). • Casing last tested to 3,000 psi for 30 min down to 8,073' on 7/19/2008. • Jet Pump is pulled and the sliding sleeve closed. • Deviation at pump is 71.3°. • Deviation at upper window into the OA lateral is 74.1°. • Deviation at liner hanger into the OB lateral is 83.3°. • Tubing Grade is L-80. Min ID is 3.813" in the 4-1/2" and 3.725"thru XN profile. • Last Fill Depth: 7,910' MD tagged on 10/16/2008. Objective: The purpose of this work/sundry is to cleanout the well to the top of the OB lateral, and cut the tubing in preparation for a drilling rig to pull the tubing and sidetrack the well. d Brief Procedure: Slickline/Pumping Procedure: 1. MIRU Slickline and test lubricator to 3,500 psi. 2. RIH and set DGLV(Dummy Gaslift Valve) in GLM at 2,838' MD. POOH. 3. Rig Down Slickline. 4. MIRU Pump Truck. PT Lines to 3,500 psi. 5. Perform MIT-IA on 4-1/2"x 7"to 3,000 psi for 15 min and chart. • • Well Prognosis • Well: MPU J-24 ffiico=u Alaska,LL' Date:7/22/2016 6. Rig Down Pump Truck. Coiled Tubing Procedure: 7. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. 8. NU BOPE and pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notify AOGCC 24 hours prior to testing BOPE. c. Submit 10-424 form within 5 days. 9. RIH w/1.75" coil w/2.5"to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to Baker Torquemaster Packer at+/-8,296' MD (above OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules(LEM) so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. c. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to Baker Torquemaster Packer at+/-8,296' MD. POOH. ,✓ d. Contingency: If unable to circulate fluid to surface without significant losses (<50%returns or little to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). CO X 10. Contingency: If unable to cleanout fill w/wash nozzle, RIH w/ 1.75" coil w/2.88"to 3.5" max OD motor and mill and extended reach cleanout BHA and cleanout to Baker Torquemaster Packer at+/-8,296' 0 MD. POOH. a. Circulate out fill using 8.5 ppg seawater w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. L1.l(' b. Contingency: If unable to circulate fluid to surface without significant losses(<50% returns or little 11; to no solids circulated to surface). Circulate out fill using 8.5 ppg seawater w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). 11. RIH w/jet cutter and cut tubing at+/-7,985' MD. POOH. to/ C--r 12. PU to 2,500' and freeze protect well. POOH w/coil. 13. RD Coiled Tubing and ancillary equipment. 14. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic 4. Nitrogen Operations Procedure 5. Nitrogen Flow Diagram • Milne Point Unit •H 410 Well: MPU J-24 . SCHEMATIC Completed: 4/15/2008 Iliilcorp Alaska,LLC PTD: 200-149 Orig.KB Elev=66.5'GL Elev.36.3' CASING DETAIL RKB-Tbg Hngr:21.3'(Nabors 3S) Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surf 108' 1 t. 21 L 7" Surface 26/L-80/BTC 6.151" Surf 8,664' 4-1/2" Liner L1 12.6/L-80/IBT 3.833" 8,284' 11,987' ' 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' TUBING DETAIL ES Cementer 2397 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' a, )a 2 rt JEWELRY DETAIL No Depth Item °"s 1 21.3' Tubing Hanger 2 2,838' ST:1 KBG-2 GLM(Empty Pocket 4/24/08) 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) r 4 8,073' Baker S-3 Packer 9Cr 5 8,136' HES X Nipple-3.813"ID 6 8,196' HES XN Nipple-3.725"ID 7 8,207' WLEG 8 8,296' Baker ML Torque Master Packer 9 8,315' WLEG 10 8,563' Baker HMC Liner Hanger i 11 11,964' OA Lateral 4-1/2"Pack-off Bushing 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe 13 11,952' OB Lateral 4-1/2"Pack-off Bushing ,r 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set cmt to surface Fill Tagged: `;a 7" 1600 sx Cement,2 stages,cmt to Surface 7,910 10/16/08 3 4 o`' ,' , GENERAL WELL INFO API:50-029-22976-00/(60)-00 Drilled and Cased by Doyon 141-11/9/2000 '.,P;71:4:-.1-:17:144 ESP Installed by Nabors 4ES-11/21/2000 $ ESP Replaced by Nabors 4ES-5/20/2005 ;, S ESP Replaced by Nabors 4ES-9/01/2005 ESP Replaced by Nabors 4ES-9/10/2006 Mn ID.3.725" r. 6 . ESP Replaced by Nabors 35-7/02/2007 s Convert to Jet Pump by Nabors 3S-4/15/2008 7 RA Tag: 11 8,254' i,? 12 t i ��. ,S�+" 8 PI 9 10 13 1,, 14 , TD=11,975'(MD)/TD=3,85811VD) PBTD=11,975'(MD)/PBTD=3,858'(1VD) Created By:STP 7/22/2016 . • Milne Point Unit Well: MPU J-24 PROPOSED Completed: 4/15/2008 llilcorp Alaska,LLC PTD: 200-149 Orig.KB Elev=66.5'GL Elev.36.3' CASING DETAIL RKB—Tbg Hngr:21.3'(Nabors 3S) Size Type Wt/Grade/Conn Drift ID Top Btm 1 4 p. 20" Conductor 92/H-40/Welded N/A Surf 108' 20'4 ¢ 7" Surface 26/L-80/BTC 6.151" Surf 8,664' 4-1/2" Liner Ll 12.6/L-80/IBT 3.833" 8,284' 11,987' ( 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' `,0 _ TUBING DETAIL :- 2,397 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' '4 ES Cementer ? P Ire c r:). 2 L ret 1 JEWELRY DETAIL No Depth Item i ;114 1 21.3' Tubing Hanger 2 2,838' ST:1 KBG-2 GLM(Empty Pocket 4/24/08) 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) t 4 8,073' Baker S-3 Packer 9Cr V11 Al 5 8,136' HES X Nipple-3.813"ID ) 6 8,196' HES XN Nipple-3.725"ID , 7 8,207 WLEG ,01 8 8,296' Baker ML Torque Master Packer r; 9 8,315' WLEG 10 8,563' Baker HMC Liner Hanger 11 11,964' OA Lateral 4-1/2"Pack-off Bushing 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe 1.: Fa" 13 11,952' OB Lateral 4-1/2"Pack-off Bushing '' 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe a s OPEN HOLE/CEMENT DETAIL Jet Cut Tbg V' 20" 260 sx Arctic Set cmt to surface T90a Proposed „I it ' 7" 1600 sx Cement,2 stages,cmt to Surface i i i 3 ';1 A r GENERAL WELL INFO API:50-029-22976-00/(60)-00 Drilled and Cased by Doyon 141-11/9/2000 add <4 ESP Installed by Nabors 4ES—11/21/2000 r ESP Replaced by Nabors 4ES—5/20/2005 ' 5 ESP Replaced by Nabors 4ES-9/01/2005 Mn ID 3.725"4_0. ESP Replaced by Nabors 4ES—9/10/2006 6 ESP Replaced by Nabors 35—7/02/2007 Convert to Jet Pump by Nabors 35 4/15/2008 7 RA Tag: 11 8,254' FII Geanout: 12 8,296'Pro•..-. k yl9 8 1* i':::::ZWM.‘ 10 :•� 13 .41 14 ° TD=11,975'(MD)/TD=3,858'(TVD) PBTD=11,975'(MD)/PBTD=3,858'(TVD) Created By:STP 7/22/2016 • • •• • iiiMilne Point Unit COIL, ROPE MPU J-24 7/22/2016 H knrp Ab*'.ka.1.1A, MPU J-24 20x7x4'A Coil Tubing BOP Lubricator to injection head 11 ---lin 1.75"Single Stripper till' I I , Blind IE. 1/1615 =BBlind ,I,'•%� Via_ l\\\ 'I■IuI0 � M■I• _ Slip Slip LI,' 1) C� 11)11111l&.111111111 Pipe _mg 111111 NW; Pipe •L'1 Is Crossover spool e MI 41/16 15M X41/16 10M r Crossover spool af i 4 1/16 10M X 4 1/16 5M ; o Pump-In Sub ■ W, • IT,'W c 41/165M it(°�. ': ,:(° 111111 1502 Union A fti d c • 3 I IV Gate Ma Manual Gate i.i �i.i 2 1/8 5M 2 1/8 5M Valve,Swab,WKM-M, -- � 4 1/16 5M FE { \I "- ��e,�� 6,pE \ / ci, „o ALi o 4 . 1 u / \ Valve,Upper Master,Baker, 4 1/16 5M FE,w/Hydraulic Valve,Lower Master,WKM-M, � ° 41/165MFE . ;;_a I.i-i',ili'-'1 O y Tubing Adapter,4 1/16 5M MAO ':i.",�� • STANDARD WELL PROCEDURE Hileorp Alaska,lit: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 " r • r ,6,1, 1111 r r x x s-!. 7 V, g ym m b o 3 v v ° o > > U • C •. •. 0 ro roE" , w z w C I ro o K w w W P .-1 Vwv LLI o ao V) "� f • a rQ I Z > m p p - n. > T is C7 a ~ W N > Y E ` Z Z . ❑ > v a8i 0' a• �• w > c7 w U a" ..r r 'Ii' $aII'aa p. O. Tina N Vr r o r -- 1111 111111111111 zsc DODOC O O W Y •O W Z r a LL U O O O C CO W mr NC o_ 7 Z Q r J m 00 O O 23 ~te Project Well History File (~'er 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 ldo,,~i [] RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED (Scannable) [3 Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Sca'~ning Preparation ,,~ x 30 = '~_..~ BY: BEVERLY ROBIN VINCENT SHERYL~~ WINDY [] Other 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: ~ YES __ _ ,q NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED o'N,,~UJ~VI~AL PAGE BASIS I RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ~si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ., 21112 December 30, 2011 E F A Mr. Tom Maunder Alaska Oil and Gas Conservation Commission o o - ' L 333 West 7th Avenue O�, Anchorage, Alaska 99501 ,) n a Subject: Corrosion Inhibitor Treatments of MPJ -Pad r V 1 e3* Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator .x ic3ms#w'w': f 1TT1T'%�'£ "xiV "xwK.i R•^°. _...:. r .. i Y l 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor , NA NA NA NA NA MPJ -02 1900960 50029220710000 _ Sealed Conductor NA NA NA NA NA MPJ 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ-05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ -06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ-09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ - 11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 ----,' MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 r'~~l>CI~/CL1 STATE OF ALASKA ,5 d' ALA OIL AND GAS CONSERVATION CO SION MAY 1 9 ZOOS REPORT OF SUNDRY WELL OPERATIONS~~~~s~a C,lt ~ has Cons. Commissio, 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Pv\I, 1 ' ' ^ Change Approved Program ^ Operation Shutdown ~R S ^ Perforate ^ Time Extension CI~t1e ESP i tc 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Nu ber: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-149 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22976-00-00 7. KB Elevation (ft): 66.05 - 9. Well Name and Number: MPJ-24 8. Property Designation: 10. Field /Pool(s): _ ~9DL OQ®?S~> > ADL 025515 /90~o~s9~6 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 11975 ~ feet true vertical 3858 - feet Plugs (measured) N/A Effective depth: measured 11975 feet Junk (measured) N/A true vertical 3858 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8635' 7" 8664' 3920' 7240 5410 Liner 3421' 4-1/2" 8554' - 11975' 3913' - 3858' 8430 7500 >~'tr/1+C9~D~~4d ~~~ ~ ~ ~~ ~~ Perforation Depth MD (ft): Slotted Liner 8657' - 11954' Perforation Depth TVD (ft): Slotted Liner 3920' - 3859' 4-1/2", 12.6# L-80 8208' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 8073' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 NIA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Si ature Phone 564-4750 Date ~ ~' ~ rj'~Sondra Stewman, 564-4750 ~` Form 10-404 Revised 04/2006 ~~'~ Np~~` ~ ~ ~D~a/ ~~ Submit Original Only ORIGf NAI ~~I`,ir c~~ Tree: 4-1/16" 5M FMC Tree _ Wellhead: 11" x 11" 5M tbg. spool, l 1" x 4-1/16" 4 1/2" TC-II (top & bottom) FMC TBG HNG w/4"'H' BPV profile. 2' of blast rings installed 110° Halliburton ES cementer 2,397' 4 1/2" 12.6ppf L-80 IBT-M tubing. ( Capacity = .0152 bpf) 7" 26 ppf, L-80, BTC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) KOP ~ 600' Max wellbore Angle: 75° @ ' MD Hole angle through perfs = 90 deg. HES XN Nipple @ 8196' MD Minimum ID= 3.725" RA tag at 8254' 3 Short joints 8119'-8242' M P J X24 \ ~ I _ KB elev. = 28.55' \\\ DF elev. = 66.05' GL elev. = 36.30' SLB 4 1/2" x 1" KBG-2 SPM 2838' Milled window from 8264'-8276' Baker HR setting sleeve 8284' o ~ I 4 1/2" HES XD Durasleeve 8010' 3.81" polish bores 4 1/2" x 7" Baker S-3 Packer 8073' 3.875" I D 4 1/2" HES X-nipple 3.81" Polish Bore 8136' 4 1/2" HES XN-nipple 3.81" Polish Bore 8196' 3.725" No-Go WLEG 8207' Baker 7" ML torque master pkr 600-47 I 6296' I ' ' -8373 2jts. of solid liner (82') 8291 Wireline en try guide 8315' 91jts. of slotted liner (3590') (8373'-11964') ' 4.5" 12.6#, L-80 IBT tubing Baker HR setting sleeve 8553 Baker Float shoe at 11986' Baker HMC liner hanger 8563' 6577' Hallibunon landing collar Halliburton float collar 8620' I 4.5" 12.6#, L-80 IBT tubing. Halliburton float shoe 8664' Baker Float shoe at 11975' SSjts. of Slotted liner (3296') (8656'-11953') 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') Mid-lateral ND @ 3877' OA- 8,656' - 11,953' MD (3296') 5120/OS L. Hulme ESP replacement by 4ES 9/01/05 MDO ESP Replacement by 4ES 9/10/06 REH ESP Replacement by 4ES 7/2/07 L. Hulme ESP w/ desander & screens replacement by 3S 04-15-08 JRP 3S RWO conversion to Jet pump completion MILNE POINT UNIT WELL J-24 API NO: 50-029-22976-00°oL S~ -vZ9 ~ Zzq't(~ ~i~1 BP EXPLORATION (AK) • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: WORKOVER Start: 4/9/2008 End: 4/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: Date From- To Hours' Task. Code NPT Phase Description of Operations 4/9/2008 06:00 - 10:00 4.00 MOB P PRE R/D floor, lower mast, move pipeshed, pits and move carrier off of P-21. 10:00 - 17:00 7.00 MOB P PRE Move from GPB P-pad through U-pad, N-pad onto the Spine Road to Milne Point Road. Down Milne Point Road to Texaco Pad. 17:00 - 19:30 2.50 MOB P PRE Wait on Milne Point crew bus change out. 19:30 - 22:00 2.50 MOB P PRE Move from Texaco Pad to Milne Point J-pad. 22:00 - 23:30 1.50 MOB P PRE Move equipment on pad and spot camp, shop, generator and parts house. 23:30 - 00:00 0.50 MOB P PRE Spot BOP cradle behind well MPJ-24 4/10/2008 00:00 - 02:00 2.00 MOB P PRE Line up BOP cradle, Line up carr er'and lay herculite. Back carrier up toward well. Lost power in carrier. 02:00 - 03:30 1.50 MOB P PRE Broken drive line on carrier. Remove broken shaft and spot over well using forklift. 03:30 - 04:30 1.00 MOB P PRE Jack and level carrier, Spot pipeshed. 04:30 - 08:00 3.50 MOB P PRE Lay herculite and spot pits. Spot cuttings tank and boiler blowdown tank. Berm rig. Set stairs and walkways in place. Spot change room. Put steam around the Rig. Spot Tiger Tank. 08:00 - 10:00 2.00 RIGU P PRE PJSM. Raise and scope the Derrick. MU Flow Line and pin the wind wall. 10:00 - 12:00 2.00 WHSUR P DECOMP The Rig was accepted at 10:00 hrs on 4/0/2008. RU circulating lines to the Tree to pump down the Tubing and take returns up the IA through the Choke to the Tiger Tank. Pressure test return line to the Tiger Tank to 500 psi - OK. 12:00 - 13:00 1.00 WHSUR P DECOMP PU and RU Lubricator with Well Support Techs. Pressure test the Lubricator to 500 si with diesel. Pull the BPV. Pressure on the Tubing = 60 psi and pressure on the IA = 50 psi. 13:00 - 16:30 3.50 KILL N DECOMP Main fuel line on the rig is frozen, cannot keep either engine running. It appears that there is water in the fuel (contaminated). Call for heater and thaw out. 16:30 - 17:00 0.50 KILL P DECOMP Pressure test all surface lines to 2,500 psi. 17:00 - 20:00 3.00 KILL P DECOMP Pre-kill safety meeting. Notify Pad Operator and MPU of gas venting. Open the well and show 0 psi on the Tubing and 0 psi on the IA. Bleed the IA and the Tubing to the Tiger Tank. Break circulation down the Tubing taking returns up the IA to the Tiger Tank at a rate of 3.25 bpm / 40 psi with no returns. Pump a Tubing volume (46 bbls) and shut in the IA. Bullhead 46 bbls down the Tubing at a rate of 3.25 bbls / 300 psi (caught fluid after 31 bbls). Line up and Pump 75 bbls down Tubing taking returns up IA to the iger Tank with no retums. ine up to Bullhead down IA 4bpm at 380 psi, with 80 bbls away lost rod oilers on Mud Pump. 20:00 - 22:00 2.00 KILL N DECOMP Work on rod oiler on Mud Pump. While working on rod oiler the rig power went down with fuel line problems. Get second heater and put on fuel lines. Adapt barrel pump to use as rod oiler. 22:00 - 23:30 1.50 KILL P DECOMP Continue with Bullhead kill down IA at 4bpm with 480 psi. Pump 172 bbls and lost rig power. 23:30 - 00:00 0.50 KILL P DECOMP Work on fuel system on rig. C/O primer pump on generator. Bled fuel injector and get generator restarted. 4/11/2008 00:00 - 00:30 0.50 KILL P DECOMP Continue Bullhead down the IA 4bpm with 480 psi. A total of 355 bbls was pumped down IA. 00:30 - 01:00 0.50 KILL P DECOMP Bullhead 46 bbls down Tubing 2.5 bpm with 510 psi. Printed: 4/21/2008 1:14:11 PM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: WORKOVER Start: 4/9/2008 End: 4/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 4/11/2008 01:00 - 01:30 0.50 KILL P DECOMP Monitor well 0 psi on Tubing and IA. Both IA and Tubing on a vac. 01:30 - 03:00 1.50 WHSUR P DECOMP P/U T-B and install 3" e H TWC with FMC wellhe d tech. Test from above to 3,500 si for 10 minutes. Good test. 03:00 - 05:00 2.00 WHSUR P DECOMP N/D tree and remove from cellar. Had to work SBMS seal free. Function all Lock Down Screws. Inspect hanger threads. 05:00 - 07:00 2.00 BOPSU P DECOMP Prep spool to N/U. Locate 11"spool. PU the Stack and set back. 11" x 13-5/8" Spool is en route from Nabors 4ES. 07:00 - 08:30 1.50 PULL P DECOMP Hold PJSM and RU the ESP Sheave and Elephant Trunk in the Derrick. RU the 2-7/8" and 4-1/2" Test Joints in preparation for the BOPE test. Prepare the floor for POOH. 08:30 - 11:00 2.50 BOPSU N DECOMP Wait on the 11" x 13-5/8" Spool to arrive on location. Clean and maintain the Rig. Grease the choke valves. Continue feeding the well down the IA with 30 bbts per hour of seawater. 11:00 - 16:00 5.00 BOPSU P DECOMP Spool arrives on location. NU the Spool onto the wellhead. PU and NU the 13-5/8" 5M BOPE. Hook up Accumulator lines. At 14:30 hrs, spoke with AOGCC inspector John Crisp and gave a 2 hour notification on the test. 16:00 - 18:00 2.00 BOPSU P DECOMP Test gas detector alarms - OK. Function test all components. Fill BOP stack and manifold with water. 18:00 - 19:00 1.00 BOPSU P DECOMP M/U test assembly and body test choke manifold and BOP stack while waiting for AOGCC inspector. 19:00 - 23:00 4.00 BOPSU P DECOMP Test BOPE, Choke Manifold, and Floor delves to 250 psi low pressure and 3,500 psi high. VBR's and Hydril were tested with 2-7/8" and 4-1/2" test joints. Each test was held for 5 minutes on the chart. One failure, dart valve failed. Replaced with spare and tested. Perform draw down test on Koomey system. BOP test was witnessed by BP WSL, Nabors Toolpusher and AOGCC inspector John Crisp. Continue feeding the well down the IA with 30 bph of seawater. 23:00 - 23:30 0.50 BOPSU P DECOMP UD BOP test assembly and drain stack. 23:30 - 00:00 0.50 WHSUR P DECOMP P/U Opso Lopso and M/U XO's. Screw Opso Lopso into tubing hanger. 4/12/2008 00:00 - 02:30 2.50 WHSUR P DECOMP M/U lubricator to Opso Lopso and test to 500 psi. O-ring in Otis connection leaked. C/O O-ring and retest to 500 psi. Good test. Pull tvge H TWC. Both tubing and IA on vac. 02:30 - 04:00 1.50 PULL P DECOMP M/U landing joint with TIW valve and screw into tubing hanger. FMC wellhead tech backed out lock down screws. Pull hanger to floor, came off seat at 52K, up weight 48K, UD landing joint. 04:00 - 05:00 1.00 PULL P DECOMP UD tubing hanger and run ESP cable through sheave and containment trunk. 05:00 - 12:00 7.00 PULL P DECOMP POOH with ESP completion standing back 2-7/8" tubing. Maintaining continuous fill of 30 bph. 60 stands out at 09:00 hrs. 95 stands out at 10:30 hrs. 12:00 - 15:30 3.50 PULL P DECOMP On surface with existin ESP Assembl Recovered a total of 251 Joints of 2-7/8" EUE 8rd Tubing, (2) 10' Pup Jts, (2) GLM Assemblies and 133 LaSalle Clamps. Break out and lay down ESP Components with Centrilift rep. Recovered 5 Protectolizers and 3 Flat Guards. 15:30 - 16:00 0.50 PULL P DECOMP On surface with (2) Joints of 4" IBT Baker Screens. The upper Joint had traces of sand and the bottom Joint was completely packed off with sand/fluid from top to bottom. 16:00 - 17:00 1.00 PULL P DECOMP Clear and clean Rig Floor. Lay down Screens, Pup Joints and Printed: 4/21/2008 1:14:11 PM BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: WORKOVER Start: 4/9/2008 End: 4/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT `Phase Description of Operations 4/12/2008 16:00 - 17:00 1.00 PULL P DECOMP LaSalle Clamps. 17:00 - 18:00 1.00 CLEAN P DECOMP PUMU 7" Scraper Assembly. PU (3) 2-7/8" EUE 8rd Tubing Joints that were laid down in the Pipe Shed. 18:00 - 18:30 0.50 CLEAN P DECOMP Service crown sheaves, wireline anchor, blocks and drawworks. Inspect brake bands and rollers. 18:30 - 00:00 5.50 CLEAN P DECOMP RIH with 7" Scraper Assembly on 2-7/8" EUE 8rd Tubing from derrick to 7,910'. Maintain 30 b h continuous hole fill. 4/13/2008 00:00 - 01:00 1.00 CLEAN P DECOMP P/U (10) joints of 2-7/8" EUE 8rd Tubing from 7,910' to 8,225'. Work Casing Scraper 6 times from 8,045' to 8,095' and 8,175' to 8,225' to cover packer and RBP setting depths. 01:00 - 06:00 5.00 CLEAN P DECOMP POOH with Casing Scraper Assembly standing back 2-7/8" EUE 8rd Tubing in derrick from 8,225'. Maintain 30 bph continuous hole fill. 06:00 - 07:00 1.00 CLEAN P DECOMP Pre-tour checks. Break out and lay down Scraper Assembly. RD ESP Single Sheave and Elephant Trunk Containment. 07:00 - 12:00 5.00 EVAL P DECOMP PUMU 7" RBP with Halliburton rep and TIH on 2-7/8" EUE 8rd Tubing from the Derrick. Maintain 30 bph fill rate with seawater while TIH. 50 stands in at 09:00 hrs. 12:00 - 12:30 0.50 EVAL P DECOMP In with 130 stands and one single of 2-7/8" Tubing. PUW = 38K ,SOW = 26K. Set the 7" RBP at 8,200' center of element with Halliburton re .Slack off 15K and overpull 5K to confirm set. Stand back 1 stand (2 Jts) in the Derrick. 12:30 - 13:00 0.50 EVAL P DECOMP MU TIW and Headpin. Fill the well with 34 bbls of seawater. Close the Annular. 13:00 - 14:00 1.00 EVAL P DECOMP Pressure test the 7" Casin a ainst the RBP to 3,500 si for 30 charted mins - ood test. The first 15 mins lost 100 psi and the second 15 mins lost 50 psi with signs of stabilization. 14:00 - 15:00 1.00 EVAL P DECOMP POOH 1 stand (2 Jts) and lay down a single. PUMU 7" RTTS with Sub Surface Control Valve and RIH on a single and 10' Pup Joint. 15:00 - 15:30 0.50 EVAL P DECOMP Set the 7" RTTS with Sub Surface Control Valve at 39' in with Halliburton re . 15:30 - 17:00 1.50 EVAL P DECOMP Test the 7" RTTS with Sub Surface Control Valve a ainst the Blind Rams to 3,500 si for 10 charted mins -good test. Bleed down all lines. 17:00 - 20:00 3.00 BOPSU P DECOMP ND the BOPE and stand back. Our two barriers are a tested 7" RBP at 8,200' and a tested 7" RTTS with Sub Surface Control Valve at 39'. N/D adaptor spool and remove from cellar. 20:00 - 22:00 2.00 WHSUR P DECOMP N/D CasinglTubing Head. Wipe head down and remove from cellar. Had no problems removing head. 22:00 - 00:00 2.00 WHSUR P DECOMP N/U new FMC 11" 5k Casin Head, Isolation Sleeve and new FMC 11 " x 11 " 5k Tubing Spool. Locking pins on Casing Head were torqued to 350 Ibs as per MC procedure. 4/14/2008 00:00 - 01:00 1.00 WHSUR P DECOMP Continue to N/U new FMC 11" x 11" 5k Tubing Spool. Test Isolation Sleeve voids to 1,000 psi for 10 minutes and Tubing Spool to 5,000 psi for 30 minutes. 01:00 - 04:30 3.50 BOPSU P DECOMP N/U 13-5/8" x 11" 5K DSA N/U BOPE, Install Choke Line, Kill Line and Koomey Hoses. Secure BOP Stack, install Flow Riser. Install Secondary Annulus Valve on IA. 04:30 - 06:00 1.50 BOPSU P DECOMP Function test BOPE. Fill BOP Stack with water and purge air from lines. Unibolt connection on kill line leaking. Break Unibolt connection and replace brass ring. Pressure test the break to 250 psi low and 3,500 psi high for 5 charted mins. Printed: 4/21/2008 1:14:11 PM • BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: WORKOVER Start: 4/9/2008 End: 4/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/14/2008 06:00 - 06:30 0.50 EVAL P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:00 0.50 EVAL P DECOMP PU 7" RTTS Pulling Tool with Halliburton rep. 07:00 - 07:30 0.50 EVAL P DECOMP Screw into the RTTS with 20 turns. Pull the RTTS per Halliburton re LD the 10' Pup Joint, single Joint and the RTTS. 07:30 - 08:00 0.50 EVAL P DECOMP TIH with 2 stands of 2-7/8" Tubing from the Derrick. 08:00 - 08:30 0.50 EVAL P DECOMP Circulate 70 bbls of clean seawater down the Tubing takin returns u the IA above the RBP to clean the well out of crude. Circulate at 4 bpm / 650 psi until clean returns observed on surface. 08:30 - 09:00 0.50 EVAL P DECOMP Latch onto 7" RBP at 8,200' per Halliburton rep. Pull the RBP and observe the fluid level drop on a strong vacuum. RIH past set depth to confirm that the RBP was latched and released. 09:00 - 17:00 8.00 EVAL P DECOMP POOH with 7" RBP laying down the 2-7/8" Tubing in the Pipe Shed. Maintain 30 bbl per hour fill rate while POOH. AES reps came out and shot the new spools. 150 Jts out at 14:00 hrs. 200 Jts out at 15:30 hrs. 17:00 - 17:30 0.50 EVAL P DECOMP Break and UD 7" RPB. Clear rig floor. 17:30 - 19:00 1.50 BUNCO RUNCMP R/D 2-7/8" Handling Equipment and R/U 4-1/2" Handling Equipment. 19:00 - 20:00 1.00 BUNCO RUNCMP Put 4-1/2" Completion in Pipe Shed and put in order. Hold PJSM with all personnel involved. 20:00 - 00:00 4.00 BUNCO RUNCMP P/U and run 4-1/2" Jet Pump Assembly. Run 4-1/2", L-80, u ~mg using Best- -Lie 2000 Pipe Dope. Make up to the Mark. Average Make Up Torque is 2,800 ft/Ibs. 70 joints in at 00:00 hrs. 4/15/2008 00:00 - 07:30 7.50 BUNCO RUNCMP P/U and run 4-1/2" Jet Pump Assembly. Run 4-1/2", L-80, 12.6#, IBT-M Tubing using Best-O-Life 2000 Pipe Dope. Make up to the Mark. Average Make Up Torque is 2,800 fUlbs. 125 joints in at 03:30 hrs. 160 joints in at 05:00 hrs. Ran a total of 206 Jts of 4-1/2" IBT-M Tubing. 07:30 - 08:30 1.00 BUNCO RUNCMP PU FMC Hanger Assembly. PUMU Headpin to 4-1/2" IBT Tubing. 08:30 - 09:30 1.00 BUNCO RUNCMP Pump 125 bbls of 120 degree clean seawater down the Tubing at a rate of 3 bpm / 300 psi to flush the Tubing. Shut down pump and monitor well. Both the Tubing and IA are on a vac. 09:30 - 13:30 4.00 BUNCO RUNCMP Blow down and break off the Headpin. Drop ball and rod down the Tubing. PUMU Tubing Hanger assembly to the 4-1/2" Tubing string. PUW = 70K ,SOW = 40K. Land Tubing Hanger and RILDS with FMC rep. Pump 150 Bbls of inhibited 120 degree SW down IA. 13:30 - 14:30 1.00 BUNCO RUNCMP Pressure tubing to 3500 psi w/ 98 strokes, pumping SW. Small lea on stand pipe. ee o , tig ten connection and re- ressure tubin to 3500 si w/ 96 strokes. Lost 90 si in 1 hour thermal decline 14:30 - 16:00 1.50 BUNCO RUNCMP Bleed Tbg pressure to 1500 psi. Pressure IA to 3500 psi w/ 193 strokes, um ing SW. Chart for 30 minutes. Tbg pressure to 2000 si. Bleed Tbg to 1550 psi ands ear D K va ve. Establish circulation both ways ~ 2 BPM, 110 psi. 16:00 - 18:00 2.00 WHSUR P RUNCMP rod TWC CIW 4" T e H w/ FMC. Blow down lines. Test from above to 3500 psi and from below to 1000 psi. Chart both tests for 10 minutes. 18:00 - 22:00 4.00 WHSUR P RUNCMP N/D BOPE, remove koomey hoses, flow riser, choke line and Printed: 4/21/2008 1:14:11 PM • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: WORKOVER Start: 4/9/2008 End: 4/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: .Date From - To Hours .Task Code NPT Phase Description of Operations 4/15/2008 18:00 - 22:00 4.00 WHSUR P RUNCMP kill line. Set BOP Stack on cradle and lay over. N/D DSA and remove from cellar. Secure kill and choke hoses out of way. Clear cellar area. 22:00 - 00:00 2.00 WHSUR P RUNCMP Prep wellhead, N/U FMC 11" x 4-1/16" 5k Adaptor Flange and 4-1/6" 5k Tree. 4/16/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Pressure test Adaptor flange to 5,000 psi for 30 minutes. Fill Tree with diesel and test to 5,000 psi. No leaks. 01:00 - 02:00 1.00 WHSUR P RUNCMP R/U Well Tech Lubricaqtor and pressure test to 500 psi. Pull 4" type H TWC. R/D and L/D Lubriator. 02:00 - 05:30 3.50 WHSUR P RUNCMP R/U Lines for pumping diesel down IA and taking returns out the tubing. R/U Little Red and test lines to 2,500 psi. Pump 75 bbls of diesel freeze protect down IA at 2 bpm with 800 psi. U-tube freeze protect from IA to tubing. 05:30 - 06:00 0.50 WHSUR P RUNCMP Set 4" Type H BPV. Normal up Tree. Rig released ~ 06:00 Printed: 4/21/2008 1:14:11 PM Digital Well File • Well: MPJ-24 Well History Well Date Summary MPJ-24 1/17/2008 T/I/0= 60/0 (IA Flush) Pumped 5 bbls 60/40 Meth, 125 bbls Produced Water, 5 bbls 60/40 Meth, and 125 bbls Crude into IA. Final WHP's=200/0 MPJ-24 1/17/2008 T/I/0= IA Flush Pumped 5 bbls 60/40 Meth, bbls Produced Water, 5 bbls 60/40 Meth, and bbls Crude into IA. Final WHP's= MPJ-24 1/18/2008 (Ice Plug in FL) T/I/0= 500/0 Pump 2 bbls neet meth down FL to free up Ice Plug. (NOTE: Could not clear Ice Plug) Left 300 Psi on FL. FWHP= 500/0 MPJ-24 1/21/2008 T/1= 0/0 Freeze Protect TBG and Flowlines ***Note*** Production Flowline is still Frozen Pumped 10 bbls Neat Meth into Test Flowline. Pumped 5 bbls Neat Meth and 15 bbls Diesel into TBG. Attempted to pump into Prod Flowline--No Success--. Final WHP's=0/0 MPJ-24 2/12/2008 ***WELL S/I ON ARRIVAL*** (caliper / mtt) DRIFT TUBING TO 600' SLM W/ 2.31 GAUGE RING FOR MTT TOOL RUN PDS CALIPER / MTT TOOL AS PER PROCEDURE, RECOVERED GOOD DATA. ***WELL S/I ON DEPART*** MPJ-24 2/26/2008 ***ARRIV ON LOC WELL S/I*** RIH TO PULL BOTTOM STATION ***CONT'D ON 02-27-08 WSR*** MPJ-24 2/27/2008 ***CONT FROM 2/26/08 PRE RIG MADE SEVERAL ATTEMPTS TO PULL 1" BK-DGLV FROM 7830' MD. PULLED 1" BEK-DPSOV FROM 145' MD, SET 1" BK-DGLV WILL RETURN TO FINISH RIG PREP *** INSTRUCTED TO RIG DOWN MOVE OUT *** TURN WELL OVER TO DSO MPJ-24 2/27/2008 (Freeze Protect FL and Testline) T/I/0= 0/0/0 Pump 6 bbls 60/40 meth followed by 4 bbls diesel then 6 bbls 60/40 meth down TL to freeze protect.FWHP= 0/0/0 (NOTE: Production line is frozen /pressured up to 950 Psi on FL) verified casing valves open to gauges. MPJ-24 2/28/2008 ***ARRIV ON LOC WELL S/I *** BHP ,_ PULLED 1" BK-DGLV FROM 7830' MD, LEFT OPEN RAN SBHP GAUGES MADE 30 MIN STOP ~ 7,509' SLM MADE 3 HR STOP @ 8009' SLM (7' CORRECTION ) *** TURN WELL OVER TO DSO **** MPJ-24 2/29/2008 Well Support Techs set BPV, pulled well house, production lines and foundation. ***NOTE*** BPV left in hole MPJ-24 3/12/2008 Freeze Protect -Pumped 5 bbls neat methanol to freeze protect flow line. (Flow line is disconnected from well, pumped from blind flange). Tag flow line & notify operator upon departure MPJ-24 4/23/2008 Pressure test Flow lines Prod, and test to 1150 PSI for 10 min. and Power fluid line Pressure tested to 3600 PSI for 10 min. Passed PT.also pulled BPV. PT fluid diesel. MPJ-24 4/23/2008 *** WELL SI ON ARRIVAL *** POST RWO PULL BACK PRESSURE VALVE OPEN SLEEVE C~3 8010' MD/8021 SLM PULL BAR & ROD ~ 8197 SLM MADE ATTEMPT TO PULL SHEAR VALVE C~3 2838 MD. ***CONTINUE ON 4/24/08*** MPJ-24 4/24/2008 (Assist wireline) T/I/0= 0/0/0 Pump 30 bbls dead crude down IA to verify sliding sleeve is open .Load 100 bbls diesel and pump down TBG as requested to assist wireline setting Jet Pump. (Awgers continued on 04-25-08 ) MPJ-24 4/24/2008 ***CONTINUE FROM 4/23/08***POST RWO PULL SHEAR VALVE C~3 2842 SLM SET DUMMY VALVE 1' W/ BK LATCH PULL RHC ~ 8195 SLM / 8196' MD. MADE DRIFT W/ 3.69" CENT AND S-BAILER TO 8250 SLM / 8251' MD. RECOVERED SAND LRS PUMPED ON BACK SIDE TO MAKE SURE THAT SLEEVE WAS OPEN RAN 4.5 X-LINE AND JET PUMP SN# 1090 A 12-A RATIO #12-NOZZLE #12 THROAT OAL 102" . UNABLE TO GET PASSED 5180' SLM ***CONTINUED ON 4/25/08 WSR*** MPJ-24 4/24/2008 (Assist Wireline) T/I/0= 0/0/0 Pump 30 bbls dead crude down IA to ensure sliding sleeve is open . Page 1 of 2 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 5/15/2008 Digital Well File ~ Page 2 of 2 MPJ-24 4/25/2008 MPJ-24 4/25/2008 MPJ-24 5/12/2008 Print Date: 5/15/2008 FWHP= 0/0/0 ***CONTINUE FROM 4/24/08 ***POST RWO SET 12-A JET PUMP (SN# BP-1090 HAS A 12-A RATIO, #12-NOZZLE, #12-THROAT ) ***TURN WELL OVER TO DSO **** ( Assist Wireline setting Jet Pump) T/I/0=0/0/0 Pump 100 bbls diesel down TBG to assist wireline going down hole. (Awgers continued from 04-24-08) FWHP= 0/0/0 T/1=0/0 (Freeze protect) Pumped 40 bbls Dead Crude down IA. Pumped 40 bbls Dead Crude down tubing. Pumped 2 bbls Neat methanol down each of the power fluid, Production and test flowlines. FWHP = 0/0 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 5/15/2008 " STATE OF ALASi{A 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: SS DATE: 4111/2008 Rig Rep.: J. Greco / J. Fritts Rig Phase: 659-4487 Rig Fax: 659-4486 Operator: Bp ~. Phone:. 659-4485 Op. Fax: 659-462$ Rep.: W. Hoffman / B. Burson Field/Unit 8~ Well No.: MP J-24 PTD # 2~149d Operation: Dr1g: Workover. x Explor.: Test: Initial: x Weeky: Bi-Weekly Test Pressure: Rams: 250/3500 Annu~r. 25013500 Valves: 250!3500 MISC. INSPECTIONS: lest Result Test Result Location Gen.: P Wet Sic,~e P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sea. P Standing Order Posted P BOP STACK: Quantity Size Test ResuiF Annular Preventer 1 13 5/$ 5000 P Pipe Rams 1 2 7/8 X 5 3? Lower Pipe Rams 0 NA Blind Rams t Blrced P Choke Ln. Valves 1 3 t/8" 5000 P HCR Naives 2 3 118" 5000 P Kill Line Valves 1 2 1116" 5000 P Check Valve 0 NA MUD SYSTEM: Vial Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P rest Resutts FLOOR SAFETY VALVES: Quantity Test Result Upper KeNy 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 FP CHOKE MANIFOLD: Quantity Test Result No. Naives 13 P Maul Chokes 1 P Hydrau~ Chokes 1 P ACCUMt~LATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Ck>s~e 1500 P 2130 psi Attained 30 sec P Fug Pressure Attaaeed 145sec P Bind Switch Covers: A~ stations P Nitgn. Bottles (avg}: 2t?t)t)~ Number of Failures: 1 Test Time: 4 Hours Components tested ALL Repair ar replacement of eemeret w~ be maw . Notify the North Slope Inspector 659-3607, foNow wine written c:onFamation to Su~eretiser ett: Remarks: Tested with 4112" and 2 718" test jo~rts. Rer~aced !nom BOP valve and retested. 24 HOUR N071CE GIVEN YES x NO ...Waived By Date 04/09108 Time 1900Hrs Witreess J.Fr~tts.B.Burson.J.Cr Test start 19:00Hrs Finish BOP Test (for rigs) ~~~ ~~~ ~ ~ ~~~~ BFL 11/14/07 Nabors 3s BOP Test MP J-24 4-11-08.x1s ., iii STATE OF ALASKA Y ALASKA OIL AND GAS CONSERVATION COMMISSION ~VQV I ~:r i~Q7 REPORT OF SUNDRY WELL OPERATIONS „t,~~~, ~,,, Q..~._ n~..._ ;, 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ er ' '' ' ` Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Q H~~~- Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory 200-1490 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number. , Anchorage, AK 99519-6612 50-029-22976-00-00 7. KB Elevation (ft): 9. Well Name and Number: 66.05 KB MPJ-24 8. Property Designation: 10. Field/Pool(s): ADLO-025515 Milne point field/Schrader Bluff 11. Present Well Condition Summary: Total Depth measured 11975 ~ feet Plugs (measured) None true vertical 3858.19 ~ feet Junk (measured) None Effective Depth measured 11975 feet true vertical 3858 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" Surface - 108' Surface - 108' 1530 520 Production 8635' 7" 26# L-80 Surface - 8664' Surface - 3920' 7240 5410 Liner 3421' 4-1/2" 12.6# L80 8554' - 11975' 3913' - 3858' 8430 7500 ~~~~® N~V ~ ~ ~~~7 Perforation depth: Measured depth: SL 8656' - 11954' _ _ _ _ True Vertical depth: 3920' - 3859' _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 8164' 0 0 - Packers and SSSV (type and measured depth) NO PACKERS 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: ~r Intervals treated (measured): ~ ~~,, ~(1~ ~ ~ 2001 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 367 23 280 339 Subsequent to operation: 366 23 314 328 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service !~"~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' Gas WAG ~"" GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature - Phone 564-4944 Date 11/9/2007 Form 10-404 Revised 0'4/2006 ~ ~V '~L~`y Submit Original Only • • MPJ-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY 10/30/2007~Ti1-200/0. (Acid treatment). IA fluid near surface (-18'). Pump 20 bbls crude down tbg for infectivity. Pump 10 bbls 12% DAD acid down tbg followed by 3 bbls .:60/40 meth & 35 bbls crude. Let acid set on ESP for 20 minutes. Displace acid thru ESP & back into formation w/ 55 bbls crude down tbg. RD off tbg. RU to IA. „Spear into IA w/ 5 bbls crude followed by 178 bbls produced water. Cap w/ 5 bbls crude. FWHP=O/0. FLUIDS PUMPED BBLS 125 CRUDE 10 Gallons of Cement 3 60/40 METH 178 PRODUCED WATER 316 TOTAL · STATE OF ALASKA _ ~l-RECEI\lED ALA~ OIL AND GAS CONSERVATION CO~SION!~ #" 0 ' REPORT OF SUNDRY WELL OPERATIONS""I\<;{{<.,. b 1 2007 & Gas Cons. Commission 1, Operations Performed: .Ôfnchoran'E~ o Abandon 181 Repair Well ' o Plug Perforations o Stimulate o Re-Enter Suspe~ded Well o Alter Casing 181 Pull Tubing' o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Replace ESP, Desander & Screens 2, Operator Name: 4, Well Class Before Work: 5, Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 200-149 /' 3. Address: o Service o Stratigraphic 6. API Number: P,O, Box 196612, Anchorage, Alaska 99519-6612 50-029-22976-00-00 /' 7. KB Elevation (ft): 66.05 , 9. Well Name and Number: MPJ-24 ' 8, Property Designation: 10, Field 1 Pool(s): ADL 025515 Milne Point Unit 1 Schrader Bluff - 11. Present well condition summary Total depth: measured 11975 ' feet true vertical 3858 ' feet Plugs (measured) N/A Effective depth: measured 11975 feet Junk (measured) N/A true vertical 3858 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8635' 7" 8664' 3920' 7240 5410 Liner 3421' 4-1/2" 8554' - 11975' 3913' - 3858' 8430 7500 Perforation Depth MD (ft): SCAJ'iNED AUG.O 8 Z001 Slotted Liner 8657' - 11954' Perforation Depth TVD (ft): Slotted Liner 3920' - 3859' Tubing Size (size, grade, and measured depth): 2-7/8",6,5# with 4", 95# Excluder L-80 8164' Screens and 4-3/4" Bull Plug Packers and SSSV (type and measured depth): 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13, Recresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinÇ) Pressure Tubina Pressure Prior to well operation: 0 0 0 260 0 Subsequent to operation: 312 18 235 250 284 14, Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 N/A Printed Name Sondra Stewman Title Technical Assistant ~nat~~ ^' -<J'Ù Prepared By Name/Number: Phone 564-4750 DateLJ1-Z tel Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 f lImMS 6FL AUG 0 8 2007 Submit Original Only ORIGINAL ~~7 Tree: 3-1/8" FMC horizontal tree Wellhead: 11" x 11" 5M tbg, spooi, 11" x 38' RH Acme & 8rd EUE (top & bottom) FMC TBG HNG wi 3.5" 'H' BPV MP J-24\LI FMC Horizontal tree Model 120 profile. ~ KB elev, = 28.55' DF elev. = 66.05' GL elev. = 36.30' Cameo 2-7/8" x 1" KBMM SPM 145' Halliburton ES cementer I 2,397' I Baker 7" ML torque master pkr 600-47 Wireline entry guide 8296' Cameo 2-7/8" xi" KBMM SPM 7830' HES 2-7/8" XN nipple 2.25" ID 7973' Discharge Head GPDIS 8016' Pump 137 Stage/538P17 8016' PMSXD 1 :7 Gas Separator GRSFTX AR H6 8035' Tandem Seal Section 8040' GS83DA FER HL SSCV HA SB/S8 PFSA Motor 152 hp KMH 2325 volt, 40 amp 8054' PumpMate XTO wi fin centralizer 8067' PumpMate TVD: 3796' Shear sub & Cavins Desander 8071' Baker Excluder Screens w/ 8079' centralizers and end bull plug 27/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap. ,00592 bpf ) 7" 26 ppf, L-80, BTC production casing (drift ID = 6.151 ", cap. = 0,0383 bpf) (capacity wi tubing inside = 0,02758 bpf) KOP @ 600 ' Max wellbore Angle: 75° @ , MD Hole angle through perfs = 90 deg. RA tag at 8254' 3 Short joints 8119'-8242' Milled window from 8264'-8276' Baker HR setting sleeve I 8284' 8315' Baker HR setting sleeve Baker HMC liner hanger 8553' 8563' Halliburton landing collar Halliburton float collar Halliburton float shoe 8577' 8620' 8664' 4.5" 12,6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (8656'-11953') 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- 8,656' - 11,953' MD (3296') Mid-lateral TVD @ 3877' DATE REV. BY COMMENTS 11/09/00 MDO Initial casing completion Doyon 141 11/21/00 M. Linder Initial ESP corn letion 4-ES 5/20/05 L. Hulme ESP replacement by 4ES 9/01/05 MDO ESP Replacement by 4ES 9/10106 REH ESP Replacement by 4ES 00 7/2/07 L. Hulme ESP wi desander & screens replacement by 3S . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-~24'~ tnÞ::s 04 LI MPJ-224 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: Spud Date: 10/9/2000 End: 7/2/2007 6/20/2007 7/2/2007 01 :30 - 02:30 1.00 DEMOB P I DECOMP 02:30 - 03:30 I 1.00 DEMOB P I DECOMP 03:30 - 05:30 I 2.00 DEMOB P DECOMP 05:30 - 06:00 I 0.50 BOPSU P POST 06:00 - 00:00 18.00 DEMOB P POST 6/22/2007 00:00 - 17:00 17.00 MOB P PRE 17:00 - 22:00 5.00 MOB P PRE 22:00 - 00:00 2.00 RIGU P PRE 6/23/2007 00:00 - 01 :30 1.50 RIGU PRE 01 :30 - 03:00 1.50 RIGU PRE 03:00 - 06:00 3.00 RIGU PRE 06:00 - 09:00 3.00 RIGU PRE 09:00 - 12:00 3.00 KILL DECOMP 12:00 - 13:30 DECOMP 1.50 KILL 13:30 - 15:00 1.50 KILL DECOMP 15:00 - 15:30 0.50 KILL DECOMP 15:30 - 17:30 DECOMP 2.00 KILL 17:30 - 22:30 5.00 WHSUR DECOMP RID LRHOS. PJSM. Secure derrick lines and scope down derrick. PJSM. UD Derrick Jack up pipe shed and roll pipe shed away from rig. RlU carrier to move. Jack up carrier and move off NK-23L Spot carrier off well and prep to re-configure BOPE for MPU. BOPE modifications, Rig maintenance. Move from NK-23 to MPJ-24 Continue moving rig from Niakuk to MPU J-24. Arrive on J-Pad at 17:00 hrs. Spot camp. Layout herculite over well J-24 and set rig mats. Prep carrier to move and spot carrier over J-24. Shim carrier. Prep pipe shed and mud pits to move and shot into place. Shim and hook up power to pipe shed. Accept rig @ 22:00 hours. Continue rigging up Nabors 3S over J-24. Spot pipe shed and mud pits. Shim and power up pipe shed. Prep derrick to be raised. PJSM. Raise and scope up derrick. Secure lines. RlU flow line. P/U newly fabricated kill line and fit into place. RU Tiger Tank and hardline for killing well. RU Tree and cellar. Pull BPV wI 100 psi on Tbg. Finish RU circlines to tree. Wait on tree cap pump in sub. Unable to obtain a 4" PI sub. Nipple up integral flange on top of tree. Re-connect hardline and circ, manifold. Pressure test hardline to Tiger Tank to 2500 psL PJSM Pump 50 Bls @ 3.5 BPM down tubing, fluid returns to Tiger tank. Close choke, bullhead 75 Bbls @ 3.5 BPM, 440 psL SITP of 0 psL Tubing on vacuum. Open choke and pump another 25 Bbls. Minimal fluid returns to Tiger Tank. Pump 150 Bbls total. 12 Bbls returns, 138 Bbls lost to formation. (includes Bullhead volume) Check rig up in cellar. Return line hooked up to horizontal outlet on tubing head, (communicates with tubing). Wellhead/Tree successfully flushed and cleaned, Re-rig circulation lines on tree. NU tree cap on top of tree. Test hardline to 2500 psL Open well to 0 psi on tubing, 280 psi on annulus. Bleed IA to Tiger tank. Gas only and bled off rapidly. Begin pumping down tubing @ 3 1/2 BPM and 70 psL No Returns. Caught fluid after 15 Bbls pumped, still no returns. 35 Bbls into pumping, slight returns to Tiger tank. Pump 50 Bbls, close Choke and Bullhead 50 Bbls @ 3 1/2 BPM, 480 psL Strap tank, 4 Bbls returned out of 50 pumped. Open choke and pump additional 50 Bls down tubing wI no returns. SITP of 0 PSI. Bullhead SW down IA @ 31/2 BPM 190 PSI. Bullhead 300 Bls total. SICP of 0 PSI. Bullhead 50 Bbls down Tbg @ 3 1/2 BPM 540 PSI. SITP of 0 psL Tubing and IA on vacuum. Total fluid lost to formation - 491 Bbls. FMC Tech dry rod TWC. TWC took 1 extra turn to install in hanger. RlU and attempt to test TWC to 3500 from above. TWC would not test. Trouble shoot rig testing equipment and change out questionable valves. Attempt to test TWC from ./ Printed: 7/24/2007 5:05:12 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ~24\L\ MPJ~~'24 \L\ WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 6/23/2007 17:30 - 22:30 5.00 WHSUR 14:30 - 15:30 1.00 WHSUR C DECOMP above without success. While changing out valves, attempt to test TWC from below at 4 BPM with 130 psi. Unsuccessful test. R/U and attempt to test TWC from above. Unsuccessful test. Call Drill Site Tech to CIO TWC. DECOMP R/U DSM lubricator and pull TWC. Set redressed TWC. RID DSM. DECaMP Fill tree and attempt to test TWC from above to 3500 psi. Unsuccessful test. Re-check rig testing equipment for possible leak. Equipment good and tested to 4000 psi. DECaMP Re-check rig testing equipment for possible leak. Equipment good and tested to 4000 psi. Make one more unsuccessful attempt to test TWC. No Good. DECOMP Confer with town engineer. Decision made to set 2-7/8" WRP with e-line in TBG at 150', Make arrangements to change scope. Contact SLB e-line and Weatherford. DEcaMP Contact DSM. R/U DSM lubricator and pull TWC. RID DSM. DECaMP R/U DSM and shoot fluid levels in TBG at 2035' and in the annulus at 385'. Continue gravity feeding 20 BPH in annulus. Plan on shooting fluid levels hourly. DECOMP Wait on SWS. Clean and organize rig. 2nd fluid shot taken at 05:30 hrs in annulus @ 385'. 08:00 shoot fluid level in IA- 412' DECOMP SLB on location. Call Weatherford for a 2 7/8" WRP. PJSM. RU SLB e-line. SLB getting variance for running explosive setting tool @ depth less than 200' (SLB policy). Fluid level @ 10:30 in IA -412'. DECOMP BOPE on wellhead, lubricator and grease head rigged up on rig floor. Wait on SLB., DECOMP Model 505 E charge setting tool on location. PJSM. MU WFD plug to setting tool. MU to wellhead, pressure test lubricator to 500/3000 psi. Open well to 0 psi. RIH wI WFD 2 7/8" WRP on SLB e-line wI Baker setting tool. Log up from 200'. Tie into GLM @ 176' ELM. Set WRP @ 145' (middle of 1st full joint above GLM). POOH. DECOMP Break lubricator off of tree. Confirm setting of WRP. Close master valve and test Tubing and WRP to 500 I 3500 psi for 5 minutes each, and chart. Bleed and drain tree. DECOMP RD SLB e-line lubricator and grease head from Rig floor. Break off wireline BOPE from tree and remove from cellar. I Continue to put 20 Bbl SW in Annulus every 1 hour. DECOMP ND tree. Pull sleeve from top of hanger. Screw 31/2" RH Acme XO into top of hanger wI 9-1/2 turns. Inspect TWC profile and threads. No visible sign of damage. Screw TWC into profile wI no problems. Will send hanger in to FMC for inspection and testing after pulling to floor. DECOMP Shoot fluid level on IA. Fluid @ 400'. NU 13-5/8" x 11" double flange spool piece to tubing head. NU BOPE, CIO unibolt on BOPE, NU kill line and choke line, function test, install riser and flow line, center BOP stack. Shoot fluid level at 24:00 @ 440'. DECOMP R/U BOPE testing equipment and purge air. Pressure up on BOPE body and check for leaks. Valves connecting to TBG head leaking slightly. Call for grease crew to service wellhead valves. Service valves. 22:30 - 23: 15 0.75 WHSUR 23:15 - 00:00 0.75 WHSUR 6/24/2007 00:00 - 01 :30 1.50 WHSUR P 01 :30 - 03:00 1.50 DHB C 03:00 - 04:00 1.00 DHB C 04:00 - 04:30 0.50 WHSUR C 04:30 - 08:30 4.00 WHSUR C 08:30 - 11 :30 3.00 WHSUR Ie I I 11:30 - 12:30 1.00 WHSUR C 12:30 - 14:00 1.50 WHSUR C 14:00 - 14:30 0.50 WHSUR C 15:30 - 17:30 2.00 WHSUR C 17:30 - 00:00 6.50 WHSUR C 6/25/2007 00:00 - 02:00 2.00 WHSUR P Printed: 7/24/2007 5:05:12 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ~24 .LI MPJ-2f4\ I WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 Test BOPE to 250 psi low pressure and 3,500 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by Bob Noble. Test was witnessed by Nabors toolpusher and BPX WSL. Shoot flluid levels at 03:00 - 330', 06:00 - 280'. 06:00 - 09:00 3.00 WHSUR N DECOMP Continue testing BOPE. Troubleshooting annular preventer. 09:00 - 16:00 7.00 WHSUR N DECOMP Break down annular preventer. Inspect and replace seals. Shoot FL in IA @ 11 :30 - 400'. 16:00 - 17:00 1.00 WHSUR N DECOMP MU test joint and position in annular preventer. Attempt to pressure test. Leaking by element. 17:00 - 21 :45 4.75 WHSUR N DECOMP Break off Hydril cap. Remove and replace hydril element. Called AOGCC and informed them of changes made to kill linelmud manifold. Also discussed current BOPE testing problems (Hydril annular preventer). shoot Fluid level @ 17:30 - 400'. 121 :45 - 22:30 0.75 WHSUR P DECOMP Continue testing BOPE, Test Annular and TIW to 250 psi low I pressure and 3,500 psi high pressure. Perform Accumlator draw down test. RD BOP testing equipment. 22:30 - 00:00 1.50 WHSUR P DECOMP Drain BOPE, BID lines. RD bell nipple and flow line. 6/26/2007 00:00 - 01 :30 I 1.50 WHSUR P DECOMP PU and install shooting flange on hydril. 01 :30 - 03:30 2.00 WHSUR P DECOMP PU SWS lubricator extension, BOPE, lubricator and packoff. RU same. 03:30 - 04:30 1.00 DHB P DECOMP PJSM, MU WRP retrieving tool and enter TBG. Fill lubricator wI seawater and pressure test SWS lubricator to 500 psi low I 3000 psi high. 04:30 - 05:30 1.00 DHB P DECOMP RIH to 149' WLM. Latch to WRP and jar attempt to shear loose. POOH wlo WRP. 05:30 - 06:00 0.50 DHB P DECOMP Examine retreiving tool. M/U and RIH to retrieve WRP. 06:00 - 09:00 3.00 DHB P DECOMP 1st run unable to latch WRP. Re-dress pulling tool RIH. 2nd run unsuccessful as well. Dogs on pulling tool bent in which prevented being able to latch 1-1/8" fishing neck. RIH wI 2.25" LIB and get impression of fishing neck -looked good. RIH wI WFD pulling tool. Hand spang and equalize plug, latch and POOH 09:00 - 09:30 0.50 WHSUR P DECOMP Close blind rams and bullhead 70 bbs seawater down tubing @ 3-1/2 BPM wI 500 psi. Final injection pressure of 630 psi. Shut down wI tubing and IA on vacuum. 09:30 - 11 :00 1.50 PULL P DECOMP RD SLB wireline equipment. ND shooting flange, NU pitcher nipple and flow line. RU floor to pull completion. 11 :00 - 12:30 1.50 PULL P DECOMP Hang ESP sheave in derrick. Continue to filllA wI seawater @ 20 bph. 12:30 - 14:00 1.50 PULL P DECOMP Pull tubing hanger to floor. LD hanger and landing joint. 14:00 - 23:00 9.00 PULL P DECOMP POOH and stand back 2-7/8" tubing string (251 joints). Check ESP cable conductivity. Double-displace tubing wI seawater while POOH. Slight scale on tubing starting on joint # 103. LD single w/GLM and 2 pup joints above pump. Recovered 133 of 133 LaSalle clamps, 6 of 6 Protectalizers, 3 of 3 Flat Guards. 23:00 - 00:00 1.00 PULL P DECOMP Cut cable and check conductivity to motor (no good). LD pump sections & motor. Continue to fill hole wI seawater @ 20 bph. 6/27/2007 00:00 - 02:00 2.00 PULL P DECOMP LD Centrilift ESP assembly. 02:00 - 03:00 1,00 PULL P DECOMP Clear rig floor. 03:00 - 03:30 0.50 CLEAN P DECOMP PU test joint and set wear ring wI 9" ID. RILDS (4). 03:30 - 04:00 0.50 CLEAN P DECOMP LD cable spooler elephant trunk. Printed: 7/24/2007 5:05:12 PM . . MPJ~24 L\ MPJ-~24 \ L/ WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/27/2007 04:00 - 07:00 3.00 CLEAN P DECOMP MU BHA #1: 2-7/8" muleshoe, 7" casing scraper, 2 boot baskets, oil jars and 4 DCs on 2-7/8" tubing. 07:00 - 11 :30 4.50 CLEAN P DECOMP TIH with BHA #1 on 2 7/8" Tubing from the Derrick. Fill the hole with 20 bbls per hour while TIH. 11 :30 - 13:00 1.50 CLEAN N WAIT DECOMP In with 125 stands of 2 7/8" Tubing (250 Jts) from the Derrick. Wait on 15 Jts of 2 7/8" Tubing to arrive on location to continue TIH to tag fill. Pipe arrives on location at 12:30 hrs. Load and strap in the Pipe Shed. 13:00 - 14:30 1.50 CLEAN P DECOMP Establish parameters: UW = 45K , DW = 25K Continue TIH with single Joints of 2 7/8" Tubing from the Pipe Shed. Tag 18' in on Jt #258. Re-confirm tag depth 5 times to ensure, tag depth = 8,279' 3SMD. Did not encounter any obstructions to TD. 14:30 - 20:00 5.50 CLEAN P DECOMP TOH with BHA #1 standing back 27/8" Tubing in the Derrick (129 stands). Double displace with seawater while TOH. Boot baskets empty. No indication of junk in hole. 20:00 - 20:30 0.50 CLEAN P DECOMP Change out handling equipment and set back 2 stands 4-3/4" DCs. 20:30 - 22:00 1.50 CLEAN P DECOMP LD BHA #1. Clear rig floor & unload shed. 22:00 - 23:00 1.00 EVAL P DECOMP PU HES RBP on 2 stands 4-3/4" DCs. 23:00 - 00:00 1.00 EVAL P DECOMP RIH wI HES RBP. Test-set & release RBP wI 2 stands in hole to insure RBP still attached to string - OK. Increase hole fill rate to 40 bph while RIH wI RBP. 6/28/2007 00:00 - 05:30 5.50 EV AL P DECOMP Continue RIH wI HES RBP. Shoot fluid level @ 400-600' at 0300 hrs. Continue filling hole wI seawater @ 40 bph. Found bad pin & collar threads in stand 126 (out of 129). Replace 2 jts tubing. Continue RIH. 05:30 - 09:00 3.50 EVAL P DECOMP Set 7" RBP with center of element at 8,246'. Release from RBP and fill hole wi seawater prior to pressure testing. Pump seawater down the backside with the Charge Pump with no hole fill noted. Pumped away 100 bbls. Shut down and no fluid level evident on surface. Discuss with Anchorage Engineering. Re-Iatch the RBP and release it. POOH 3 stands and re-set it @ 8,060' center of element. Attempt to fill the hole again - no joy. Pumped a total of 75 bbls with no fluid to surface. Discuss with Anchorage Engineering and decision made to pull the RBP out of the hole and run another 7" RBP in to the original set depth of approximately 8,250' +1-. 09:00 - 15:00 6.00 EV AL C DECOMP POOH with 7" RBP standing back 2 7/8" Tubing and 4 3/4" Drill Collars in the Derrick, Double displacing the well with seawater while POOH. Discuss plan forward again with Anchorage Engineering and prepare for either another 7" RBP or a 7" Champ IV Packer run. 15:00 - 17:00 2.00 EV AL C DECOMP On surface with 7" RBP. Inspect the RBP with the Halliburton rep and the RBP looks like new. No evidence of any malfunction or damage noted. Discuss with Anchorage Engineering and the plan forward is to RIH with a 7" Champ IV Packer and set it slightly deeper than the 7" RBP and attempt to achieve a pressure test on the Casing. Break out and lay down the 7" RBP, PU and MU the 7" Champ IV Packer. 17:00 - 22:30 5.50 EV AL C DECOMP TIH with 7" Halliburton Champ IV Packer on 2 7/8" Tubing from the Derrick. LD top single on std #14 & bottom single on std #15 due to galled threads. Replace with 31.37' and 31.75' Printed: 7/24/2007 5:05:12 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-~24\ LI MPJ-~24 \ L I WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 joints. Set 7" HES Champ IV Packer with center packer element at 8250'. Fill hole with 24 bbls (approx. 900') of seawater with rig pump. 23:30 - 00:00 0,50 EVAL C DECOMP Close annular BOP. Pressure-test 7" casing to 1,500 psi for 30 charted minutes - good test. 6/29/2007 00:00 - 08:30 8,50 EVAL C DECOMP Release HES Champ IV Packer. POOH with the Packer. Stand back 2 7/8" Tubing string in Derrick. LD bottom single std #84 & top single std #85 due to galled threads. Replace with new joints from pipe shed. Break down and lay down HES Champ IV Packer. 08:30 - 09:30 1.00 EVAL C DECOMP On surface with 7" HES Champ IV Packer. Break out and lay down. PU and MU 7" HES RBP, 09:30 - 15:00 5.50 EVAL C DECOMP TIH with 7" RBP on 2 7/8" Tubing from the Derrick. 15:00 - 16:00 1.00 EVAL C DECOMP Set 7" RBP with Halliburton rep at a depth of 8,250' center of element. Fill up the backside using the Rig Pump at 3 bpm with 18 bbls of seawater (-600'). Shut down the Pump and allow the fluid column to air out. Close the Annular Preventor and RU test equipment. 16:00 - 16:30 0,50 EVAL C DECOMP Pressure test the 7" Casing against the 7" RBP at 8,250' to surface to 1,000 psi for 30 charted minutes - OK. 16:30 - 23:00 6.50 EVAL P DECOMP Release the Setting Tool from the RBP. TOH with Halliburton RBP Setting Tool Assembly standing back 2 7/8" Tubing in the Derrick. Maintaining continuous hole fill while TOH. 23:00 - 00:00 1.00 EVAL P DECOMP Set back DC's. Break out and lay down RBP setting tool. Clean & clear rig floor. 6/30/2007 00:00 - 02:00 2.00 EVAL P DECOMP Drain BOP stack. ND flow nipple & flange. Install & NU shooting flange. 02:00 - 04:30 2.50 EVAL P DECOMP RU SWS wi lubricator extension, pump-in sub and packoff. Test shooting nipple to 1000 psi for 5 minutes - OK. 04:30 - 12:00 7.50 EVAL P DECOMP RIH wI USIT logging tool. Log in cement evaluationlcorrosion mode from 8,200' to surface at 50 feet per minute. On surface at 10:30 hrs. Field evaluate the log with E-line Engineer and WSL. Discuss with Anchorage Engineering. Will re-Iog from 500' to surface with 500 psi on the well to compare results. RIH to 500', engauge Packoff around the wire and pressure up the wellbore to 500 psi. Run the USIT tool from 500' to surface. 12:00 - 13:00 1.00 EVAL P DECOMP PJSM. RD Schlumberger E-line. While RD E-line, inadvertantly closed the Blind Rams on the Toolstring pinching and damaging a Roller. Will pressure test the Blind Rams to ensure no damage to the Rams themselves. 13:00 - 16:30 3.50 EV AL P DECOMP ND Shooting Flange. NU Flow Riser. Pull Wear Ring. Set Test Plug. Pressure test Blind Rams to 250 psi low and 3,500 psi high for five minutes - OK. Pull Test Plug. Set Wear Ring. 16:30 - 17:00 0.50 EVAL P DECOMP PU and MU 7" RBP Retrieving Tool Assembly with Halliburton rep. 17:00 - 18:00 1.00 EVAL P DECOMP TIH with Retrieving Tool Assembly on 2 7/8" Tubing from the Derrick. 18:00 - 18:30 0.50 EVAL P DECOMP RU and circulate well bore at 500'. 18:30 - 23:30 5,00 EVAL P DECOMP Finish TIH with RBP retrieving tool to top of RBP. 23:30 - 00:00 0.50 EVAL P DECOMP RU and circulate 60 bbls seawater at 4 bpm I 710 psi to ensure I clean fluid above RBP prior to releasing plug. Printed: 7/24/2007 5:05:12 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ~24\L\ MPJ-~24\ 1.-\ WORKOVER NABORS ALASKA DRILLING I NABORS 3$ Start: Rig Release: Rig Number: 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 7/1/2007 00:00 - 00:30 0.50 EVAL P Latch and releaseRBP, PUW I SOW = 40K I 25K Ibs. RBP released without a problem, 00:30 - 08:00 7.50 EVAL P DECaMP LD 10 joints 2-7/8" tubing (7 extra + 3 for completion). POOH with 124 stands to Derrick. Double displace tubing while TOH. 08:00 - 09:00 1.00 EVAL P DECOMP On surface with 7" RBP, Break down and lay down with Halliburton rep. 09:00 - 10:00 1.001 WHSUR P DECaMP Pull Wear Ring. Prepare to run completion. 10:00 - 11 :00 1.00 I RUNCO P RUNCMP Pre-job safety meeting with WSL, Toolpusher, Nabors crew, Centrilift reps and Baker Completions rep. Do final check on all completion jewelry prior to picking up. 11 :00 - 15:00 4.00 RUNCOMP RUNCMP PU and MU completion jewelry with Baker Completions rep. I Torque up the 4" Imp Buttress Tubing Screens connection to I I the mark per Baker Completions rep. PU, MU and service new ESP components with Centrilift reps. Pump 20 bbls of seawater per hour while MU completion jewelry. Pull ESP Cable over the Sheave and attach Motor Lead Extension to the Motor, Secured ESP Cable with 3 Flat Guards and 6 Protectolizers. Check the ESP Cable conductivity with the I Centrilift reps - OK. 15:00 - 21 :00 6.00 I RUNCO P RUNCMP RIH with new ESP Completion on 27/8", 6.5#/ft, L-80, EUE 8rd i Tubing. Using Best-a-Life Pipe Dope on all connections and MU to 2,300 ft-Ibs of torque. Attached LaSalle Clamps to first 9 Joints of 2 7/8" Tubing, every other Joint of Tubing to surface and on the 10' Pup Joints on either side of the GLM Assemblies. Stop every 2,000' to check the conductivity of the ESP Cable. At every stop, fill the Tubing with seawater and flush the pump with 10 bbls of seawater pumped at 1 bpm. 40 Jts in the well at 17:00 hrs. 21 :00 - 21 :30 0.50 RUNCO P I RUNCMP Replace top coupling on stand #63. Replace bottom joint on I stand #64 due to damaged pin threads. 21 :30 - 23:30 2.00 RUNCO P RUNCMP RIH 90 stands. Pump 10 bbls seawater down tubing to flush pump @ 1 bpm / 1,450 psi. 23:30 - 00:00 0.50 RUNCO P RUNCMP Splice electric cable at approximately 6,500'. 7/2/2007 00:00 - 03:30 3.50 RUNCO P RUNCMP Complete reel-to-reel electric cable splice. Pump 20 bph seawater in hole during splice. 03:30 - 06:30 3.00 RUNCO P RUNCMP Continue RIH with 251 jts 2-7/8" ESP completion to 8,159'. 06:30 - 08:00 1.50 RUNCO P RUNCMP PU and MU 2 7/8" Tubing Hanger with FMC rep. Final PUW I SOW = 48K Ibs I 26K Ibs. Ran a total of 124 LaSalle Clamps in the completion. 08:00 - 10:00 2.00 RUNCO P RUNCMP Make penetrator splice with Centrilift reps. Clear and clean floor. Service the Rig. Make final checks on ESP cable with Centrilift reps. Phase to phase = 3.0 ohms, Phase to ground = 2.4 Giga-ohms , Pressure at the intake = 1,547 psi, Temperature at the motor and intake = 62 degrees. 10:00 - 11 :00 1.00 I RUNCMP Land Tubing Hanger with FMC rep utilizing alignment pin. RILDS. 11 :00 - 12:00 1.00 RUNCMP Set TWC with FMC rep. Test from above to 1,000 psi for 10 mins - charted. Attempt to test from below but no injection pressure noted. 12:00 - 14:30 2.50 BOPSU P RUNCMP PJSM, ND BOPE and lay in Cradle. 14:30 - 16:30 2.00 WHSUR P RUNCMP NU Adapter Flange and Tree, 16:30 - 18:00 1.50 WHSUR I P RUNCMP Pressure test the Adapter to 5,000 psi for 30 mins with FMC rep - OK. Pressure test the Tree to 5,000 psi for 5 mins Printed: 7/24/2007 5:05: 12 PM .. . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ\24~\ MPJ-~24 L\ WORKO R NABORS ALASKA DRILLING I NABORS 3S Start: 6/20/2007 Rig Release: 7/2/2007 Rig Number: Spud Date: 10/9/2000 End: 7/2/2007 charted - OK. Held prejob safety meeting. Service rig. Pull TWC wI lubricator. Set BPV. Make final ESP check. Secure tree and cellar. Release rig @ 20:00 hrs. Printed: 7/24/2007 5:05:12 PM é)CD-/~9 07/27/07 Scblullbepger RE(~ErVE[J NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth JUL 3 0 zom !\ '\ '15)\)1 þ.. \} \j \I ), Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission . D Anchorage S~~"t;. Field: Prudhoe Bay Endicott Well Job# Log Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 US IT 07/20/07 1 02-30B 11813058 US IT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: dlo kt:.Gl::IVl::U . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ION OCT 0 4 2006 REPORT OF SUNDRY WELL OPERA TION~aska Oil & Gas Cons. Commission 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: ~ Development 0 Exploratory 200-149 o Stratigraphic 0 Service 6. API Number: 50-029-22976-00-00 o Re-Enter Suspended Well ~ Other Change Out ESP ~ Repair Well ~ Pull Tubing o Operation Shutdown 66.05 9. Well Name and Number: MPJ-24 8. Property Designation: 10. Field 1 Pool(s): ADL 025515 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 11975 feet true vertical 3858 feet Plugs (measured) N/A Effective depth: measured 11975 feet Junk (measured) N/A true vertical 3858 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8635' 7" 8664' 3920' 7240 5410 Liner 3421' 4-1/2" 8554' - 11975' 3913' - 3858' 8430 7500 Perforation Depth MD (ft): Slotted Liner 8657' - 11954' Perforation Depth TVD (ft): Slotted Liner 3920' - 3859' (C'(,'.0.r"t",.r::::r, (ÇV"H.[~~l1 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ?-7/R" n fi# Baker 7" ML torque master packer I-Rn 8296' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure o 0 350 173 290 200 15. Well Class after proposed work: o Exploratory ~ Development 0 Service 16. Well Status after proposed work: ~ Well Schematic Diagram '3 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge; J..... L Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 SfIJ ¡f)ftJ5{ 0'0 Printed ame Sondra Stewman Title Technical Assistant ~. . nature Form 10-404 Revised 04/2006 13. Oil-Bbl Prior to well operation: 0 Subsequent to operation: 445 14. Attachments: 0 Copies of Logs and Surveys run ~ Daily Report of Well Operations Tubin Pressure o 280 R8DMS 8Ft 0 C1 £} 5 2006 Prepared By Name/Number: DatetC·"C~-f <y.p Sondra Stewman, 564-4750 Submit Original Only Phone 564-4750 Tree: 3-1/B" FMC horizontal tr Wellhead: 11" x 11" 5M tbg. spool, 11" x 3.5" RH Acme & 8rd EUE (top & bottom FMC TBG HNG wI 3.5" 'H' BPV profile. . FMC ~r~n~;~~oiI1~1 KB elev. = 28.55' DF elev. = 66.05' GL elev. = 36.30' ~ Camco 2-7/8" x 1" side pocket KBMM GLM 173' Halliburton ES cementer I 2,397' I 2718" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap. .00592 bpf ) 7" 26 ppf, L-80, BTC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) (capacity wI tubing inside = 0.02758 bpf) Camco 2-7/8" x 1" sidepocket KBMM GLM 7,860' HES 2-718" XN nipple 2.25" ID 8,002' KOP @ 600 ' Max well bore Angle: 75° @ , MD Hole angle through perfs = 90 deg. GPDIS Pressure Head 8,021' Tandem Pumps: 86S/538P11 & 16 GCNPSH GPMTAR1:1 8,022' 8,032' 3 Short joints B119' -8242' Gas Separator GRSFTX AR H6 Tandem Seal Section I GSB3DBFERHLSSCVH6SWSBPRSNSBPFSA 133hp KMH 2205 volt, 37 amp Motor Centrilift Pumpmate wI fin centralizer I 8,041' RA tag at 8254' 8,055' 8,070' Milled window from B264'-8276' Baker HR setting sleeve I 8284' I Baker T' ML torque master pkr 600-47 Wireline entry guide 8296' B315' 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (8656'-11953') Baker HR setting sleeve Baker HMC liner hanger 8553' B563' Halliburton landing collar Halliburton float collar Halliburton float shoe 8577' 8620' 8664' 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- 8,656' - 11,953' MD (3296') Mid-lateral TVD @ 3877' DATE 11/09/00 11/21/00 5/20105 9/01/05 9/10/06 REV. BY MDO M. Linder L. Hulme MOO REH COMMENTS Initial casing completion Doyon 141 Initial ESP completion 4-ES ESP replacement by 4ES ESP Replacement by 4-es ESP Replacement by 4ES \- ZoO· MILNE POINT UNIT WELL J.a24 ~ 1..1 API NO: 50-029-22976-00 -00 50 -zq-z:a_ ...,c,l.O BP EXPLORATION (AK) · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 91512006 91612006 MPJ-224 MPJ-224 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From...To Hlôurs Task Code NPT Phase 16:00 - 18:00 2.00 RIGD P PRE 18:00 - 19:30 1.50 MOB P PRE 19:30 - 20:30 1.00 RIGU P PRE 20:30 - 22:00 1.50 RIGU P PRE 22:00 - 23:00 1.00 KILL P DECOMP 23:00 - 00:00 1.00 WHSUR P DECOMP 00:00 - 00:30 0.50 KILL P DECOMP 00:30 - 03:00 2.50 KILL P DECOMP 03:00 - 06:00 3.00 KILL P DECOMP 06:00 - 09:00 3.00 KILL P DECOMP 09:00 - 11 :00 2.00 KILL P DECOMP 11 :00 - 12:00 1.00 WHSUR P DECOMP 12:00 - 12:30 0.50 WHSUR P DECOMP 12:30 - 14:00 1.50 WHSUR P DECOMP 14:00 - 16:00 2.00 BOPSU P DECOMP 16:00 - 19:30 3.50 BOPSU P DECOMP 19:30 - 20:00 0.50 WHSUR P DECOMP 20:00 - 20:30 0.50 PULL P DECOMP 20:30 - 00:00 3.50 PULL P DECOMP 9m2006 00:00 - 01:30 1.50 PULL P DECOMP 01:30 - 03:00 1.50 PULL P DECOMP Start: 9/5/2006 Rig Release: 9/9/2006 Rig Number: Spud Date: 10/9/2000 End: 9/9/2006 Description of OperationS Scope down and lower derrick Move rig from J-06 to J-24 Prep location wI pit liner and spot rig. Move and spot camp Raise and scope up derrick. Accepted Rig at 22:00 hrs. RU circulating lines to tree and to Tiger Tank for killing operations. Take on 2% KCI brine. PU lubricator and pull BPV. RD Pressure test lines from 1000 to 3500 psi. Record shut-in pressures Annulus = 260 psi, TBG = 260 psi. Bleed off pressure on TBG to 20 psi, Annulus to 40 psi. Pump 2% KCI brine @ 4 BPM wI 490 psi TBG pressure and 0 psi on Annulus. Caught up with the fluid in the TBG @ 180 strokes and 500 psi. Continue circulating @ 5 BPM wI 860 psi TBG pressure and 0 psi on Annulus. Well bore fluids retums to surface in the annulas after pumping 116 bbls. Pumped a total of 580 bbls without brine returns. Shut-in well and monitored pressures. TBG = 0 psi, Annulus = 130 psi. Wait on additional 2% KCL Fluid to finish cleanning up and killing Well. Continue wait on additional 2% KCL. Service and maintain Rig. Check PVT Alarms. Inspect Derrick. Bullhead KiIIlA at 6.0 bpm/240 psi. Bullhead tubing at 6.0 bpm/1500 psi. Both sides on a "screaming" vacuum. Set and test TWC (top) 1200 psi x 10 minutes. Good. Unable to test from bottom-side. Well on vacuum...un-able to catch fluid. Rig-down test equipment. Blow down lines. Nipple-down Tree. Inspect lift threads (3" LH Acme). Good. Nipple-up Dual Stub Adaptor, Test Spool, and BOP Stack. PJSM. Test BOPE per BP/AOGCC requirements at 25013500 psi. The State's right to witness test was waived by J. Chrisp. Good test. Witnessed by Nabors Toolpusher and BP WSL. Test #1- Choke Valves #1, 2, and 12 Test #2- Choke Valves #3 and 4 Test #3- Choke Valves #5, 6, and 7 Test #4- Choke Valves #8, 9, and 10 Test #5- Choke Valve #11 Test #6- Manual Kill and Choke Valve Test #7- HCR Kill and Choke Test #8- Pipe Rams and TIW Test #9- Hydrill Accumulater Test- 3000 psi Starting Pressure, 1700 psi After Actuation, First 200 psi in 41 seconds, Full Pressure in 2 Minutes 56 Seconds. 4 Nitrogen Bottles at 1625 psi. RD Test Equipment PU Lubricator and pull TWC. RU to pull 2 7/S" TBG. MU Landing Joint. Sting into HGR and pull to rig floor 57K to break loose, 52K to pull to floor. POOH w/2 7/S" ESP completion TBG. Continue POOH w/2 7/8" Completion TBG. POOH wI ESP and UD. Found broken shaft on upper pump. No sand was found in ESP. Printed: 9/1112006 11:50:24AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-224 MPJ-224 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 9/5/2006 9/9/2006 Spud Date: 10/9/2000 End: 9/9/2006 Date From - To HoUrS mask Code. NPT Phase Døsçriptionof Operations 9/7/2006 03:00 - 04:30 1.50 PULL P DECOMP Clean floor, RID Centrilift, set Wear Ring. 04:30 - 08:30 4.00 CLEAN P DECOMP MlU BHA #1 and trip in with 2 7/8" Tubing. Tagged (solid) at 8,265' 4es kb (OB Window). 08:30 - 09:30 1.00 CLEAN P DECOMP Flush TBG at 70 SPMI 700 psi. Drop ball and pump on seat. Work RCJB several times. Tagged remains at the same place. 09:30 - 13:00 3.50 CLEAN P DECOMP Trip out with 27/8" Tubing and BHA. Double displace each 5 stands pulled. 13:00 - 13:30 0.50 CLEAN P DECOMP Lay down RCJB and Boot Basket. Recovered 1 piece of metal, 2 pieces of scale or cement, and 3 stones. Boot Basket was empty...no sand. 13:30 - 14:30 1.00 CLEAN P DECOMP Discuss plan forward with Anchorage Eng. 14:30 - 15:00 0.50 CLEAN P DECOMP Make-up Boot Basket and RCJB. Re-run same BHA. 15:00 - 18:30 3.50 CLEAN P DECOMP Trip in with RCJB BHA and 2 7/8" Tubing. Tag @ 8265'. 18:30 - 19:30 1.00 CLEAN P DECOMP Flush TBG volume at 6 BPMl1200 psi. Drop ball, and pump to seat at 4.5 BPM/900 psi. Work RCJB several times to 8267'. 19:30 - 22:30 3.00 CLEAN P DECOMP POOH wI 27/8" TBG and BHA. Double displace each 5 stands pulled. 22:30 - 23:00 0.50 CLEAN P DECOMP Break RCJB and recover 3 pieces of metal banding, 1 fist size chunk of CMT, and a number of smaller stones and CMT. No sand. 23:00 - 00:00 1.00 CLEAN P DECOMP RU RCJB on same BHA and RIH for clean out #3. 9/812006 00:00 - 03:00 3.00 CLEAN P DECOMP Continue RIH wI RCJB run #3. Tag @ 8267'. 03:00 - 04:00 1.00 CLEAN P DECOMP Flush TBG volume at 4.25 bpm/720 psi. Drop ball and pump to seat at 4.0 bpmSPM/700 psi. Work RCJB several times at 97 SPMl1680 psi. No extra footage gained. 04:00 - 06:00 2.00 CLEAN P DECOMP POOH w/2 7/8" workstring TBG. Double displacing each 5 stands pulled. 06:00 - 07:00 1.00 CLEAN P DECOMP Inspect Derrick. Check PVT Alarms. Finish Tripping-out with 2 7/8" tubing and RCJB. 07:00 - 08:00 1.00 CLEAN P DECOMP Lay down and empty RCJB. Recovered several stones. Lay down remaining BHA. Pull Wear Bushing. 08:00 - 10:30 2.50 RUNCMP Make-up and service new ESP Assembly. 10:30 - 19:00 8.50 RUNCMP Trip in with new ESP Assembly and 2 7/8" Cable. Test ESP each 2000' and pump @ 1 BPMl1700 psi. 19:00 - 22:00 3.00 RUNCO RUNCMP Make reel to reel splice at 7584'177 stands in the hole, 22:00 - 22:30 0.50 RUNCO RUNCMP Continue RIH wI ESP completion. 22:30 - 23:00 0.50 RUNCO RUNCMP PUlMU HGR and install Penetrator. 23:00 - 00:00 1.00 RUNCO RUNCMP Attach field connection. Plug into penetrator and test. 9/9/2006 00:00 - 00:30 0.50 RUNCO RUNCMP Continue attaching field connection. Plug into penetrator and test. 00:30 - 01 :30 1.00 RUNCMP Land ESP completion and RILDS. SIO wt = 30K, P/U wt = 52K 01 :30 - 02:30 RUNCMP Set TWC and test from top 1000 psi for 10 minutes. 02:30 - 04:00 RUNCMP NO BOPE 04:00 - 06:00 RUNCMP NU Tree, Test HGR to 5000 psi for 15 minutes. RD Rig Equipment and secure Well. Take final ESP readings of: 3.6 Balance OHMS reading, BHP= 1392 psi, Motor Temp= 68.5 deg F, Intake Temp= 73.1 deg F, and Meg Test= 1.32 Gig. Released Rig at 06:00 hrs. Printed: 9/1112006 11 :50:24 AM ALASKA JL AND ~~~6g~s~~~:~ON CO,y,11SSION R,;re!tVED REPORT OF SUNDRY WELL OPERATION::» I ö 2005' Alaska Oi, & Gas Conl!Þ I'tommo 0 IIJ. " 1$81018 c~HiAqoog8SP 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 66.05 8. Property Designation: ADL 025515 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 11975 3858 11975 3858 Casing Structural Conductor Surface Intermediate Production Liner Length 108' 8635' 3421' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-149 6. API Number: 50-029-22976-00-00 99519-6612 9. Well Name and Number: MPJ-24 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 108' 108' 1530 520 7" 8664' 3920' 7240 5410 4-1/2" 8554' - 11975' 3913' - 3858' 8430 7500 Slotted Liner 8657' - 11954' Slotted Liner 3920' - 3859' $ÇANNED NO" 0 B 2005 Tubing Size (size, grade, and measured depth): 2-7/8",6.5# Packers and SSSV (type and measured depth): Baker 7" ML torque master packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): L-80 8080' 8296' Treatment description including volumes used and final pressure: RBDMS BFL 0 CT :~ J 2005 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman s~~. Form 10-404 Revised 04/2004 Title Technical Assistant Phpn~ (~§4i4clJlf\ L Datec9tr-Öl-Ó~~~~:~t:~N~:~~~~~~~750 \.' '\ ~ u ! i \\ . \ Submit Original Only Tree: 3-1~8" ~MC ~orizontal tl ) M P J -24\ Ll Wellhead. 11 x 115M tbg. spool, FMC Horizontal tree Model 120 11" x 3.5" RH Acme & 8rd EUE (top & bottom) j FMC TBG HNG wi 3.5" 'H' BPV profile. I ..L 110' .. 8296' :~ 8315' 8553' 1- 8563' I~ 8577' " 8620' 8664' Halliburton ES cementer I 2,397' I 0 27/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap. .00592 bpf ) 7" 26 ppf, L-80, BTC production casing (drift 10 = 6.151", cap. = 0.0383 bpf) (capacity wI tubing inside = 0.02758 bpf) KOP @ 600 ' Max wellbore Angle: 75° @ , MD Hole angle through perfs = 90 deg. RA tag at 8254' 3 Short joints 8119'-8242' Milled window from 8264'-8276' Baker HR setting sleeve I 8284' I Baker 7" ML torque master pkr 600-47 Wireline entry guide Baker HR setting sleeve Baker HMC liner hanger Halliburton landing collar Halliburton float collar Halliburton float shoe x 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- 8,656' - 11,953' MD (3296') ) KB elev. = 28.55' OF elev. = 66.05' GL elev. = 36.30' .~ Cameo 2-7/8" x 1" sidepocket KBMM GLM 173' Cameo 2-7/8" x 1" sidepock(·;t KBMM GLM 7,860' I HES 2-7/8" XN nipple 2.205" 10 8,003' MS-1 Pressure Head 8,021' Tandem Pumps 100GC1150 & 19GC8200 GPMTAR1:1 8,033' 8,040' 8,045' Gas Separator GRSFTX AR H6 Tandem Seal Section GSB3DB UT/L T AB/HSN PFSAlFSA CL5 114 KMH 2330 volt, 30 amp Motor 8,059' Centrilift Pumpmate wI fin centralizer I 8,074' ~ ... ~ ~ .... 2jts. of solid liner (82') 8291 '-8373' 91 jts. of slotted liner (3590') (8373'-11964') 4.5" 12.6#, L-80 IBT tubing Baker Float shoe at 11986' ~ ... 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (8656'-11953') .... Mid-lateral TVD @ 3877' DATE REV. BY COMMENTS MILNE POINT UNIT 11 109/00 MOO Initial casing completion Doyon 141 WELL J-224 11 /21 /00 M. Linder Initial ESP completion 4-ES API NO: 50-029-22976-00 -o-u 5/20/05 L. Hulme ESP replacement by 4ES µ,.¥¡. f\\) ~ Eb--D2.9 ~ 2d..~ l(.o~-.:)D 9/01/05 MOO ESP Replacement by 4-es BP EXPLORATION (AK) ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-224 MPJ-224 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/31/2005 Rig Release: 9/2/2005 Rig Number: Spud Date: 10/9/2000 End: 9/2/2005 Date From.. To Hours Task Code NPT Phase Description of Operations 8/31/2005 06:00 - 09:00 3.00 MOB P PRE RDMO from MPH-08. Move to MPJ-Pad. 09:00 - 10:30 1.50 MOB P PRE Lay herculite, rig mates spot rig modules 10:30 - 12:00 1.50 RIGU P PRE Raise and set derrick I Accept rig at 12:00 hrs 12:00 - 13:00 1.00 WHSUR P DECaMP PJSM Fill pits with 140* F sea water R/U lines to tree and tiger tank test to 3500 psi 13:00 - 17:00 4.00 KILL P DECOMP Order out seawater and wait Take on 380 bbls of 130* F seawaterCirculate and kill Well with hot Sea Water at 4 bpm/550 psi. Still getting heavey oil returns. However, ran out of Sea Water. 17:00 - 21 :30 4.50 KILL DECaMP Additional hot Sea Water arrives on location. 21 :30 - 22:30 1.00 KILL DECOMP Continue to circulate additional hot Sea Water. Unable to get returns after 300 bbls. Well on vac. 22:30 - 00:00 1.50 KILL DECaMP Monitor Well. Order additional Sea Water. Rig up to pull ESP Completion. Prep to to Nipple down Tree. 9/1/2005 00:00 - 02:30 2.50 KILL P DECOMP Continue to wait on additional Sea Water. 02:30 - 03:30 1.00 KILL P DECOMP Bull Head 18 bbls seawater 3 bpm 170 psi in Tbg. close in. I Bull Head 250 bbls seawater 3 bpm 50 psi in Annulus Monitor well Tbg 0 psi Annulus 0 psi. Well on vac. ( Fluid level at est 2,OOO-ft). 03:30 - 04:00 0.50 WHSUR P DECaMP Set TWC and test 1000 psi 04:00 - 06:30 2.50 WHSUR P DECOMP N/D Tree and Adaptor Flange. 06:30 - 08:30 2.00 BOPSUP P DECaMP Nipple-up Double stud adaptor, Test Spool, and BOP Stack. 08:30 - 12:00 3.50 BOPSUR P DECOMP Rig-up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. AOGCC representive C. Sheeve was present for the test. 12:00 - 13:30 1.50 BOPSUF P DECOMP Pick-up Lubricator. Pull TWC. Lay down same. 13:30 - 14:30 1.00 PULL P DECOMP Make-up Landing Joint. BOLDS. Pull Tubing Hanger to floor with no problems at 45K. LAy down same. 14:30-18:00 3.50 PULL P DECaMP TOH with 2 7/8" Tubing. 18:00 - 19:30 1.50 PULL P DECOMP TOH with 2-7/8' Tbg. ESP Completion. 19:30 - 21 :30 2.00 PULL P DECaMP Lay down ESP Pump I No sand in pump I Low Flow Valve was broken off, it is 1/2" O.D. x 3" length Recovered all clamps and protectors. 21 :30 - 22:30 1.00 PULL P DECaMP Clean and Clear rig floor 22:30 - 00:00 1.50 RUNCOtvf> RUNCMP Pick up and assemble ESP Pump 9/2/2005 00:00 - 02:00 2.00 RUNCOrvP RUNCMP Service ESP pump Connect cable and test. 02:00 - 08:00 6.00 RUNCOrvP RUNCMP TIH with ESP Assembly and 27/8" Tubing by stands. Test cable every 2000'. Pump thru pump every 2000' ; 1 BPM @ 800 psi. Total Joints = 251 ea. Make-up Tubing Hanger. 08:00 - 09:00 1.00 RUNCOrvP RUNCMP Slip and Cut Drilling Line (81'). 09:00 - 11 :30 2.50 RUNCOrvP RUNCMP Make upper ESP Cable splice. Attach to Penatrator and test. 11 :30 - 12:00 0.50 RUNCOrvP RUNCMP Land tubing Hanger. RILDS. Test. 12:00 - 12:30 0.50 RUNCOrvP RUNCMP Install TWC and test. Drain BOP stack. 12:30 - 13:30 1.00 BOPSUP P RUNCMP Nipple down BOP Stack. 13:30 - 14:30 1.00 WHSUR P RUNCMP Nipple up Adaptor Flange and Production Tree. 14:30 - 15:00 0.50 WHSUR P RUNCMP Test Adaptor Flange and Tree at 5,000 psi. Good. 15:00 - 16:00 1.00 WHSUR P RUNCMP Pick-up Lubricator. Pull TWC. Lay down same. Install BPV. Secure Tree and Cellar. Periorm final ESP Cable check. Good. Release Rig at 16:00 hrs. Printed: 9/12/2005 10:04:32 AM , STATE OF ALASKA ALASKA ....ÎL AND GAS CONSERVATION COho/tISSION REPORT OF SUNDRY WELL OPERATIONS JUN 2: tv 7.005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program f,\;,~rrJ:~k~ g~ Change ~utËSR:;~":' o Suspend 0 Operation Shutdown 0 Perforate 181 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 66.05 8. Property Designation: ADL 025515 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 11975 3858 11975 3858 Casing Structural Conductor Surface Intermediate Production Liner Length 108' 8635' 3421' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-149 6. API Number: 50-029-22976-00-00 99519-6612 9. Well Name and Number: MPJ·24 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 108' 108' 1530 520 7" 8664' 3920' 7240 5410 4-1/2" 8554' - 11975' 3913' - 3858' 8430 7500 SCA~\H~EI) tHH\~ 2; 1 2005 Slotted Liner 8657' - 11954' Slotted Liner 3920' - 3859' Tubing Size (size, grade, and measured depth): 2-7/8",6.5# Packers and SSSV (type and measured depth): Baker 7" ML torque master packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): L-80 8100' 8296' Treatment description including volumes used and final pressure: RBDMS 8Ft JUN 2 J 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman ~ £:1;- - ~ '"' (Ši;ature~~._ ::"J,¡rJ~.,-._ Form Ì"O--4Ð'~evised 04/2004 Title Technical Assistant , . . . .."- Prepared By Name/Number: Phr~ r'\\ p64-t4r~9 .L~ ¡ Da~~ -Z().())Sondra Stewman, 564-4750 U K \ u ~ ~ IJ ¡ -\ L Submit Original Only MP J-24S. -mP~-~ '1, FMC Horizontal tree Model 120 ~ 3-1/8" FMC horizonta ~) Wellhead: 11" x 11" 5M tbg. spool, 11" x 3.5" RH Acme & 8rd EUE (top & bottom) J FMC TBG HNG wi 3.5" 'H' BPV profile. 110' I Halliburton ES cementer I 2,397' I 0 27/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap. .00592 bpf ) 7" 26 ppf, L-80, BTC production casing (drift ID = 6.151", cap. = 0.0383 bpf) (capacity wi tubing inside = 0.02758 bpf) KOP @ 600 ' Max wellbore Angle: 75° @ . MD Hole angle through perts = 90 deg. RA tag at 8254' 'W A. 3 Short joints 8119'-8242' Milled window from 8264'-8276' Baker HR setting sleeve I 8284' Baker 7" ML torque master pkr 600-47 Wireline entry guide 8296' :~ 8315' 8553' 1- 8563' I~ 8577' " 8620' 8664' Baker HR setting sleeve Baker HMC liner hanger Halliburton landing collar Halliburton float collar Halliburton float shoe 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- 8,656' - 11,953' MD (3296') DATE REV. BY COMMENTS 11/09/00 MDO Initial casing completion Doyon 141 11/21/00 M. Linder Initial ESP completion 4-ES 5/20/05 L. Hulme ESP replacement by 4ES KB elev. = 28.55' DF elev. = 66.05' GL elev. = 36.30' , Cameo 2-7/8" x 1" sidepoeket KBMM GLM 143' Cameo 2·7/8" x 1" sidepoeket KBMM GLM 7891' HES 2-7/8" XN nipple 2.205" ID 8117' MS-1 Pressure Head I 8046' Tandem Pumps 100GC1150 I 8048' & 19GC8200 GPMTAR1:1 Gas Separator GRSFTX AR H6 I 8066' Tandem Seal Section I GSB3DB UT/L T AB/HSN PFSAlFSA CLS 8071' 114 KMH 2330 volt, 30 amp Motor I 8085' XT1 Sensor wi fin centralizer I 8096' Intake Sensor @ (TVD) I 3805' ~ .. ~ ~ .... ~ 2jts. of solid liner (82') 8291'-8373' 91 jts. of slotted liner (3590') (8373'-11964') 4.5" 12.6#, L-80 IBT tubing Baker Float shoe at 11986' ~ 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (8656'-11953') .... Mid-lateral TVD @ 3877' MILNE POINT UNIT WELL J-224 API NO: 50-029-22976-00"-00 -H PI (1) ~ C)O :.Q2Ç}- W1lo -(ð) ill BP EXPLORATION (AK) ) ) BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-t24 MPJ-î24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2005 Rig Release: Rig Number: Spud Date: 10/9/2000 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/17/2005 13:00 - 16:30 3.50 MOB P PRE RDMO D-26A Well Slot. Secure BOP to transport cradle. 16:30 - 21 :00 4.50 MOB P PRE Moving Sub Base, Pipe Shed, Pits, and Camp from D-Pad to Milne Pont. 21 :00 - 00:00 3.00 MOB N WAIT PRE Park Rig Modules at M-Pad Access Road due to Lost Circulation problems on the Well that Rig #9 is drilling. Allow Trucks hauling Water, Drilling fluids, Mud Products to pass by the Rig to surport Rig #9. 5/18/2005 00:00 - 02:00 2.00 MOB N WAIT PRE Continue to wait trucks to pass in support of Rig #9. 02:00 - 18:00 16.00 MOB P PRE Continue with rig move to Milne Point. 18:00 - 20:00 2.00 MOB P PRE Continue to move to MPJ-24 Well Slot. 20:00 - 00:00 4.00 RIGU P PRE Load BOP Stack in Sub Base. Spot Sub over Well. Spot Pipe Shed, Pits, and Camp. Spot Tiger Tank. Raise and scope Derrick. 5/19/2005 00:00 - 02:00 2.00 RIGU P DECOMP Take on 120 deg Sea Water in Pits. Pick-up Lubricator and pull BPV. Hook-up Lines to Horizontal Well Head. Test Lines to 3,500 psi. Accepted Rig at 00:00 hrs. 02:00 - 02:30 0.50 RIGU P DECOMP PJSM with All. 02:30 - 05:00 2.50 KILL P DECOMP SITP = 0 psi. SICP = 480 psi. Kill Well 120 Deg Sea Water at 4 bpm/675 psi. Pumped a total of 385 bbls. Recovered -92 . bbls of Diesel and Oil. Truck Diesel and Oil to MPU ORT. 05:00 - 06:00 1.00 KILL P DECOMP Monitor Well. Well on vacuum. Install TWC and test. Blow down and rig down Lines. 06:00 - 07:00 1.00 WHSUR P DECOMP Nipple down Horizontal Well Head. 07:00 - 13:30 6.50 BOPSUP P DECOMP Nipple up BOP Stack. Nipple up Kill and Choke Wing Valves. Torque all bolts. Hook up Koomey Hoses. Install 2 7/8" x 5" variable bore Pipe Rams. 13:30 - 14:00 0.50 BOPSUP P DECOMP Rig up test equipment. 14:00 - 17:00 3.00 BOPSUP P DECOMP Perform BOPE Test per BP/AOGCC requirements at 250/3500 psi. State's right to witness test waived by C. Sheeve. Test witnessed by Co Man and Tool Pusher. 17:00 - 18:00 1.00 WHSUR P DECOMP M/U lubricator & Pull TWC. UD TWC & lubricator 18:00 - 19:00 1.00 PULL P DECOMP M/U landing jt. BOLDS. P/U & pull hanger to floor wI 50K. 19:00 - 21 :00 2.00 PULL P DECOMP UD hanger. Pump 25 bbls of seawater down annulus. Monitor well. Cut & test ESP cable. UD 5 singles of 27/8" tubing. 21 :00 - 00:00 3.00 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. 5/20/2005 00:00 - 01 :00 1.00 PULL P DECOMP Con't to POOH & stand back 2 7/8" ESP completion. 2/3 of bootom jt of 2 7/8" tubing + bottom 2 7/8" pup jt were packed full of medium grained sand. 01 :00 - 04:30 3.50 PULL P DECOMP Break out & UD ESP. Pump was packed wI sand as above. 04:30 - 06:00 1.50 PULL P DECOMP Clear & clean rig floor. R/U to P/U ESP. Load new spool in spooling unit. 06:00 - 09:00 3.00 RUNCOfvP RUNCMP Pick-up and service ESP assembly. 09:00 - 17:00 8.00 RUNCOfvP RUNCMP TIH with ESP Assembly and 2 7/8" Tubing. Ran new XN-Nipple and new 2 7/8" x 1" KBMM GLM on bottom of completion. Test cable every 2000'. Pump thru pump every 2000' ; 1 BPM @ 800 psi. Ran 252 jts. Used 3 Flat Guards, 5 Protectolizers & 133 La Salle Clamps. 17:00 - 19:30 2.50 RUNCOfvP RUNCMP MIU landing jt into hanger. Install penetrator. Make final splice for cable connector. Check & test same. Bottom of string @ 8100'. 19:30 - 20:30 1.00 RUNCOfvP RUNCMP Land & align tubing hanger. RILDS. P/U Wt = 47K, SIO Wt = 25K. Install & test TWC to 3500 psi, OK. 20:30 - 21 :30 1.00 BOPSUP P RUNCMP N/D BOPE. Printed: 5/23/2005 1 :37:45 PM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPJ-~24 MPJ-t24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 5/20/2005 From - To Hou rs Task Code NPT Phase 21 :30 - 23:00 1.50 WHSUR P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP Page 2 of 2 Start: 5/17/2005 Rig Release: Rig Number: Spud Date: 10/9/2000 End: Description of Operations N/U X-mas Tree. Test hanger & tree to 5000 psi, OK. Perform final check on ESP. P/U lubricator & pull TWC. Install BPV. Secure well & clean cellar. RELEASE RIG @ 2400 hrs. Printed: 5/23/2005 1 :37:45 PM F:\LaserFiche\CvrPgs _I nserts\M icrofi 1 m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ) ) Permitto Drill 2001490 MD 11975 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116/2003 Well Name/No. MILNE PT UNIT SB J-24 Operator BP EXPLORATION (ALASKA) INC 3658 Completion Dat 11/5/2000 Completion Statu l-OIL Current Status l-OIL APl No. 50-029-22976-00-00 UIC N REQUIRED INFORMATION Mud Log N__~o Sample N_9.o Directional Survey_____J~_.. y.~__~ _, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval OH I Start Stop CH (data taken from Logs Portion of Master Well Data Maint Dataset Received Number Comments T Lis Verification FINAL 10276~,,,~- FI NAL LIS VERIFICATION FINAL 10360 ~ FINAL 100 11901 Open oh 100 11901 OH OH 2721 11908 OH 9/12/2001 8/13/2001 9/1 2/2001 9/1 2/2001 10/10/2001 10276(.,~00~ 1901 Lis Verification Paper Copy 10360~21-11908 Oigi~_Da~ _ Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~3 Chips Received? ~ Analysis ~ R ~.c.~.iv~.d ? Daily History Received? ~1~ N Formation Tops ~1 Comments: Compliance Reviewed By: Date: To'- WELL LOG TRANSM1TFAL State of Alaska October 5, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 ~~-~ Anchorage, 99501 AK-MM-00220 c:~ O- ! 15 ~ .,.., ~~.~ ,......o~ ........... ~-"' ........ MPJ-24: Digital Log Images: 2 CD Rom Discs PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITFAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED OCT 10 Alaska Oil & Gas Cons. Commi~,aion Anchorage WELL LOG TRANSMITTAL To: State of Alaska September 7, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation.,Evaluafio.n Logs: MPJ-24, L1,L1 PB1 & L1 PB2, AK-MM-10127 1 LDWG formatted Disc with verification listing. API#: 50-029-22976-00, 50-029-22976-60, 50-029-22976-70 & 50-029-22976-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETYER 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: STATE OF ALASKA ALASKa" _AND GAS CONSERVATION COMIC" .~ION REPORT OF SUNDRY WELL OPERATION~; 1. Operations performed: I-I Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other N2 Lift for oil sample 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 66.05' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2713' NSL, 3402' WEL, Sec. 28, T13N, R10E, UM MPJ-24 At top of productive interval 9. Permit Number / Approval No. 200-149 5138' NSL, 4569' WEL, Sec. 29, T13N, R10E, UM (OB) 10. APl Number At effective depth 50-029-22976-00 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 5172' NSL, 2663' WEL, Sec. 30, T13N, R10E, UM 12. Present well condition summary Total depth: measured 11975 feet Plugs (measured) true vertical 3858 feet Effective depth: measured 11975 feet Junk (measured) true vertical 3858 feet Casing Length Size Cemented MD TVD Structural Conductor 108 20 260 sx Amtic Set (Approx.) 108 108 Surface Intermediate Production 8635 7 1025 sx Amtic Set III, 685 sx Class 'G' 29-8664 29-3355 Liner 342] 4-1/2 Uncemented Slotted Liner 8554-11975 3340-4563 Perforation depth: measured 8657'-11954' Slotted Liner ~ E C ~ ~ V ~ D true vertical 3354' - 4548' , Jij j 05 2001 Tubing (size, grade, and measured depth) 2-7/8", 6.5¢, L-80 8191' Alasl(a Oil & C~ss f~..on.,." ~- Commission Packers and SSSV (type and measured depth) ,~nchorage 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service ,, ,,=,,,, ,,,,, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~lned .... Michae'.Wi'.'iam~...,~_~_~w ~ ....... Title.. ~echni~al..Assista.nt ...... Date ' ":.. ' Submit In Duplicate 'Form 10-404 Rev. 06/15/88 i""i ?'~'? i'~ ....... i. I'"'~ i """"~ i. ~ '...~ ~ ~ ~? ;' t ~,/'""t ~.... 11/29/2000 MPJ-24 (' DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS N2 LIFT: N2 FLOW SUMMARY RU CTU #3, N2 UNIT, AND APC TEST SEPARATOR FOR N2 LIFT. HAD TO RECONFIGURE RIG UP WITH SECOND WELLHEAD VALVE, CHECK VALVES, ET(:;. STARTED N2 DOWN COIL, RIH TO 26' TO MAKE SURE COULD GET IN WELL, PUH TO SURFACE TO INSURE COIL FLUIDS GO TO APC AND AID IN PRESSURING UP VESSEL. RIH W/N2 AT 500 SCF/M; PARKED AT 3300 AND SHOT FLUID LEVEL-FLUID AT SURFACE AND WITH 95 IA. RIH PUMPING N2 AT 200 SCF. STOP AT 8050 (BELOW GLM, ABOVE PLUG). BHP FLUCTUATED FROM 1600 PSI TO 1500 PSI. 40 IA (FLUID PACKED). PUMP 30 BBLS 60/40 METH DOWN CT X T ANNULUS TO CLEAR GLV. OPEN WELL BACK TO SEPARATOR 183 BBLS SHIPPED FROM START OF JOB. 200 WHP, 25 IA. *****WELL IS LEFT OPEN TO SEPARATOR***** RIH PUMPING N2 AT 350 SCF. TRY VARIOUS METHODS OF DEPTH AND RATES TO ACHIEVE FLOW. MAX RATE 600 SCF, MIN RATE 250 SCF. MAX FLOW 29 BBLS/HR. 1450 BHP FROM CENTRILIFT, STEADY ALL DAY. TOTAL BBLS RETURNED FOR DAY= 147 BBLS, TOTAL CUMULATIVE FOR JOB 302 BBLS RETURNED. *****WELL OPEN TO SEPARATOR***** RIH WITH N2 @ 500 SCF TO 8075, DID NOT GET FLOW. PUH TO 3300 AND GOT WELL TO KICK OFF AT 400 SCF/MIN WITH RATES' AT 20-30 BBLS/HR. RIH TO 8050 TO TRY INCREASE FLOWRATE BUT WELL DIED, SWABBED UP TO 3300 AND WELL FLOWED AGAIN. RIH TO 4300 TO TRY AND INCREASE FLOWRATE, BUT ALAS, IT TOO DIED; SWABBED BACK TO 3300. WITH OVER 500 BBLS RECOVERED, WELL FINALLY GAVE UP SOME OIL, AND IA FLUID LEVEL BEGAN DROPPING. RAN OUT OF DIESEL ON N2 PUMPER AND HAD TO SHUT DOWN. TRIED KICKING WELL OFF AND TOOK AWHILE TO GET GOING, OIL CUT INCREASED TO 55% BUT WAS FLOWING COLD AND THICK. FLUID LEVEL WORKED DOWN TO 1700' AND BHP WAS 1500 (NOTE MATH IS NOT WORKING), RIH TO TRY INCREASING RATE, BUT LOST N2 PUMPER AGAIN. HAD TO PICK UP TO 3300 TO KICK OFF AGAIN. TOTAL RECOVERED 376 BBLS, 678 TOTAL. PUH TO 2300, RATE STILL LOW, RIH AND IT APPEARED THE WELL WAS STACKING-SUPPOSING IT MUST BE THICK COLD CRUDE HOLDING COIL. RIH TO 8090 AND RATE STILL LOW. PUH TO 3480, CONSTANTLY GETTING GREATER THAN 80% OIL. TALK WITH TOWN, DECIDE TO POOH. FINAL=695 BBLS RETURNED. 94% OIL, 1% MUD, RDMO ****WELL OPEN TO SEPARATOR**** Fluids Pumped BBLS. Description 53 60/40 METH 233.6 NITROGEN (9390 GAL, 875,052 SCF) 286.6 Total f ALASK,- .~IL AND GAS CONSERVATION COM ,..,SION 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. / 't,O"'..~TlOf'~[ 200-149 3. Address ',_.,,~,~,..; 8.-APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 i~'.~¢,~~.,. 50-029-22976-00 4. Location of well at surface .......... it. ~.-:'.-~az.~_..-.j-~-~" "" 9. Unit or Lease Name 2713' NSL, 3402' WEL, Sec. 28, T13N, R10E, UM " Milne Point Unit At top of productive interval ':;. . .' ' 5138' NSL, 4569' WEL, Sec. 29, T13N, R10E, UM (OB) .-../-"' At total depth , .. . · ~ .10. Well Number 5172' NSL, 2663' WEL, Sec. 30, T13,, R10E, UM ii ...... "..,J~aS.'. 'i___ i' MPJ-24 "' ' "'" ....... ~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 66.05' ADL 025515 12. Date Spudded10/9/2000 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'l 0/21/2000 11/5/2000 115' water depth' if °ffsh°reN/A MSL 110' N°' °, c°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Direcltional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11975 3858 FTI 11975 3858 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electdc or Other Logs Run MWD, GR, RES, PWD, AMI, Caliper 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 92# H-40 Surface 108' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 29' 8664' 9-7/8" 1025 sx Arctic Set III, 685 sx Class 'G' , 4-1/2" 12.6# L-80 8554' 11975' 6-1/8" Uncemented Slotted Liner , , 24. Perforations pp. en to. P.roductipn (M.D+.TVD of Top and ' 25. ' ' ' YUBING RECORD ' Bottom and ~merva~, s~ze ana number) S~ZE DEPTH SET (MD)' P.~,CKER S'ET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 8191' RECEIVED 8657'- 11954' 3920'-3859' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED F E: B I ~ Z 0 01 8296' set TorqueMaster Packer (w/ Retrieved Whipstock on top at 8286') Alaska 0il & Gas Cons. Commissio Anchorage Freeze Protect Tubing w/15 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 22, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE ~'.,28. "'CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 291 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 7718' 3682' NB 7818' 3714' NC 7916' 3747' NE 7981' 3768' N F 8131' 3816' OA 8254' 3852' OB 8590' 3916' RECEIVED FEB ZOO1 Alaska 0il & Gas Cons. Commission Anchor~je , $1. List of Attachments: Summary of Daily Drilling Fleports, Surveys 32. I hereby certify that the foregoing i$ true and correot to the best of my knowledge Signed TerrieHubbIe .,~,/1~/',. ~~~._ Title TechnicalAssistant Date MPJ-24 200-149 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL · . ",, .., .. ,., .. ~ BP.,EXPLORATION Page 1 of 1 , ' '. , · · '. ,, · ' ." ' '. ~ .. "'l~eak~Off Testsumma~rv , Legal Name: MPJ-224 Common Name: MPJ-224 Test Date .. '.TeSt Type., , ,. ., TeSt, Depth'(TMD.). . '. Test Depth,~(,TVD) · AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/19/2000 FIT 8,704.0 (ft) 3,920.0 (ft) 9.10 (ppg) 310 (psi) 2,163 (psi) 10.62 (ppg) 11/2/2000 FIT (ft) (ft) (ppg) (psi) (psi) 9.10 (ppg) ; ! I. ~. Printed: 111212001 2:31:16 PM RECEIVED BP EXPLORATION FEB 1 ~ Z01)4ge I of 8 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: . 'Sub' PhaSe Description of Operations Date From-To Hours Task Code 10/8/2000 00:00 - 05:00 5.00 RIGU PRE Move rig with derrick up MPJ-223 to MPJ-224 (30' in line) - Rig up - Accept rig 0500 hrs 10/8/2000 05:00 - 10:00 5.00 BOPSUR INT1 Nipple up 20" diverter system with single 16" diverter line 110' long 10:00 - 13:00 3.00 DRILL INT1 Change over top drive saver sub & bell guide from 3 1/2 to 5" drill pipe - Load pipe shed with 5" 19.5~/ff 'G' drill pipe 13:00 - 19:00 6.00 DRILL INT1 Pick up and stand back in derrick 5" drill pipe 19:00 - 19:30 0.50 DRILL INT1 Function test 20" diverter system, Gas & PVl' alarms with Jeff Jones of AOGCC - all ok 19:30 - 00:00 4.50 DRILL INT1 Finish picking up 5" drill pipe - Total 96 stands in derrick +/- 9100' - Pick up and stand back Flex collars, HWT drill pipe 1019/2000 00:00 - 00:30 0.50 DRILL INT1 Pro-Spud meeting with drill crew and service personnel - Well plan & Hazards discussion 00:30 - 03:00 2.50 DRILL INT1 Make up BHA #1: Pick up Sperry 6 3~4" Motor wi 9 5/8" stablizer sleeve - adjust motor to 1.50 deg BH - Make up Sperry MWD I GR / PWD / Acal - Program MWD & orient - Make up HTC 9 7/8" MX-C1 mill tooth bit jetted with 3-20's 1-10 03:00 - 03:30 0.50 DRILL INT1 Fill hole with mud & check for leak - ok 03:30 - 00:00 20.50 DRILL INT1 Tag bottom at 108' - Spud in at 0330 hrs 10/912000 - Drill to Kick off point at 300' - Kick off at 290 deg Azimuth build angle at 4 deg / 100' - Drill to 1825' at 00:00 hrs -Art 8.25 hrs, Ast 6.75 hrs, Average Rop 114 ftJhr - 400 gpm 1500 psi - 70 rpm, 5,000 fi/lb torque - Wob 20k 10110/2000 00:00 - 06:30 6.50 DRILL INT1 = Continue Directional drilling 1825 to 2779' - Finish building angle to 72 deg at 290 deg Azimuth 4 deg / 100' build rate 06:30 - 09:00 2.50 DRILL INT1 Pump out of hole at 404 gpm 1400 psi rotating at 40 rpm - Did not circulate bottoms up due to hole washing out and loosing angle - Pump out of hole to 1000' 09:00 - 09:30 0.50 DRILL INT1 Pull out of hole without pumping to BHA 09:30 - 12:00 2.50 DRILL INT1 Pull BHA #1: Lay down MWD and down load LWD - Lay down Pressue drop sub - Break bit 12:00 - 14:00 2.00 DRILL INT1 Make UP BHA #2: Adjust motor to 1.15 deg BH- Make up New bit jetted wi 3-20's 1-10 - Pick up Sperry MWD I GR I Res I PWD / Acal - Orient and Program tools - New MWD picked up to satisfy JORPS requirement 14:00 - 15:00 1.00 DRILL INT1 TIH with 5" drill pipe to 2719' - no problem 15:00 - 15:30 0.50 DRILL INT1 Break Circulation & Precautionary wash 60' to bottom at 2779' - no Fill - Check shot benchmark' survey at 2712'- ok 15:30 - 00:00 8.50 DRILL INT1 Directional drill 2,779 to 4,022' at 00:00 hrs - Pumping at 421 gpm 1200 psi - Rotating at 70 - 80 rpm with 8,000 fi/lb torque - Last 24 hrs Art 7.0 hrs, Ast 3.75 hrs, Average Rop 204 fi/hr 10111/2000 00:00 - 04:00 4.00 DRILL INT1 Continue Directional drilling 4022 to 4551' - Pump 422 gpm 1300 psi - 100 rpm with 9,000 fi/lb torque 04:00 - 04:30 0.50 DRILL INT1 Circulate bottoms up at 4551' at 457 gpm 1400 psi 04:30 - 06:30 2.00 DRILL INT1 Backream out of hole to prevent swabing - Rotate at 80 rpm, pumping 421 gpm - Backream out 20 stands to 2,701' - attempt to pull without pumping - swabing, pump addition stand out - Pull three stand without pumping, slight swabing - pooh to 2,238'- total 25 stands 06:30 - 08:00 1.50 DRILL INT1 TIH wash through bridge at 2,261' - Continue wash & ream hole to 2,911' - TIH - Wash through tight spot at 3,530 to 3,560' - Continue TIH - Wash 60' to bottom at 4,551' 08:00 - 20:30 12.50 DRILL INT1 Directional drill 4,551 to 6,038'- Pump 457 gpm 1400 psi - 80 rpm 15,000 fi/lb torque - wob 15K 20:30 - 22:00 1.50 DRILL INT1 Pump high vis, fiber sweep and circulate around while pumping 457 gpm - Circulate hole clean - 2.5 bottoms up Printed: 11/28/2000 8:49:37 AM ' (" RECEIVE Page 2 of 8 BP EXPLORATION FEB 1 4 ZOO1 Operations Summary Report Alaska Oil & Gas Cons. Commission Legal Well Name: MPJ-224 ^ncnorage Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DP,ILL+COMPLETE Start: 1018/2000 End: 11/22/2000 Contractor Name: NABOP, S P,ig P,elease: 11/22/2000 Group: P,IG P,ig Name: N^BORS 4ES P,ig Number: . . Sub Date From-To Hours Task Code Phase. Description of Operations 1011112000 22:00 - 00:00 2.00 DRILL INT1 Pump out of hole without rotating at 422 gpm - Ream back down stands that pull tight, or give increase in pump pressure - pump out to 3561' - 27 stands - Pull out of hole without pumping for wiper trip at 00:00 1011212000 00:00 - 02:00 2.00 DRILL INT1 Continue Pooh for wiper trip to 1,704' - total 46 stands - Did not have to pump or backream above 3,500' 02:00 - 03:30 1.50 DRILL INT1 TIH - tight spot at 2,044 to 2,075' - Continue TIh with no problem - Wash 60' to bottom, no fill 03:30 - 04:00 0.50 DRILL INT1 Directional drill 6038 to 6066' - Make connnection - MWD not working 04:00 - 05:00 1.00 DRILL LMWD INT1 Trouble shoot MWD problem - regain MWD function 05:00 - 08:30 3.50 DRILL INT1 Continue directional drill 6,066 to 6,437' - Pumping 457 gpm 1400 psi - MWD failure 08:30 - 10:30 2.00 DRILL LMWD INT1 Circulate while trouble shoot MWD problem - Circulate two bottoms up 10:30 - 11:30 1.00 DRILL LMWD INT1 Pump out of hole without rotating 6,437 to 5,510' - 10 stands 11:30 - 15:30 4.00 DRILL LMWD INT1 Pull out of hole 5 stands to 5,047'- no problem - Pump slug and continue pooh 15:30 - 18:00 2.50 DRILL LMWD INT1 Pull BHA - Down load MWD - Lay down pulser sub - Check bit & motor ok 18:00 - 19:30 1.50, DRILL LMWD INT1 Make up BHA #3 - Re-run bit #2 - Make up new pulser sub, Orient MWD and Program Sperry MWD I GR I Res I PWD I Acal 19:30 - 20:30 1.00 DRILL LMWD INT1 Slip and cut drill line 20:30 - 00:00 3.50 DRILL LMWD INT1 TIH fill pipe every 20 stands - No problem while TIH down 5,215' -Tight hole below 5,215' - Ream 5,215 to 5,300 - 5,400 to 5,490 - 5,860 to 5,955' - At 5,955 00:00 hrs 10113/2000 00:00 - 00:30 0.50 DRILL LMWD INT1 Finish TIH 5,955 to 6,347 with no problem - Did not have to ream - Precautionary Wash 90' to bottom at 6,437' 00:30 - 00:00 23.50 DRILL ~INT1 Directional drill 6,437 to 8,479' at 00:00 hrs - Top 'OA' sand 8,254' - Pumping 492 gpm 1600 psi - 80 rpm 17,000 fi/lb torque - Add 1% lubetex to mud system for torque - Torque up to 25,000 ft/Ib before lubetex addition - Last 24 hrs Art 12.0 hrs, Asr 4.75 hrs, Average Rop 121 fi/hr - Start building angle at 5 deg 1100' at +/- 8200' 10/14/2000 00:00 - 03:30 3.50 DRILL INT1 Directional drill 8,479 to 7" casing point at 8,674' - Top 'OA' sand 8,254' - Build angle to 87 deg - pumping 492 gpm 1600 psi -Art 1.0 hr, Ast 2.0 hrs, Average Rop 65 fi/hr 03:30 - 06:00 2.50 DRILL INT1 Circulate around Two high vis fiber sweeps at 500 gpm - Circulate Three bottoms up - shakers clean 06:00 - 10:00 4.00 DRILL INT1 Wiper trip to 5,400' - Pump out of hole 8,110 to 5,914 due to swabing 10:00 - 11:30 1.50 DRILL INT1 TIH - Wash through tight hole 6,843 and 8,358' - Wash 90' to bottom 11:30 - 14:00 2.50 DRILL INT1 'Circulate around high vis fiber sweep at 565 gpm - Circulate Three bottoms up - shakers Clean 14:00 - 19:30 5.50 DRILL INT1 Pooh without pumping or backream - Pump slug at 7,200' - Record P/U, . SIO R/T wt and torque every 5 stands - SLM, no correction 19:30 - 22:00 2.50 DRILL INT1 Pull BI-IA - Down load LWD tools & lay down - Drain and Lay down mud I motor 22:00 - 22:30 0.50 DRILL INT1 Service top drive 22:30 - 23:30 1.00 DRILL INT1 Make up BHA: Pick up 9 7~8" Hole opener, N/B stablizer, Sperry Acal tool w/recorded only data, Stab, flex collar Stab, 2-flex collar - Tag up at 300' 23:30 - 00:00 0.50 DRILL INT1 Began hole opener run at 300' md - Pump 457 gpm 450 psi, 100 rpm 4,000 fi/lb torque - Rop 500 fi/hr 10/15/2000 00:00 - 00:00 24.00 DRILL INT1 Continue opening hole with 9 7/8" packed hole opener assembly - Ream from 400' to 7,400' at 00:00 hrs - Ream tight spot until clean - Pump 492 gpm 1400 psi, Rotating at 100 rpm 15,000 fi/lb torque - Add Printed: 11/28/2000 8:49:37 AM ,. . ' (" (' RECEtVFF) !' 'm' BP EXPLORATIONFEBJ. 4 ~001Page3°f8 · Operations Summary Report Alaska Oil & Gas Cons. Commission Anchnr'a~ Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: N^BORS 4ES Rig Number: Sub ' Date From - To Hours Task Code Phase Description of Operations 1011512000 00:00 - 00:00 24.00 DRILL INT1 5% lubricant to system while reaming starting at +1- 4,000' - Lower APl I fluid loss to < 4.0 cc ,10116/2000 ~00:00 - 04:00 4.00 DRILL INT1 Finish reaming with packed hole opener assembly from 7,400 to bottom at 8,674' - Ream through tight spot until clean - P/U wt on bottom 155K, SIO wt 95K - torque 15,000 fi/lb at 100 rpm - 5% lubricant in system, APl fluid loss 3.6 cc 04:00 - 07:00 3.00 DRILL INT1 Circulate around high vis, fiber sweep weighted to 10.5 ppg - Continue circulate until hole clean at 510 gpm 1600 psi - Circulated three bottoms up 07:00 - 08:30 1.50 DRILL INT1 Slow pump to 300 gpm - add 12.5 ppb stickless bead to system and spot down hole 08:30 - 13:00 4.50 DRILL INT1 Pooh stand back 5" drill pipe, Record plu s/o wt. every 5 stands, record p/u, s/o, r/t wt. every 10 stands, - no problem pooh 13:00 - 14:00 1.00 DRILL INT1 Lay down BHA - Down load Acal data - Hole average size 11" 14:00 - 15:30 1.50 CASE INT1 Rig up Doyon drilling casing tools and Franks fill up tool 15:30 - 16:00 0.50 CASE INT1 Pre-Job safety meeting with drill crew on running 7" production casing 16:00 - 19:30 3.50 CASE INT1 Run 7" 26~ L-80 Btc-Mod production casing - Make up torque 9,000 fi/lb - Install 7 1/8 x 9 5/8" straight rigid centralizer jts 1 - 40, none across 'OA' sand on jts # 9 & 10 - Run 75 jts +/- 3,000' - Record p/u s/o wt. every 10 jts. - Trouble getting pipe down starting at +/- 2200' - Having to work pipe 19:30 - 20:00 0.50 CASE INT1 Circulate bottoms up at 3,000' 7.5 bpm 400 psi - Shakers covered with solids 20:00 - 22:30 2.50 CASE INT1 Continue running 7" caisng to +/- 6,000' - total 150 jts in hole - No trouble running pipe below 4,500' 22:30 - 23:30 1.00 CASE INT1 Circulate bottoms up at 6,000 7.5 bpm 600 psi - Less solid on skakers 23:30 - 00'.00 0.50 CASE INT1 Continue running 7" production casing - +/- 6,500' -165 jts in hole at 00:00 hrs - 10117/2000 00:00 - 01:30 1.50 CASE INT1 Finish running 211 jts 7" 26# L-80 BTC casing. 01:30 - 02:00 0.50 CASE INT1 M/U landing jt. Lay down Frank's casing tool. Make up cement head. 02:00 - 05:00 3.00 CASE INT1 Break circulation slow at 2 bpm and increase rate to 8 bpm with 650 psi. Reciprocate casing with full returns and no losses. Circulate two casing volumes. 05:00 - 07:30 2.50 CASE INT1 Pre job safety meeting with all personnel. Test lines 4000 psi. Drop plug and load top plug. Pump 50 bbls chemical wash and 75 bbls mud push. Mix and pump 410 sxs ASIII @ 10.7 ppg. Tail with 575 sxs "G" ~ 15.8 ppg. Pump 20 bbls water and displace with rig pumps. Pump efficiency 94%. Bump plug to 2000 psi. 07:30 - 09:00 1.50 CASE INT1 Open ES cementer with 3200 psi. Circulate out chemical wash, mud push and 50 bbls contaminated cement. 09:00 - 11:00 2.00 CASE INT1 Perform second stage cement job. Mix and pump 615 sxs ASIli ~10.7 ppg. When cement reached surface, mixed 18 bbls tail cement-Class "G" ~ 15.7 ppg. Drop plug and displace with Dowell. Bump plug with 2500 psi. Floats held CIP ~ 1100hrs. 11:00 - 12:00 1.00 CASE INT1 Lay down cement head and landing jt. '12:00 - 14:30 2.50 WHSUR INT1 Nipple down 20" BOP and Diverter 14:30 - 16:00 1.50 WHSUR INT1 Land FMC Tubing Head, 11"-5M x 7-1/16"-5M Uni-Head. Test to 250-1,000 psi for 10 Min. (Test Good) ~ 16:00 - 19:00 3.00 WHSUR INT1 Nipple-Up 7-1/16"-5M BOP 19:00 - 20:30 1.50 CASE INT1 Pick-Up 5" handling equipment. Hold pre-job safety meeting 20:30 - 00:00 3.50' CASE INT1 Lay down 5" drill pipe in mouse hole. 10/1812000 00:00 - 01:30 1.50' CASE INT1 Finish laying down 5" drill pipe. Printed: 11/28/2000 8:49:37 AM ("' (' RECEIVED BP EXPLORATION FEB 1 4 Z0{~age 4 of 8 Operations Summary Report Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/2212000 Contractor Name: NABORS Rig Release: 11/2212000 Group: RIG Rig Name: NABORS 4ES Rig Number: .... Sub ............ Date From - To Hours Task Code Phase Description of Operations :10118~2000 01:30 - 02:30 1.00 CASE INT1 Nipple up flow line. Install wear ring. 02:30 - 05:00 2.50 CASE INT1 Pick up and stand back 37 stands 3-112" drill pipe. 05:00 - 11:00 6.00 BOPSUR INT1 Install test plug and test all rams and valves 250~2000; annular 25012000. John Spaulding with AOGCC waived witnessing test. Pull test plug and install wear ring. 11:00 - 13:00 2.00 DRILL LNR1 Make up 6-118" directional assembly. 13:00 - 14:00 1.00 DRILL LNR1 ABl(angle at bit) motor failed. Lay down same and picked up another motor. 14:00 - 16:00 2.00 DRILL LNR1 Trip in hole picking up 3-112" drill pipe. Tag "ES" cementer. 16:00 - 17:00 1.00 DRILL LNR1 Drill Es cementer with 210 gpm, 60 rpms, 1100 psi. Torque 5-10,000 ff lbs. Wob 0-5,0000. 17:00 - 21:30 4.50 DRILL LNR1 Continue tripping in hole picking up 3-112" drill pipe to landing collar, to 8378 21:30 - 22:30 1.00 DRILL LNR1 Circ 22:30 - 00:00 1.50 DRILL LNR1 Test csg. to 3500 for 112 hr. 1011912000 00:00 - 02:00 2.00 DRILL LNR1 Drill float equipment and 30' new hole to 8704'. 02:00 - 03:30 1.50 DRILL LNR1 Circulate and condition mud. 03:30 - 04:00 0.50 DRILL LNR1 Perform FIT with 9.1 mud. Held 310 psi. Emw=10.6 ppg 04:00 - 05:00 1.00' DRILL LNR1 Slip and cut drill line. Adjust brakes. 05:00 - 06:30 1.50 DRILL LNR1 Displace well to Baradriln mud. 06:30 - 07:00 0.50 DRILL LNR1 Retest formation with new 9.1 ppg mud in hole. Pressured up and held 380 psi for 10 minutes without breaking down formation. EMW--11.0 PPg 07:00 - 00:00 17.00 DRILL 'LNR1 Directional drill from 8704'-9815. Art-8 hrs, Ast-3.5 hrs, 245 gpm, 2600 3si, wob 5-8,000; Torque-7000 ff lbs = 1012012000 00:00 - 13:30 13.50 DRILL LNR1 Directional drill from 9815'-10,415'. Art-4.5 hrs, Ast-6.25 hrs, Rop-56 fph;245 gpm, 2600 psi, wob 5-8 K; Torque-7000 ff lbs 13:30 - 14:30 1.00 DRILL LNR1 Pump sweep and circulate hole clean. 14:30 - 15:30 1.00 DRILL LNR1 19 stand trip to casing shoe. No problems, occasional 10-15K drag. No swabbing. 15:30 - 16:30 1.00 DRILL LNR1 Circulate 2% EP mud lube inside casing. Service top drive. 16:30 - 18:30 2.00 DRILL LNR1 Trip back to bottom without problems. 18:30 - 00:00 5.50 DRILL LNR1 Directional drill from 10,415-10,900'. Art- 3.0 hrs, Ast 1.5 hrs,; 245 gpm, 2600 psi, wob 5-8 K; Torque7000 ff lbs. Replaced mud in hole with 600 bbls clean. Displaced on the fly. 10/21/2000 00:00 - 15:30 15.50 DRILL LNR1 Directional drill from 10,900'-11,975'. Art- 7 hrs, Ast 6.25 hrs,; 245 gpm, 2600 psi, wob 5-8 K; Torque 7000 ft lbs. 15:30 - 18:00 2.50 DRILL LNR1 Circ and pump two sweeps. Max ECD on sweeps 12.5. Final ECD 11.8 ppg. Shakers clean. 18:00 - 20:00 2.00 DRILL LNR1 Trip out to shoe {~ getting plu & rtwt &so wt every 5 sds. No swabbing. 20:00 - 23:30 3.50 DRILL LNR1 Mad pass from csg shoe~ 8630 to 8000 check shots @ 8916,9047,9364 for JORPS. 23:30 - 00:00 0.50 DRILL LNR1 Pump slug and pooh. No problems. 10122/2000 00:00 - 02:30 2.50 DRILL LNR1 Finish pooh to bha. 02:30 - 04:00 1.50 DRILL LNR1 Download MWD. Recover ESS. Good check shot. L/D motor and bit. 04:00 - 05:00 1.00 DRILL LNR1 Pick up 30 jts Hwdp and stand back in derrick. 05:00 - 06:00 1.00 DRILL LNR1 M/U hole opener assembly 06:00 - 08:30 2.50 DRILL LNR1 Trip in hole to casing shoe with hole opener assembly. 08:30 - 18:30 10.00 DRILL LNR1 Wash and ream with hole opener from 8664'-11,975'. 100-120 rpms, 300 gpm, 2700 psi, torque 4-7000 ft lbs, 500 fph.. 18:30 - 20:00 1.50 DRILL LNR1 Circ high vis sweep. Hole clean 20:00 - 00:00 4.00 DRILL LNR1 Spot 80 bbl. new mud in open hole, Poh to 8664, pumping 1bbl. per sd., getting So wts. and pickup wts every 5 sds. Printed: 11/28/2000 8:49:37 AM (" (' RECEIVED BP EXPLORATION FEB 1 4 I~{~1~ 5 of 8 Operations Summary ReportAlaska 0il & Gas Cons. Commission Anchorage Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: ..... .. ., Sub Date From-To HoUrs Task Code Phase Description of Operations 1012312000 00:00 - 03:30 3.50 DRILL LNR1 Pump d~j job and pooh. L/D hole opener, reamer and 2 stab. 03:30 - 04:30 1.00 CASE LNR1 R/U to run slotted liner. Pre job safety meeting with all personnel. 04:30 - 07:30 3.00 CASE LNR1 P/u and run shoe jt and 87 jts 4-1/2" liner. 07:30 - 11:00 3.50 CASE LNR1 R/U and plu 2-7~8" inner string and space out. 11:00 - 12:00 1.00 CASE LNR1 Mlu hanger and 1 stand drill pipe. Cir capacity of liner at 40 spin with 600 psi. 77 K up/75 K down 12:00 - 16:30 4.50 CASE LNR1 Rih with liner on 3-1/2" drill pipe. ,16:30 - 21:00 4.50 CASE LNR1 Break cir and establish full returns at 2 bpm with 600 psi. drop 1-1/4" ball and pump down. Ball did not set. Continue pumping at various rates in attempt to get ball to seat. Drop 1 3/4 ball and pressure to 1600 set hanger pressure to 3000 and release 21:00 - 00:00 3.00 CASE LNR1 Tripping out to 2 7/8, pulling wet pipe 10/2412000 00:00 - 01:30 1.50 CASE LNR1 Cut Drilling Line 01:30 - 05:00 3.50 CASE LNR1 Laying Down 2 718 string 05:00 - 12:00 7.00 STWHIP LNR1 Pick up Torqemaster packer run in hole 12:00 - 14:00 2.00 STWHIP LNR1 Set packer ~8296 14:00 - 17:30 3.50 STWHIP LNR1 Flow Check well and Trip out 17:30 - 21:00 3.50 STWHIP LNR1 Pick up Orientation tool and Trip in to 8296 21:00 - 00:00 3.00 STWHIP LNR1 Orienting to packer 136 R and log to IRA tag ~ 8119 1012512000 00:00 - 01:00 1.00 STWHIP LNR1 Finished pulling out of hole with 3-1/2" drill pipe. 01:00 - 03:00 2.00 STWHIP LNR1 Pulled BH^ and stood back HWDCs, drill collars and MWD. 03:00 - 03:30 0.50 STWHIP LNR1 Pulled wear bushing and set test plug. 03:30 - 09:30 6.00 STWHIP LNR1 Tested all rams and valves to 250 psi Iow ! 2000 psi high for 10 minutes. All tests recorded and witnessed by AOGCC Inspector, Lou Grimaldi. 09:30 - 10:00 0.50 STWHIP LNR1 Pulled test plug and installed wear bushing. 10:00 - 12:30 2.50 STWHIP LNR1 Oriented anchor on whipstock. Made up Windowmaster milling :assembly and 5-1/2" OD WindowMaster Whipstock assembly. Ran in hole with whipstock assembly to 2402' (Halliburton ES Cementer at 2400'). Set down with 20K. Pulled 35K over pick up and pulled assembly frae. 12:30 - 15:30 3.00 STWHIP TGHT LNR1 Pulled out of hole slowly and recovered whipstock assembly. Stood back MWD and laid out 2 bottom mills. 15:30 - 19:00 3.50 STWHIP TGHT LNR1 Made up Muleshoe on bottom of 6.150" OD watermelon mill and ran in hole. Reamed and worked mill through tight spot at 2400'. Continued running in hole to 8286'. 19:00 - 20:30 1.50 STWHIP TGHT LNR1 Circ sweep 20:30 - 23:00 2.50 STWHIP TGHT LNR1 Trip out w/mill 23:00 - 00:00 1.00 STWHIP LNR1 Pick up whipstock and Tripping in 10126/2000 00:00 - 04:30 4.50 STWHIP TGHT LNR1 Surface test MWD. Ran in hole slowly with whipstock assembly to 8286'. 04:30 - 05:00 0.50 STWHIP LNR1 Broke circulation and oriented whipstock to high side. Set whipstock and confirmed latch. Whipstock orientation 9 degrees to the left. PUW 96K SOW 75K. Printed: 11/28/2000 8:49:37 AM (" (' RECEIVED BP EXPLORATION FEB 1 4 2001~age 6 of 8 Operations Summary Report Aiaska0il&OasCons. Commission Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: N^BORS 4ES Rig Number: .. . ,. Sub Date From-To Hours Task Code Phase Description of Operations 10126~2000 04:30 - 05:00 0.50 STWHIP LNR1 05:00 - 09:30 4.50 STVVHIP LNR1 Milled window from 8264'-8276'. Milled formation from 8276'-8290'. 09:30 - 10:00 0.50 STWHIP LNR1 Reamed through window until window was clean. Worked through window without rotary and pump. Good window. 10:00 - 11:00 1.00 STWHIP LNR1 Pulled above whipstock and pumped weighted high vis sweep. Circulated hole clean. 11:00 - 16:30 5.50 STWHIP LNR1 Trip out, lay down BHA. 16:30 - 19:00 2.50 DRILL LNR1 Pick up new BH^ 19:00 - 21:30 2.50 DRILL LNR1 Tripping in to 8157 21:30 - 22:00 0.50 DRILL LNR1 Service rig 22:00 - 23:30 1.50 DRILL LNR1 Rig repair (change out saver sub 3 1/2) 23:30 - 00:00 0.50 DRILL LNR1 Oriented BHA and slide thru whipstock window (no problems) 10/27/2000 00:00 - 00:00 24.00 DRILL LNR2 Drlg & slide 8290-9872 10/2812000 00:00 - 03:30 3.50 DRILL LNR2 Rotate and slide from 9872'-10157'. PUW 100K, SOW 70K, Rot WT 82K, 70 RPM @ 7000 ftlbs, 250 gpm at 2650 psi. 03:30 - 04:30 1.00 DRILL LNR2 Pumped high vis weighted sweep and circulated hole clean. 04:30 - 06:00 1.50 DRILL LNR2 !Tripping out to 8253 06:00 - 07:00 1.00 DRILL LNR2 Cut drlg line 07:00 - 07:30 0.50 DRILL LNR2 Rig service 07:30 - 08:30 1.00 DRILL LNR2 Tripping back to bottom 08:30 - 21:00 12.50 DRILL LNR2 Rotate and slide from 10,157 to 10867. PUW 100K, SOW 70K, Rot WT 82K, 70 RPM @ 7000 ftlbs, 250 gpm at 2650 psi. drilling shale 10700-10867 21:00 - 21:30 0.50 DRILL LNR2 pull out to 10250 21:30 - 00:00 2.50 DRILL SURV LNR2 open hole side track,cutting ditch from 10250 to 10300 10/29/2000 00:00 - 11:30 11.50 DRILL SURV LNR2 Rotate and slide from 10291'-11,114'. Drilled shale from 10775'-11,114'. PUW 98K SOW 72K Rot WT 86K, 50 RPM at 6500 ftlbs, 240 gpm at 2700 psi. 11:30- 13:00 1.50 DRILL SURV LNR2 Pulled out of hole to 10,000' for open-hole sidetrack. 13:00 - 15:30 2.50 DRILL SURV LNR2 Trough from 10035'-10100' with oriented to the Iow side. 15:30 - 20:00 4.50 DRILL I SURV LNR2 Drlg Rotate and slide, new hole 10046 to 10253 PUW 98K SOW 72K Rot WT 86K, 240 gpm at 2700 psi. 20:00 - 21:00 1.00 DRILL SURV LNR2 circ, sweep 21:00 - 23:30 2.50 DRILL SURV LNR2 short trip to whipstock~} 8264 back to bottom (no problems) 23:30 - 00:00 0.50 DRILL SURV LNR2 Drlg Rotate and slide, new hole 10253 to 10348 PUW 98K SOW 72K Rot WT 86K, 240 gpm at 2700 psi. 10130/2000 00:00 - 06:30 6.50 DRILL SURV LNR2 Drlg to 10827 displace new mud 06:30 - 07:00 0.50 DRILL LNR2 Circ. 07:00 - 22:30 15.50 DRILL LNR2. Drlg Rotate and slide, new hole 10827 to 11879 PUW 102K SOW 65K Rot WT85K, 240 gpm at 2700 psi. 22:30 - 23:30 1.00 DRILL LNR2 Circ. sweep 23:30 - 00:00 0.50 DRILL LNR2 Short trip to 9900 10/31/2000 00:00 - 05:30 5.50 DRILL LNR2 Drill & slide fl 11880' to 12114'. Encountered shale at 12020'. 05:30 - 08:00 2.50 DRILL LNR2 Pump 25 bbl weighted HiVis sweep, circulate hole clean Printed: 11/28/2000 8:49:37 AM L,,I'" I V I" LJ BP EXPLORATION Page 7 of 8 Operations Summary Report FEB 1 4 Z001 Alask_~ 0!! & Gm C~_~. C_.~..m!?_!~ Legal Well Name: MPJ-224 Anchorage Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: N^BORS 4ES Rig Number: SUb Date From-To Hours Task Code Phase Description of Operations 10131/2000 08:00 - 12:30 4.50 DRILL LNR2 Pump out of hole fl 12114' to 8253'. 12:30 - 13:30 1.00 DRILL LNR2 Drop multishot, TIH to 8728'. 13:30- 17:00 3.50 DRILL LNR2 POOH 17:00 - 19:00 2.00 DRILL LNR2 Download MWD, LD BHA 19:00 - 22:30 3.50 DRILL LNR2 Pull wear bushing, test BOP. Test all rams, annular, lines, valves and all related equipment to 250 psi Iow and 2000 psi high. Low psi tests held 5 minutes, high psi tests held 10 minutes. All tests good. Witness of tests waived by Jeff Jones of AOGCC on 10131/2000. Tested choke manifold while POOH. Install wear bushing. 122:30 - 23:30 1.00 DRILL LNR2 Pick up 6 1/8" porcupine hole opener assembly. 23:30 - 00:00 0.50 DRILL LNR2 TIH to 2000' at 00:00 hrs. 1111/2000 00:00 - 02:00 2.00 DRILL LNR2 ~ TIH wi 6 118" hole opener. 02:00 - 03:00 1.00 DRILL LNR2 Slip & cut drilling line 03:00 - 03:30 0.50 DRILL LNR2 TIH to 8350'. Bottom of window at 8276', top stab 5' below window. 03:30 - 15:30 12.00 DRILL LNR2 Wash & ream w/hole opener f/8350' to 12112'. 120 rpm, 8000 ft-lbs, 299 gpm @ 2900 psi. 15:30 - 17:00 1.50 DRILL LNR2 Pump 11.0 ppg HiVis sweep and circ hole clean 17:00 - 20:00 3.00 DRILL LNR2 POOH to 8200' 20:00 - 20:30 0.50 DRILL LNR2 Drop & pump down multishot survey 20:30 - 22:00 1.50 DRILL LNR2 TIH to 12112' 22:00 - 23:30 1.50 DRILL LNR2 Pump 20 bbl HiVis sweep around. Displace open hole w/150 bbl new mud. 23:30 - 00:00 0.50 DRILL LNR2 Pump out of hole to prevent swabbing. 11650' at 00:00 hrs. 11/2/2000 00:00 - 02:30 2.50 DRILL LNR2 Continue POOH to 7" casing 02:30 - 03:30 1.00 DRILL LNR2 Circ & spot 70 bbl mud mixed w/8 drums of EP Mudlube in 7" casing 03:30 - 06:00 2.50 DRILL LNR2 POOH, record PU, SO & ROT wts & tq every 5 stds 06:00 - 07:00 1.00 DRILL LNR2 POOH, LD BH^ 07:00 - 08:00 1.00 DRILL LNR2 RU to run liner 08:00 - 08:30 0.50 DRILL ~LNR2 PJSM on running liner 08:30 - 11:00 2.50 DRILL LNR2 RIH wi 94 its of 4 1/2", 12.6~, slotted IBT casing 11:00 - 11:30 0.50 DRILL LNR2 RU to run inner string. PJSM on running inner string 11:30 - 16:00 4.50 DRILL LNR2 Run 2 7/8" inner string, space out and MU Baker HR running tool. 16:00 - 16:30 0.50 DRILL LNR2 Circ liner volume, 300 gpm, 650 psi 16:30 - 20:00 3.50 DRILL LNR2 RIH w/liner on 3 1/2" drillpipe recording PU/SO every 5 stands. Circ & wash through bridge ~ 8839'. Continue RIH w/minor problems. 20:00 - 21:00 1.00 DRILL LNR2 Drop ball, pump down and release liner. Shear ball seat {~ 4200 psi. TOL ~ 8284' = 8' below window, shoe {~ 11986'. 21:00 - 00:00 3.00 DRILL LNR2 . Pump slug, POOH. Hole not taking proper fill. Pump out of hole to 7" casing. 1113/2000 00:00 - 00:30 0.50 DRILL LNR2 Continue POOH to window 00:30 - 02:00 1.50 DRILL LNR2. POOH to 2 7~8" inner string 02:00 - 06:00 4.00 DRILL LNR2 POOH laying down inner string 06:00 - 07:00 1.00 DRILL LNR2 PJSM, PU whipstock retreiving tool and orient BHA 07:00 - 11:00 4.00 DRILL LNR2 TIH, test MWD - OK 11:00 - 12:30 1.50 DRILL LNR2 Orient wi MWD, make hookup on whipstock, pull free wi 35000 lbs, did not jar, circ bottoms up 12:30 - 18:00 5.50 DRILL LNR2 Slug, POOH w/whipstock 18:00 - 18:30 0.50 DRILL LNR2 Clear rig floor, safety meeting 18:30 - 20:30 2.00: DRILL LNR2 TIH w/DC, HWDP and excess drillpipe 20:30 - 21:30 1.00 DRILL LNR2 Cut drill line 21:30 - 00:00 2.50 DRILL LNR2 POOH laying down 1114/2000 00:00 - 01:00 1.00 DRILL LNR2 Continue laying down excess drillpipe and BHA Printed: 11/28/2000 8:49:37 AM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task 'Sub ......... 'Code Phase Description of Operations 111412000 01:00 - 03:00 2.00 DRILL LNR2 RIH open ended to 8250' 03:00 - 04:30 1.50 DRILL LNR2 Displace hole to 9.1 ppg brine, Pumping 420 gpm 3000 psi, rotating 120 rpm. - Final return brine 150 ntu 04:30 - 05:00 0.50 DRILL LNR2 Observe well, PJSM, clean spillways, pump slug 05:00 - 11:30 6.50 DRILL LNR2 POOH laying down 3 112" drillpipe 11:30 - 12:30 1.00 DRILL ~ LNR2 Pull wear bushing, clear floor 12:30 - 13:00 0.50 DRILL I LNR2 Service rig & top drive 13:00 - 20:00 7.00 DRILL LNR2 Run 258 jts of 2 7/8", 6.5~, EUE mod tubing to 8146'. 20:00 - 21:30 1.50 DRILL LNR2 Make up FMC 10 x 3?" Schrader Bluff Producer tubing hanger w/TWC and land same. Run in locking pins. Test TWClhangerlmanual valve from top to 1000 psi for 10 min. Test TWC from below to 200 psi for 10 min. 21:30 - 23:30 2.00 DRILL LNR2 ND BOP 23:30 - 00:00 0.50 DRILL LNR2 NU FMC 3 118" 5K Horizontal tree 11/5/2000 00:00 - 00:30 0.50 DRILL LNR2 Test Fmc tubing hanger pack-off to 5000 psi - Shell test Fmc 3 1/8" 5k Horizontal tree to 5000 psi - ok - Torqued lock down screw on hanger to 500 fi/lbs 00:30 - 01:30 1.00 DRILL LNR2 Pull two way check valve with dry rod - Rig up lines - Pump 7 bbls of diesel down annulus with HB&R hot oil truck - Allow Diesel to U-Tube to Tubing side - Freezed protected Tubing and annulus to 194' below ground level - SITP 0 - SICP 0 01:30 - 02:30 1.00 DRILL LNR2 Rig up Lubricator - Set ClW 3" type 'H' BPV - Secure Well - Rig Released at 0230 111512000 11122/2000 00.'00 - 01:00 1.00 WHSUI~ COMP N/U X-MAS TREE. TEST HANGER & TREE TO 5000 PSI, OK. 01:00 - 01:30 0.50 WHSUR COMP PULL '[WC & INSTALL BPV. 01:30 - 02:00 0.50 WHSUI~ COMP SECURE WELL, CLEAN CELLAR. RELEASE RIG ~ 0200 HRS, 11-22-00. 02:00 - 04:30 2.50 MOB COMP RIG DOWN. 04:30 - 06:00 1.50 MOB COMP MOVE TO L-40. RECEIVED FEB 1 4 ZOO1 Alaska 0ii & Gas Cons. Commission Anchorage Printed: 11/28/2000 8:49:37 AM BP EXPLORATION Page I of 1 Operations Summary Report 'Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/9/2000 Event Name: COMPLETION Start: 11/20/2000 End: Contractor Name: NABORS Rig Release: 11/2212000 Group: RIG Rig Name: NABORS 4ES Rig Number: Sub Date From-To Hours .Task Code Phase Description of Operations 11/2012000 06:00 - 11:00 5.00 MOB PRE Scope and Lower Derrick. Move Rig from MPU J-06 to MPU J-224. Spot and Berm Rig & Tiger Tank. Hook Up Lines between Tiger Tank 11:00 - 14:00 3.00 MOB PRE Hook Up Lines Between Modules. Raise and Scope Up Derrick. Take on 9.1 ppg Fluid. Rig accepted at 14:00 Hrs. 11-20-00 14:00 - 16:30 2.50 PULL COMP Hook Up Lines to well, Pull BPV, with Lubricator, Test Surface lines to 3,000 psi. 16:30 - 20:00 3.50 KILL COMP Opened wellbore to record pressures 50 psi on TBG and 50 psi on CSG. Pumped down annulus to circulate diesel out of tubing. Shut down and pumped down tubing and circulated diesel out of annulus to Tiger Tank. With 9.1 ppg returns switched over to pits and circulated well all the way around with 9.1 ppg brine. 20:00 - 20:30 0.50 KILL COMP Monitor well for flow. Annulus and Tubing on vacuum 20:30 - 21:00 0.50 PULL COMP Set TWCV and test to 2,500 psi 21:00 - 23:00 2.00 WHSUR COMP Nipple down Tree and reposition Valves on Horizontal Tree. 23:00 - 00:00 1.00 WHSUR COMP Nipple Up BOP equipment 11/21/2000 00:00 - 02:00 2.00 KILL COMP NU BOPE and Change Shear Rams to Blind Ram 02:00 - 03:00 1.00 BOPSUFi COMP Body test BOP E to 250~3500 psi and 2500 annular 03:00 - 04:30 1.50 WHSUR COMP Pull TWCV w/Lubricator MU Land JT. BOLDS Pull Hanger/LD Land JT 04:30 - 08:30 4.00 PULL COMP Pulled out of the Hole with 2 7/8" tuning. Pulled in Stands and strap tubing 08:30 - 10:00 1.50 RUNCOI~! COMP Clear rig floor. Prepare to run ESP. 10:00 - 12:30 2.50 RUNCOI~! COMP Make up & service ESP. 12:30 - 16:30 4.00 RUNCOI~I COMP Run ESP & completion assy. 16:30 - 18:30 2.00 RUNCOI~! COMP Make mid-run cable splice {~ 7278'. 18:30- 19:30 1.00 RUNCOI~! COMP Run in hole wi completion assy. 19:30 - 20:00 0.50 RUNCOI~! COMP Make up hanger & P/U landing it. 20:00 - 21:30 1.50 RUNCOI~I COMP Make hanger connection splice & connect to hanger. 21:30 - 22:00 0.50 RUNCOI~I COMP Land Tbg Hgr & RILDS. 22:00 - 22:30 0.50 RUNCOI~I COMP L/D landing it. & set TWC. Test to 2500 psi, OK. 22:30 - 00:00 1.50 BOPSUI~ COMP Niple down BOPE. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Printed: 11/28/2000 8:49:53 AM North Slope Alaska Alaska State Plane 4 Milne Point MPJ MPJ-224 Job No. AKMM00220, Surveyed: 21 October, 2000 SURVEY REPORT 15 November, 2000 Your Ref: API-500292297600 Surface Coordinates: 6015110.45 N, 551914.26 E (70° 27' 07.2878" N, 210° 25' 24.9148" E) Kelly Bushing: 66.05ft above Mean Sea Level A Htlllburton Company Survey Reft svy9637 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (fi) Sperry-Sun Drilling Services Vertical Depth (ft) 0.00 0.000 0.000 -66.05 0.00 113.99 0.050 153.270 47.94 113.99 205.65 0.180 153.270 139.60 205.65 296.07 0.160 212.940 230.02 296.07 326.16 0.620 256.790 260.11 326.16 353.47 445.84 536.72 629.90 719.99 419.57 2.940 278.040 512.21 5.650 276.730 603.80 8.540 288.710 698.34 10.890 295.670 790.55 13.700 297.540 Survey Report for MPJ-224 Your Ref: API-500292297600 Job No. AKMM00220, Surveyed: 21 October, 2000 882.22 16.300 296.270 808.53 974.86 18.780 292.760 896.86 1067.02 21.990 289.230 983.24 1161.98 24.620 292.070 1070.45 1254.82 28.140 290.480 1153.61 419.52 511.89 602.77 695.95 786.04 874.58 962.91 1049.29 1136.50 1219.66 1346.77 31.830 290.030 1233.24 1299.29 1439.08 35.600 288.790 1310.01 1376.06 1531.34 36.640 290.020 1384.53 1450.58 1624.21 40.690 288.110 1457.03 1523.08 1717.86 42.090 289.350 1527.29 1593.34 1809.63 44.880 289.230 1593.87 1659.92 1906.01 46.300 291.660 1661.32 1727.37 1997.65 48.370 291.570 1723.42 1789.47 2089.69 49.880 290.780 1783.65 1849.70 2182.72 51.000 290.990 1842.90 1908.95 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00N 0.00 E 6015110.45 N 551914.26 E 0.04S 0.02E 6015110.41N 551914.28 E 0.21S 0.11E 6015110.24N 551914.37E 0.44S 0.10 E 6015110.01N 551914.36E 0.51S 0.08W 6015109.94 N 551914.18 E 0.29 S 2.95W 6015110.14 N 551911.32 E 0.57 N 9.83W 6015110.95 N 551904.43 E 3.28 N 20.75W 6015113.59 N 551893.49 E 9.40 N 35.45W 6015119.61N 551878.75E 18.23 N 52.99W 6015128.31N 551861.15 E 28.94 N 74.15W 6015138.88 N 551839.91 E 40.47N 99.56W 6015150.22 N 551814.42 E 51.89 N 129.54W 6015161.44N 551784.36 E 65.18 N 164.67W 6015174.49 N 551749.14 E 80.12 N 203.11W 6015189.15 N 551710.59 E 96.01N 246.22W 6015204.74N 113.01N 294.54W 6015221.41N 131.09 N 345.83W 6015239.12 N 149.99 N 400.67W 6015257.65 N 169.88 N 459.30W 6015277.13 N 190.74 N 518.91W 6015297.57N 214,80 N 583.40W 6015321.18 N 239.62 N 646.05W 6015345.57N 264.76 N 710.94W 6015370.25 N 290.32 N 777.95W 6015395.35 N 551667.38 E 551618.94 E 551567.52 E 551512.55 E 551453.78 E 551394.04E 551329.38 E 551266.56 E 551201.49E 551134.31E Dogleg Rate (°/lOOft) 0.04 0.14 0.19 1.72 2.54 2.93 3.53 2.77 3.08 2.86 2.91 3.73 3.01 3.87 4.02 4.15 1.37 4.55 1.73 3.04 2.33 2.26 1.76 1.22 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment o.0o -0.03 -0.15 -0.21 -0.05 2.77 9.65 20.90 36.68 55.88 79.08 106.59 138.49 175.85 216.83 262.56 313.62 367.83 425.67 487.44 550.39 618.89 685.79 754.95 826.26 Continued... 15 November, 2000.14:08 - 2- DrillQuest 2.00.02 North Slope Alaska Meaaured Depth Incl. Azim. Sub-Sea Depth (fi) Sperry-Sun Drilling Services Vertical Depth (fi) 2275.12 55.120 292.720 1898.42 1964.47 2366.62 59.530 294.200 1947.81 2013.86 2460.59 63.630 291.820 1992.53 2058.58 2553.35 67,070 294.460 2031.22 2097.27 2647.32 70.110 293.390 2065.52 2131.57 2766.56 69,670 294.070 2106.51 2172.56 2859.34 70.370 291,710 2138.22 2204.27 2952.14 72.190 293.440 2168.00 2234.05 3043.09 72.260 290.950 2195.77 2261.82 3131.14 71.980 287.160 2222.82 2288.87 3226.20 71.170 287.290 2252.86 2318.91 3318.63 70.340 287.250 2283.33 2349.38 3415.67 71.340 289.170 2315.18 2381.23 3505.33 71.890 290.040 2343.46 2409.51 3598.30 69,400 291.400 2374.27 2440.32 Survey Report for MPJ-224 Your Ref: API.500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 3690.38 69,080 290.490 2406.91 2472.96 3783.66 70,700 290,600 2438,98 2505.03 3872.98 73.750 291,510 2466.24 2532.29 3971.05 72.920 291.720 2494.37 2560.42 4060.26 72.340 292.160 2521.00 2587.05 4156.33 72.120 292.000 2550.32 2616.37 4250.64 71.270 292.360 2579.94 2645.99 4343.26 71.130 292.980 2609.79 2675.84 4435.02 71.140 292.950 2639.46 2705.51 4530.50 71.380 290.420 2670.14 2736.19 Local Coordinates Global Coordinates Northings Fastings Northings Fastings (ft) (ft) (ft) (ft) 317.84 N 846.46W 6015422.38 N 551065.60 E 348.51N 917.09W 6015452.57 N 550994,77 E 380.78 N 993.14W 6015484.30 N 550918.49 E 413.92 N 1070.64W 6015516.91N 550840.77E 449.39 N 1150.60W 6015551.81N 550760.56 E 494.45 N 1253.10W 6015596.16 N 550657.74 E 528.36 N 1333.42W 6015629.51N 550577.19 E 562.10 N 1414.57W 6015662.68N 550495.81E 594.82 N 1494.75W 6015694.84 N 550415.40 E 622,17 N 1573.94W 6015721.64N 550336.02E 648.88 N 1660.08W 6015747.74 N 550249.70 E 674.78 N 1743.41W 6015773,07N 550166.19 E 703.43 N 1830.48W 6015801.11N 550078.92 E 731.98 N 1910.63W 6015829.10 N 549998.58 E 763.00 N 1992,67W 6015859.55 N 549916.33 E 793.78 N 2073.08W 6015889.77N 549835.70 E 824.52 N 2155.10W 6015919.94N 549753.47 E 855.08 N 2234.46W 6015949.94 N 549673.90 E 889.69N 2321.80W 6015983.94 N 549586.31E 921.50 N 2400.78W 6016015.20 N 549507.12 E 955.89 N 2485.56W 6016049.00 N ' 549422.11 E 989.69N 2568.47W 6016082.22 N 549338.96 E 1023.48 N 2649.37W 6016115.45N 549257.82 E 1057.36N 2729,32W 6016148.77N 549177.64E 1090.77N 2813.33W 6016181.59 N 549093.40 E Dogleg Rate (°/lOOft) 4.70 5.01 4.90 4.52 3.40 0.65 2.51 2.64 2.61 4,11 0.86 0,90 2,13 1.11 3,01 0,99 1.74 3.55 0.87 0.80 0.28 0.97 0.65 0.03 2.52 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 899,52 975.63 1057.4o 1140.79 1227.15 1337.75 1424.06 1511.13 1597.Ol 1680,55 1770.65 1857.83 1949.33 2o34.11 2121.34 2206.94 2294.09 2378.62 2471.90 2556.38 2647.12 2735.91 2822.75 2908.70 2998.45 Continued... 15 November, 2000 - 14:08 - 3 - DrillQuest 2.00.02 Sperry-Sun Drilling Services , Survey Report for MPJ-224 Your Ref: AP1-500292297600 Job No. AKMM00220, Surveyed: 21 Ootober, 2000 North Slope Alaska Measured Depth (fi) Incl. Azlm. Sub-See Depth (fi) 4623.38 71.420 290.970 2699.76 4716.35 71.420 291.070 2729.38 4809.08 73.900 290.090 2757.02 4902.00 74.620 290.500 2782.23 4994.52 74.940 289.680 2806.52 5087.17 74.680 289.380 2830.79 5179.87 75.190 289.880 2854.89 5272.52 75.420 289.850 2878.39 5363.82 73.590 289.590 2902.78 5458.01 73.750 289.510 2929.26 5550.44 73.290 289.150 2955.48 5644.59 73.180 289.390 2982.64 5733.91 74.140 288.670 3007.77 5829.02 74.930 289.320 3033.13 5920.67 73.200 289.000 3058.29 6017.13 70.910 288.770 3088.01 6109.87 70.560 288.430 3118.61 6202.53 70.160 287.950 3149.75 6295.01 70.550 287.780 3180.84 6387.68 71.730 287.590 3210.80 6479.95 72.160 287.750 3239.40 6571.52 71.970 288.940 3267.60 6666.66 72.590 288.670 3296.55 6759.45 72.440 290.740 3324.43 6862.02 73.050 290.590 3351.89 Vertical Local Coordinates Global Coordinates Depth Northlngs Eastings Northings Fastings (ft) (ft) (ft) (ft) (ft) 2765.81 1121.88 N 2895.68W 6016212.12 N 549010.83 E 2795.43 1153.49 N 2977.94W 6016243.16 N 548928.36 E 2823.07 1184.59 N 3060.80W 6016273.69 N 548845.28E 2848.28 1215.61N 3144.68W 6016304.13 N 548761.18 E 2872.57 1246.28N 3228.53W 6016334.21N 548677.13 E 2896.84 1276.17 N 3312.79 W 6016363.51 N 548592.66 E 2920.94 1306.24 N 3397.11 W 6016392.99 N 548508.14 E 2944.44 1336.69 N 3481.39 W 6016422.86 N 548423.64 E 2968.83 1366.38 N 3564.21 W 6016451.97 N 548340.62 E 2995.31 1396.63 N 3649.39 W 6016481.62 N 548255.23 E 3021.53 1425.97N 3733.02W 6016510.37N 548171.39 E 3048.69 1455.72N 3818.12W 6016539.53 N 548086.09 E 3073.82 1483.66 N 3899.15W 6016566.91N 548004.87 E 3099.18 1513,50 N 3985.82W 6016596.14 N 547917,99 E 3124.34 1542.42N 4069.07W 6016624.49 N 547834.55 E 3154.06 1572.13 N 4155,89W 6016653.58 N 547747.52E 3184.66 1600.05 N 4238.86W 6016680.93 N 547664.36 E 3215.80 1627.29 N 4321.77W 6016707.59 N 547581.26 E 3246.89 1654,01N 4404.67W 6016733.73N 547498.18 E 3276.85 1680.65 N 4488.21W 6016759.79 N 547414.45 E 3305.45 1707.28 N 4571.80W 6016785.84N 547330.68 E 3333.65 1734.70 N 4654.49W 6016812.68 N 547247.79 E 3362.60 1763.91N 4740.28W 6016841.29 N 547161.81E 3390.48 1793.75N 4823.60W 6016870.55 N 547078.28 E 3417.94 1824.95 N 4906.31W 6016901.17 N 546995.35 E Dogleg Rate (°/100fi) 0.56 0.10 2.86 0.88 0.92 0.42 0.76 0.25 2:02 0.19 0.62 0.27 1.32 1.06 1.92 2.38 0,51 0.65 0.46 1.29 0.49 1.25 0,71 2.13 0.68 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 3086.01 3173.61 3261.66 3350.68 3439.57 3528.68 3617.87 37o7.13 3794.78 3884.86 3973.21 4063.08 4148.55 4239.97 4327.84 4419.36 4506.71 4593.82 4680.79 4768.37 4855.99 4942.94 5033,34 5121.51 5209.44 m Continued... 15 November, 2000 - 14:08 - 4 - - DriilQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Ref: API.500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Meaaured Depth Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (fi) 6945.04 73.990 290.380 3378.28 3444.33 7037.55 72.180 290.590 3405.20 3471.25 7130.79 72.600 290.620 3433.40 3499.45 7223.34 72.080 290.270 3461.48 3527,53 7315.26 72.990 290.880 3489.07 3555.12 7408.53 71.560 292.170 3517.46 3583.51 7500.59 71.850 293.100 3546.36 3612.41 7593.74 71.490 292.720 3575.66 3641.71 7686.62 70.660 294.510 3605.78 3671.83 7779.33 71.780 294.630 3635.63 3701.68 7872.44 69.780 294.450 3666.28 3732.33 7965.03 71.420 295.340 3697.03 3763.08 8057.77 71.310 296.040 3726.67 3792.72 8150.51 71.760 292.880 3756.05 3822.10 8242.58 74.150 290.720 3783.04 3849.09 8336.58 78.190 289.490 3805.50 3871.55 8428.55 78.230 286.020 3824.30 3890.35 8496.52 79.140 283.230 3837.64 3903.69 8522.29 80.730 282.690 3842.14 3908.19 8555.50 83.310 281.100 3846.75 3912.80 8586.61 85.690 280.780 3849.73 3915.78 8614.79 86.960 278.960 3851.54 3917.59 8623.57 87.050 278.540 3852.00 3918.05 8702.71 88.830 280.690 3854.84 3920.89 8735.22 89.940 281.200 3855.19 3921.24 Local Coordinates Global Coordinates Northings Eaatings Northings Eastings (ft) (ft) (ft) (fi) 1856.16 N 4989.87W 6016931.80 N 546911.58 E 1887.13 N 5072.78W 6016962.20N 546828.46 E 1918.41N 5155.96W 6016992.89 N 546745.06 E 1949.22N 5238.59W 6017023.12 N 546662.21 E 1980.03N 5320.68W 6017053.36 N 546579.91 E 2012.62N 5403.33W 6017085.38 N 546497.04E 2046.26N 5484.00W 6017118.46N 546416.14 E 2080.68 N 5565.45W 6017152.31 N 546334.45 E 2115.87N 5645.94W 6017186.94 N 546253.71E 2152.37N 5725.7'/W 6017222.88 N 546173.63 E 2188.88 N 5805.74W 6017258.83 N 546093.41E 2225.65 N 5884.96W 6017295.05 N 546013.94 E 2263.74N 5964.15W 6017332.59 N 545934.49E 2300.16 N 6044.21W 6017368.44N 545854.17 E 2332.83 N 6125.93W 6017400.55 N 545772.23 E 2364.19 N 6211.63W 6017431.31N 545686.31 E 2391.64N 6297.35W 6017458.16 N 545600.40 E 2408.47N 6361.84W 6017474.54 N 545535.80 E 2414.16 N 6386.56W 6017480.05 N 545511.03 E 2420.93 N 6418.74W 6017486.61N 545478.81 E 2426.81N 6449.14W 6017492.27 N 545448.37E 2431.63N 6476.85W 6017496.90 N 545420.63E 2432.96 N 6485.51W 6017498.17 N 545411.95 E 2446.17 N 6563.48W 6017510.84 N 545333.89 E 2452.35 N 6595.40W 6017516.79 N 545301.94 E Dogleg Rate (°/lOOft) 1.03 1.97 0.45 0.67 1.18 2.02 1.01 0.55 2.03 1.21 2.16 1.99 0.72 3.27 3.43 4.48 3.69 4.24 6.51 9.10 7.72 7.86 4.89 3.53 3.76 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 5298.20 5386.26 5474.67 5562.43 5649.66 5737.88 5824.46 5912.0o 5998.81 6085.30 6171.94 6257.91 6344.19 6430.89 6518.24 6609.10 6699.00 6765.64 6791.oo 6823.84 6854.73 6882.75 6891.47 6970.23 7002.67 rtl Continued... 15 November, 2000 - 14:08 - 5 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Ref: API.500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (it) Incl. Azim. Sub-Sea Depth (it) Vertical Depth (ft) 8765,83 90,000 280,650 3855,21 3921.26 8797.53 90.250 280.510 3855.14 3921.19 8831.67 90.000 279.600 3855.07 3921.12 8859.77 90.180 278.400 3855,02 3921.07 8894.67 90.310 275.700 3854.87 3920.92 8928.39 90.120 275.710 3854,75 3920.80 8956.92 89.940 274.870 3854,73 3920.78 8990.45 90.000 273,000 3854,75 3920.80 9022.27 90.180 271.940 3854,70 3920.75 9053.44 90.740 270.100 3854.45 3920.50 9086.22 91.360 268.780 3853.85 3919.90 9118,92 90.860 268.350 3853.21 3919.26 9148.45 89.020 268.010 3853.24 3919.29 9182,28 89.080 265,870 3853,81 3919.86 9216.32 89.510 263.550 3854.22 3920.27 9245.62 89.380 263,720 3854.51 3920.56 9277.41 89.690 264,130 3854.77 3920.82 9309.89 89.570 263,290 3854.98 3921.03 9339,80 89.260 263,460 3855.28 3921.33 9374.48 88.710 262,670 3855.90 3921.95 9406.02 90,250 262,190 3856,18 3922.23 9434.84 90.680 263,530 3855.95 3922.00 9469.42 92.030 263,070 3855.13 3921.18 9501.90 92,030 263,380 3853.98 3920.03 9529.56 91.910 263.680 3853.03 3919.08 Local Coordinates Global Coordinates Northinga Eaatings Northings Eastings (ft) (ft) (ft) (it) 2458.15 N 6625.45W 6017522.38 N 545271.84 E 2463.97N 6656.62W 6017527.98 N 545240.64 E 2469.93N 6690.23W 6017533.71N 545206.98 E 2474.32N 6717.98W 6017537.91N 545179.20 E 2478.61N 6752.62W 6017541.95N 545144.54 E 2481.96 N 6786.17W 6017545,07N 545110.96 E 2484.59 N 6814.58W 6017547.50 N 545082.54 E 2486.89 N 6848.03W 6017549.57N 545049,07E 2488.26 N 6879.82W 6017550.72N 545017.27E 2488.82 N 6910.98W 6017551.06 N 544986,11E 2488.50 N 6943.75W 6017550.51N 544953.34E 2487.68 N 6976.44W 6017549.46 N 544920,66 E 2486.74 N 7005.95W 6017548.32N 544891,16 E 2484.93 N 7039.72W 6017546.28N 544857.39 E 2481,80 N 7073.61W 6017542.90 N 544823.53 E 2478.55 N 7102.73 W 6017539.45 N 544794.43 E 2475,18 N 7134,34 W 6017535.87 N 544762.85 E 2471.62 N 7166.63 W 6017532.09 N 544730.59 E 2468,17 N 7196.34 W 6017528.43 N 544700,90 E 2463.99 N 7230.76 W 6017524.00 N 544666,51 E 2459.83 N 7262.02 W 6017519,63 N 544635.28 E 2456.25 N 7290.61 W 6017515.85 N 544606.71 E 2452.22 N 7324,95 W 6017511.58 N 544572.41 E 2448.39 N 7357,18 W 6017507.52 N 544540.20 E 2445.27 N 7384.65 W 6017504.22 N 544512.76 E Dogleg Rate (°/100it) 1.81 0.90 2.76 4.32 7.75 0.56 3.01 5.58 3.38 6,17 4.45 2.02 6.34 6.33 6.93 0.73 1.62 2.61 1.18 2.78 5.11 4.88 4.12 0.95 1.17 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 7o33.21 7064.82 7098.85 7126.81 7161.39 7194.68 7222.82 7255.75 7286.84 7317,12 7348.73 738o.12 74o8.42 7440.62 7472.59 7499.92 7529.62 7559.93 7587.78 7620.00 7649.17 7675.90 7708.08 7738.27 7764.03 m Continued.,, 15 November, 2000.14:08 - 6 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Ref: API-500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth Vertical Depth (ft) 9564.16 91.480 262.830 3852.01 3918.06 9596.43 92,220 262.360 3850,96 3917.01 9629.56 92.030 262.530 3649.74 3915.79 9660.78 91.780 262.500 3848.70 3914.75 9693.14 91.540 262.530 3847.76 3913.81 9722.16 92.030 264.200 3846.86 3912.91 9756.29 92.030 265.660 3845.65 3911.70 9788.90 91.780 267.210 3844.56 3910.61 9816.91 91.420 268,850 3843.78 3909.83 9851.26 91.790 270.460 3842.82 3908.87 9883,67 91.660 271.440 3841.84 3907.89 9912.53 91.290 272.260 3841.10 3907.15 9947.69 91.110 272.620 3840.36 3906.41 9980.45 92.280 272.840 3839.39 3905.44 10007.05 92.590 272.140 3838.26 3904.31 10039.32 91.540 273.260 3837.10 3903.15 10072.21 90.800 272.570 3836.43 3902.48 10101.83 90.180 271.810 3836.18 3902.23 10137.04 91.170 271.480 3835.76 3901.81 10169.42 91.600 271.030 3834.98 3901.03 10199.54 91,660 271.880 3834.12 3900.17 10231.80 91.230 272.290 3833.31 3899.36 10265.51 90.800 270.890 3832.71 3898.76 10293.92 89.820 270.530 3832.56 3898.61 10329.94 91.540 269.770 3832.13 3898.18 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft)' (fi) (ft) (ft) 2441.21 N 7418.99W 6017499.92 N 544478.44E 2437.05 N 7450.98W 6017495.54N 5~446.49 E 2432.70N 7483.80W 6017490.95 N 544413.70 E 2428.64N 7514~3W 6017486.67N 544382.79 E 2424.42N 7546.80W 6017482.24N 544350.75 E 2421.07N 7575.61W 6017478.69N 544321.96 E 2418.06N 7609.59W 6017475.43N 544288.01 E 2416.03N 7642.12W 6017473.18 N 544255.50 E 2415.07N 7670.10W 6017472.02N 544227.52 E 2414.86 N 7704.43W 6017471.58 N 544193.19 E ' 2415,40N 7736,82W 6017471.89 N 544160.80 E 2416.33 N 7765.66W 6017472.62N 544131.96 E 2417.83 N 7800.78W 6017473.87N 544096.83 E 2419.39N 7833.49W 6017475.20 N 544064.11E 2420.54N 7860.04W 6017476.17 N 544037.55 E 2422.06 N 7892.25W 6017477.47N 544005.33 E 2423.73 N 7925.09W 6017478.91 N 543972.48 E 2424.86 N 7954.69W 6017479.84 N 543942.87 E 2425.88 N 7989.88W 6017480.60 N 543907.67E 2426.58 N 8022.24W 6017481.09 N 543875.31E 2427.35 N 8052.34W 6017481.64N 543845.21 E 2428.52 N 8084.57W 6017482.59 N 543812.97 E 2429.46N 8118.26W 6017483.29 N 543779.27 E 2429.81N 8146.67W 6017483.44N 543750.86 E 2429.90 N 8182.68W 6017483.29 N 543714.85 E Dogleg Rate ("/lOOff) 2.75 2,72 0.77 0.81 0.75 5.99 4,28 4.81 5.99 4.81 3.05 3.12 1.14 3.63 2.88 4.76 3.08 3.31 2.96 1.92 2.83 1.84 4.34 3.67 5.22 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 7796.21 7826.07 7856.70 7885.58 7915.52 7942.52 7974,60 8005.54 8032.35 8065.50 8096.96 8125.o8 8159.42 8191.44 8217.41 8248.94 8281.13 831o.03 8344.32 8375.79 8405.09 8436.56 8469.37 8496.93 8531.78 ITl Continued,.. 15 November, 2000- 14:08 - 7- DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Reft API.500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) 10362.12 10389.52 10423.45 10455,75 10483.69 10520.10 10551.81 10581.57 10616.88 10649.20 Incl. 91.910 92.160 92.160 91.970 91.780 91.600 91.480 91.110 90.860 90.620 10677.97 10712.20 10745.19 1O773.57 10807.85 10840.37 10868.74 10904.54 10936.93 10964.91 90.370 91.410 91.540 91.480 91.360 91.170 91.110 91.850 91.720 91.420 90.920 92.830 92,150 90.920 90.550 10999.07 11031.51 11060.40 11095.08 11127.78 Azim. 269.900 269.910 269.740 269.150 269.500 269.340 269.230 268.460 268.510 268.260 268.300 269.200 27O.480 270.690 270.010 269.620 270.230 271,230 272.380 272,010 271,940 273.480 273,900 272.39O 271.760 Sub-Sea Depth (fi) 3831.16 3830.19 3828.91 3827.75 3826.83 3825.76 3824.91 3824.23 3823.63 3823.21 3822.96 3822.43 3821.58 382O.83 3819.98 3819.26 3818.70 3817.78 3816.77 3816.00 3815.30 3814.24 3812.99 3812.06 3811.64. Vertical Depth 3897.21 3896.24 3894.96 3893.80 3892.88 3891.81 3890.96 3890.28 3889.68 3889.26 3889.01 3888.48 3887.63 3886.88 3886.03 3885.31 3884.75 3883.83 3882.82 3882,05 3881.35 3880.29 3879.04 3878.11 3877.69 Local Coordinates Global Coordinates Northings Fastings Northings Fastings (ft) (ft) (ft) (ft) 2429.81 N 8214.85W 6017482.97N 543682.69 E 2429.77N 8242.23W 601748223 N 543655.30 E 2429.66 N 8276,13W 6017482.39N 543621.40 E 2429.35 N 8308.41W 6017481.86 N 543589.12 E 2429.02N 8336,33W 6017481.33 N 543561.20 E 2428.65N 8372~3W 6017480.71N 543524.82 E 2428.26N 8404.42W 6017480.10 N 543493.12 E 2427.66 N 8434.17W 6017479.29 N 543463.38 E 2426.72N 8469.46W 6017478.11N 543428.10 E 2425.81N 8501.77W 6017476.97N 543395.80 E 2424.95 N 8530.52W 6017475,91N 543367.05 E 2424.20 N 8564.74W 6017474.92 N 543332.84 E 2424.11N 8597.72W 6017474.60 N 543299.86 E 2424.40 N 8626.09W 6017474.69N 543271.49 E 2424,61N 8660.35W 6017474.67N 543237.22 E 2424150 N 8692.87W 6017474.33 N 543204.71 E 2424.47N 8721.23W 6017474,10 N 543176.35 E 2424,92N 8757,02W 6017474.31N 543140.56 E 2425.94 N 8789.37W 6017475.10 N 543108.20 E 2427,01N ' 8817.32W 6017475.98 N 543080.24 E 2428.19 N . 8851.45W 6017476.92N 543046.10 E 2429.72N 8883.84W 6017478.22N 543013.71E 2431.58 N 8912.64W 6017479.88 N 542984.90 E 2433.48 N 8947.25W 6017481.54 N 542950.27 E 2434.67 N 8979.g3W 6017482.50 N 542917.59 E Dogleg Rate (°/lOOft) 1.22 0.91 0.50 1.92 1.42 0.66 0.51 2.87 0.72 1.07 0.88 4.02 3.90 0.77 2.01 1.33 2.16 3.47 3.57 1.70 1.48 7.56 2.77 5.61 2.23 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 8562.86 8589.32 8622°o8 8653.21 8680.13 8715.23 8745.77 8774.38 8808.27 8839.28 8866.86 8899.76 8931.62 8959.13 8992.32 9023.73 9o51.15 9085.87 9117.41 9144.71 9178.02 9209.72 9238.05 9272.00 9303,90 rtl Continued,.. 15 November, 2000 - 14:08 - 8 - DrillQuest 2. 00. 02 Sperry-Sun Drifting Services Survey Report for MPJ-224 Your Ref: API,500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (fi) Vertical Depth (ft) 11156.03 90.990 271.750 3811.26 3877.31 11188.75 91.720 273.310 3810.48 3876.53 11221.45 91.540 272.470 3809.55 3875.60 11250,86 90,250 272.160 3809.09 3875.14 11284.58 91.660 271.650 3808.53 3874,58 11316.90 93.640 272.290 3807.04 3873.09 11347.06 93.260 273.080 3805.22 3871.27 11377.44 92.710 272.670 3803.64 3869.69 11409.58 91.970 272.180 3802.33 3868.38 11443.54 90.800 271.830 3801.51 3867.56 11476.08 90.370 272.320 3801.18 3867.23 11508,71 90.000 272.210 3801.07 3867.12 11538.50 89.880 272.270 3801.10 3867,15 11572.03 89.940 272.390 3801.15 3867.20 11606.09 90.430 271.590 3801.00 3867.09 272.62O 272.180 271.990 271.420 272.000 271.570 271.870 271.700 272.240 271.860 11633.85 91.170 11668.66 90.680 11701.27 90.550 11729.42 90.430 11762.43 90.490 3800.66 3800.09 3799.74 3799.50 3799.24 3799.01 3798.43 3797.02 3795.66 3794.41 11794.66 90.310 11824.01 91.970 11860.41 92.460 11892.50 92.400 11922.09 92.460 3866.71 3866,14 3865.79 3865.55 3865.29 3865.06 3864.48 3863.07 3861.71 3860.46 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (,It) (~t) 2435.53 N 9008.16W 6017483.16 N 542889.35 E 2436.98 N 9040.84W 6017484.38N 542856.66 E 2438.62N 9073.49W 6017485.80 N 542824.00 E 2439.81N 9102.87W 6017486.78 N 542794,61E 2440,93 N 9136.56W 6017487,67N 542760.91E 2442.00N 9168.83W 6017488.56 N 542728.64 E 2443.45 N 9198.90W 6017489.76 N 542698.56 E 2444.97N 9229.20W 6017491.07N 542668.25 E 2446,33 N 9261.29W 6017492.20N 542636.16 E 2447.52 N 9295.21W 6017493.15 N 542602.22 E 2448.70 N 9327.73 W 6017494.10 N 542569.70 E 2449.99 N 9360.34 W 6017495.17 N 542537.08 E 2451,15 N 9390,10 W 6017496.12 N 542507.31 E 2452.52 N 9423.60 W 6017497.25 N 542473.80 E 2453.70 N 9457.64 W 6017498.20 N 542439.75 E 2454.72 N 9485.38 W 6017499.03 N 542412.01 E 2456.18 N 9520.16 W 6017500.24 N 542377.22 E 2457.36 N 9552.74 W 6017501.20 N 542344.63 E 2458.20 N 9580.88 W 6017501.84 N 542316.49 E 2459.18 N 9613.87 W 6017502.60 N 542283.49 E 2460.19 N 9646.09 W 6017503.38 N 542251.27 E 2461.07 N 9675.42 W 6017504.05 N 542221.93 E 2462.20 N 9711.77 W 6017504.93 N 542185.57 E 2463.30 N 9743.81 W 6017505.81 N 542153.52 E 2464.36 N 9773.36 W 6017506.66 N 542123.97 E Dogleg Rate (°llOOft) 1.56 5.26 2,63 4,51 4,45 6.44 2.90 2.26 2.76 3.60 2.00 1.18 0.45 0.40 2.75 4.57 1.89 0.71 2.07 1.77 1.45 5.75 1.42 1.69 1.30 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 9331.42 9363.39 9395.37 9424.09 9456,95 9488.44 9517.87 9547.56 9578.93 9612.04 9643.78 9675.64 9704.72 9737.46 9770.68 9797.76 9831.76 9863.57 9890.99 9923.15 9954.55 9983.14 10018.58 10049.84 10078.68 Continued.,. 15 November, 2000- 14:08 - 9 - DriliQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Ref: API-500292297600 Job No. AKMMO0220, Surveyed: 21 October, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (ft) (ft) Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) 11975.00 92.460 271.860 3792.14 3858.19 2466.08 N 9826.19 W 6017508.01 N 542071.13 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-224. Northings and Eastings are relative to MPJ-224, The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from MPJ-224 and calculated along an Azimuth of 284.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11975.00ft., The Bottom Hole Displacement is 10130.92ft., in the Direction of 284.089° (True). Dogleg Rate {°/lOOft) 0.00 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment lO13O.21 Projected Survey Comments Meesured Depth (fi) 11975.00 Station Coordinates TVD Northlngs Eaetlngs Comment (ft) (ft) (ft) 3858.19 2466.08 N 0826.10 W Projected Suwey Continued... 15 November, 2000- 14:09 - 10- DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for MPJ-224 Your Ref: API-500292297600 Job No. AKMM00220, Surveyed: 21 October, 2000 North Slope Alaaka Alaska State Plane 4 Milne Point MPJ ;"~urvey tool program From To Measured Vertical Measured Depth Depth Depth (fi) (fi) 0.00 0.00 11975.00 Vertical Depth (~t) 3858.19 Survey Tool Description IFR 15 November, 2000 - 14:09 - 11 - DrillOuest 2.00.02 North Slope Alaska Alaska State Plane 4 Miine Point MPJ MPJ-224 mwd Surveyed: 21 October, 2000 SURVEY REPORT 11/09/2000 13:48:59 PM Your Ref: API-500292297600 Surface Coordinates: 6015110.45 N, 551914.26 E (70° 27' 07.2878" N, Kelly Bushing: 66.05fl above Mean Sea Level DRII--i-INI] LSlRVICB! 149° 34' 35.0852" W) Survey Ref: svy9682 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API,500292297600 Surveyed: 21 October, 2000 North Slope Alaska Meaeured Depth Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eaetinge Northings Eastings (ft) (ft) (ft) (ft) (fi) (ft) 0.00 0.000 0.000 -66.05 113.99 0.050 163.970 47.94 205.65 0.180 153.910 139.60 296.07 0.160 213.460 230.02 326.16 0.620 256.470 260.11 419.57 2.940 277.500 353.47 512.21 5.650 276.450 445.84 603.80 8.540 288.640 536.72 698.34 10.890 295.650 629.90 790.55 13.700 297.760 719.99 882.22 16.300 296.560 808.53 974.86 18.780 293.000 896.86 1067.02 21.990 289.580 983.24 1161.98 24.620 292.500 1070.45 1254.82 28.140 290.820 1153.61 1346.77 31.830 290.590 1233.24 1439.08 35.600 290.030 1310.01 1531.34 36.640 290.020 1384.53 1624.21 40.690 288.110 1457.03 1717.86 42.090 289.350 1527.29 1809.63 44.880 290.190 1593.87 1906.01 46.300 291.100 1661.31 1997.65 48.370 292.180 1723.42 2089.69 49.880 291.370 1783.65 2182.72 51.000 290.840 1842.90. 0.00 0.00 N 0.00 E 113.99 0.05 S 0.01 E 205.65 0.22 S 0.09 E 296.07 0.45 S 0.08 E 326.16 0.52 $ 0.10 W 419.52 0.33 S 2.97 W 511.89 0.50 N 9.86 W 602.77 3.18 N 20.78 W 695.95 9.29 N 35.49 W 786.04 18.14 N 53.00 W 874.58 28.95 N 74.12 W 962.91 40.60 N 99.48 W 1049.29 52.18 N 129.40 W 1136.50 65.71 N 164.43 W 1219.66 80.90 N 202.78 W 1299.29 97.14 N 245.76 W 1376.06 114.91 N 293.80 W 1450.58 133.53 N 344.90 W 1523.08 152.43 N 399.74 W 1593.34 172.32 N 458.37 W 1659.92 193.69 N 517.79 W 1727.36 217.97 N 582.21 W 1789.47 242.83 N 644.84 W 1849.70 268.64 N 709.47 W 1908.95 294.47 N 776.38 W 6015110.45 N 551914.26E 6015110.40 N 551914.27E 6015110.24 N 551914.35 E 6015110.00 N 551914.34E 6015109.93 N 551914.16 E 6015110.10 N 551911.30 E 6015110.88 N 551904.40E 6015113.48 N 551893.46 E 6015119.49 N 551878.71E 6015128.23 N 551861.13 E 6015138.89 N 551839.94 E 6015150.35 N 551814.50 E 6015161.73 N 551784.50 E 6015175.01N 551749.37E 6015189.93 N 551710.92 E 6015205.87N 551667.83 E 6015223.31N 551619.66 E 6015241.57N 551568.44E 6015260.10 N 551513.47E 6015279.58 N 551454.70 E 6015300.53N 551395.13 E 6015324.36 N 551330.54 E 6015348.78N 551267.74E 6015374.14 N 551202.94E- 6015399.50 N 551135.85 E Dogleg Rate (o/looft) 0.044 0.143 0.188 1.711 2.539 2.926 3.541 2.778 3.086 2.856 2.916 3.714 3.024 3.875 4.015 4.098 1.127 4.546 1.732 3.105 1.620 2.419 1.770 1.282 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 0.00 -0.03 -0.14 -0.19 -0.04 2.79 9.66 20.91 36.68 55.88 79.05 106.54 138.43 175.75 216.70 262.40 313.39 367.55 425.39 487.16 550.06 618.55 685.44 754.51 825.80 Continued... 11/09/2000 13:49:01 PM - 2 - DrillQuest 1,05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API,500292297600 Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) (ft) 2275.12 55.120 292.440 1898.42 1954.47 2366.62 59.530 294.040 1947.81 2013.86 2460.59 63.630 290.720 1992.53 2058.58 2553.35 67.070 294.520 2031.22 2097.27 2847.32 70.110 292.810 2065.52 2131.57 2766.56 69.670 295.760 2106.53 2172.58 2859.34 70.370 294.040 2138.23 2204,28 2952.14 72.190 295.390 2168.02 2234.07 3043.09 72.260 294.240 2195.78 2261,83 3131.14 71.980 289.380 2222.83 2288,88 3226.20 71.170 287.060 2252.88 2318.93 3318.63 70.340 289.340 2283.35 2349.40 3415.67 71.340 290.360 2315.20 2381.25 3505.33 71.890 291.260 2343.48 2409.53 3598.30 69.400 291.400 2374.29 2440.34 3690.38 69.080 290.490 2406.93 2472.98 3783.66 70.700 290.600 2439.00 2505.05 3872.98 73.750 291.510 2466.26 2532.31 3971.05 72.920 291.720 2494.39 2560.44 4060,26 72.340 292.160 2521.02 2587.07 4156.33 72.120 292.000 2550.34 2616.39 4250.64 71.270 292.360 2579.96 2546.01 4343.26 71.130 291.790 2609.81 2675.86 4435.02 71.140 292.950 2639.48 2705.53 4530.50 71.380 288.790 2670.16 2736.21 321.72N 845.00W 6015426.27 N 551067.04E 352.12 N 915.74W 6015456.19 N 550996.09 E 383.54N 992.14W 6015487.06 N 550919.47E 415.98 N 1069.92W 6015518.97N 550841.47 E 451.08 N 1150.04W 6015553.51N 550761.11E 497.12 N 1252.09W 6015598.84 N 550658.74 E 533.83 N 1331.18W 6015634.99 N 550579.40E 570.58 N 1411.01W 6015671.19 N 550499.31 E 606.93N 1489.62W 6015706.99N 550420.45E 638.05 N 1567.39W 6015737.57 N 550342.46 E 666.25 N 1653.04W 6015765.17 N 550256.61E 693.50 N 1735.94W 6015791.84N 550173.53 E 724.63 N 1822.15W 6015822.37N 550087.10 E 754.86 N 1901.68W 6015852.04 N 550007.36 E 786.76 N 1983.39W 6015883.37N 549925.44E 817.54N 2063.80W 6015913.59 N 549844.82E 848.28 N 2145.82W 6015943.76 N 549762.59 E 878.84N 2225.18W 6015973.76 N 549683.01E 913.44N 2312.52W 6016007.76 N 549595.43E 945.26 N 2391.50W 6016039.02N 549516.23 E 979.65 N 2476.28W 6016072.82 N 549431.22E 1013.45 N 2559.19W 6016106.04 N 549348.07E 1046.40 N 2640.44W 6016138.43 N 549266.60E 1079.44N 2720.73W 6016170.91N 549186.07E 1111.65 N 2805.20W 6016202.52 N 549101.39 E Dogleg Rate (°llOOft) 4.668 5.039 5.356 5.254 3.652 2.352 1.899 2.397 1.207 5.262 2.467 2.496 1.431 1.133 2.682 0.987 1.740 3.550 0.871 0.803 0.279 0.971 0.602 1.196 4.134 Alaska State Plane 4 Milne Point MPJ Vertical Section Comment 899.1o 975.25 lO57.14 114o.62 1227.o4 1337.45 1423.28 15o9.85 1595.13 1678.26 1768.28 1855.38 1946.68 2o31.29 2118.42 22o4.o3 2291.17 2375.70 2468.98 2553.46 2644.20 2732.99 2819.96 2906.02 2995.91 m Continued... 11/09/2000 13:49:01 PM - 3 - DriilQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API.500292297600 Surveyed: 21 October, 2000 North Slope Alaska Measured Depth Incl, Azim, Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 4623.38 71.420 291.710 2699.80 4716.35 71.420 291.070 2729.42 4809.08 73.900 289.520 2757.06 4902.00 74.620 288.140 2782.26 4994.52 74.940 289.800 2806.55 5087.17 74.680 288.680 2830.83 5179.87 75.190 290.290 2854.93 5272.52 75.420 294.110 2878.44 5363.82 73.590 291.370 2902.83 5458.01 73.750 294.070 2929.32 5550.44 73.290 292.750 2955.54 5644.59 73.180 289.830 2982.70 5733.91 74.140 290.030 3007.83 5829.02 74.930 293.030 3033.20 5920.67 73.200 292.340 3058.36 6017.13 70.910 286.890 3088.10 6109.87 70.560 285.660 3118.70 6202.53 70.160 288.730 3149.85 6295.01 70.550 285.530 3180.95 6387.68 71.730 285.000 3210.90 6479.95 72.160 287.780 3239.50 6571.52 71.970 289.150 3267.70 6666.66 72.590 289.050 3296.66 6759.45 72.440 293.840 3324.55 6852.02 73.050 293.630 3352.01 2765.85 1142.11N 2887.77W 2795.47 1174.25 N 2969.83W 2823.11 1204.94N 3052.84W 2848.31 1233.80 N 3137.49W 2872.60 1262.82 N 3221.91W 2896.88 1292.29 N 3306.33W 2920.98 1322.15 N 3390.71W 2944.49 1356.00 N 3473.67W 2968.88 1390.02 N 3554.80W 2995.37 1424.92N 3638.16W 3021.59 1460.14 N 3719.50W 3048.75 1492.87N 3803.48W 3073.88 1522.08 N 3884.06W 3099.25 1555.72N 3969.32W 3124.41 1589.71 N 4050.62 W 3154.15 1620.53 N 4137.01 W 3184.75 1645.06 N 4221.05 W 3215.90 1670.86 N 4304AIW 3247.00 1696.50N 4387.63W 3276.95 1719.59 N 4472.23W 3305.55 1744.34N 4556.38W 3333.75 1771.94 N 4639.01W 3362.71 1801.59 N 4724.65W 3390.60 1833.94N 4806.99W 3418.06 1869.52 N 4887.92W Global Coordinates · Northings Eastings (ft) (ft) 6016232.41N 549018.60 E 6016263.98 N 548936.32 E 6016294.09 N 548853.10 E 6016322.37N 548768.25 E 6016350.80 N 548683.63 E 6016379.67N 548599.01E 6016408.94N 548514.42E 6016442.22 N 548431.23 E 6016475.67N 548349.87E 6016509.99 N 548266.26 E 6016544.64 N 548184.68 E 6016576.78 N 548100.47E 6016605.44N 548019.69 E 6016638.48 N 547934.20 E 6016671.90 N 547852.66 E 6016702.12 N 547766.06 E 6016726.07N 547681.85 E 6016751.28 N 547598.32 E 6016776.34 N 547514.92 E 6016798.84 N 547430.16 E 6016823.01N 547345.84E 6016850.02 N 547263.02 E 6016879.08 N 547177.18 E 6016910.85 N 547094.61E 6016945.87 N 547013.43E Dogleg Rate (°/lOOft) 2.980 0.653 3.114 1.626 1.765 1.200 - 1.765 3.996 3.519 2.756 1,457 2.972 1.096 3.151 2.022 5.875 1.308 3.150 3.286 1.384 2.902 1.438 0.659 4.926 0.694 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 3083.52 3171.06 3259.15 3348.36 3437.39 3526.53 3615.74 3704.59 3791.71 3881.22 3968.84 4058.40 4143.76 4234.78 4322.06 4413.45 4500.96 4588.14 4675.15 4762.84 4850.52 4937.46 5027.83 5115.70 5203.02 m Continued... 11/09/2000 13:49:02 PM -4- DriliQuest 1.05.05 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (fi) Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API-5002927.97600 Surveyed: 21 October, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Fastings Northings Fastings (tt) (~) (~) (~t) (~) 6945.04 7~.390 290.430 3378.87 3444.92 7037.55 72.180 293.500 3406.26 3472.31 7130.79 72:600 291.640 3434.47 3500.52 7223.34 72.080 289.270 3462.55 3528.60 7315.26 72.990 295.040 3490.16 3556.21 7408.53 71.560 289.000 3518.58 3584.63 7500.59 71.850 288.790 3547.48 3613.53 7593.74 71.490 293.880 3576.79 3642.84 7686.62 70.660 298.760 3606.93 3672.98 7779.33 71.780 295.470 3636.78 3702.83 7872.44 69.780 293.610 3667.43 3733.48 7965.03 71.420 297.910 3698.20 3764.25 6057.77 71.310 298.390 3727.83 3793.88 8150.51 71.760 296.460 3757.21 3823.26 8242.58 74.150 290.290 3784.22 3850.27 8336.58 78.190 289.210 3806.68 3872.73 8428.55 78.230 284.970 3825,48 3891.53 8496.52 79.140 281.770 3838.82 3904.87 8522.29 80.730 281.940 3843.33 3909.38 8555.50 83.310 279.950 3847.94 3913.99 8586.61 85.690 277.960 3850.92 3916.97 8614.79 86.960 278.960 3852.73 3918.78 8623.57 87.050 278.540 3853.18 3919.23 8702.71 88.830 280.560 3856.03 3922.08 8735.22 89.940 281.120 3856.38 3922.43 1902.92 N 4970.46W 1935.96 N 5052.41W 1970.06 N 5134.47 W 2000.88 N 5217.09 W 2033.94 N 5298.25 W 2067.25 N 5380.56W 2095.55 N 5463.25W 2127.71 N 5545.59 W 2166.64 N 5624.31 W 2206.63 N 5702.43 W 2243.15 N 5782.39 W 2281.11N 5861.02W 2322.57N 5938.50W 2363.08 N 6016.58W 2397.95 N 6097.34W 2428.78 N 6183.23W 2455.23 N 6269.26W 2470.64N 6334.09W 2475.85 N 6358.92W 2432.09 N 6391.21W 2436.91N 6421.80W 2491.05 N 6449.61W 2492.38 N 6458.28W 2505.50 N 6536.26W 2511.62 N 6568.19W 6016978.69 N 546930.66 E 6017011.16 N 546848.49 E 6017044.69 N 546766.19 E 6017074.94 N 546683.36 E 6017107.43N 546601.97E 6017140.16 N 546519.43 E 6017167.89 N 546436.54 E 6017199.47N 546353.99 E 6017237.85 N 546274.99 E 6017277.30 N 546196.60 E 6017313.26 N 546116.38 E 6017350.67N 546037.49E 6017391.59 N 545959.72 E 6017431.56 N 545881.37E 6017465.87 N 545800.36 E 6017496.10 N 545714.26 E 6017521.95 N 545628.05 E 6017536.90 N 545563.11E 6017541.94 N 545538.24E 6017547.96 N 545505.91E 6017552.56 N 545475.29 E 6017556.51N 545447.45E 6017557.78 N 545438.78 E 6017570.36 N 545360.70 E 6017576.25 N 545328.73 E Dogleg Rate (°llOOff) 3.314 3.429 1.954 2.504 6.069 6.356 0.382 5.201 5.050 3.570 2.859 4.725 0.505 2.033 6.912 4.440 4.513 4.807 6.204 9~776 9.953 5.732 4.886 3.401 3.824 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 5291.35 5379.01 5467.05 5554.80 5641.71 5729.79 5816.97 5904.78 5990.83 6076.56 6163.19 6248.90 6334.39 6420.21 6507.20 6598.11 6688.04 6754.66 6780.00 6812.81 6843.61 6871.56 6880.28 6959.04 6991.47 Comment m Continued... 11/09/2000 13:49:03 PM . $- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API-500292297600 Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8765.83 90.000 280.510 3856.39 3922.44 8797.53 90.250 280.420 3856.33 3922.38 8831.67 90.000 279.460 3856.25 3922.30 8859.77 90.180 278.480 3856.21 3922.26 8894.67 90.310 275.700 3856.06 3922.11 8928.39 90.120 275.860 3855.93 3921.98 8956.92 89.940 274.980 3855.92 3921.97 8990.45 90.000 273.140 3855.93 3921.98 9022.27 90.180 272.230 3855.88 3921.93 9053.44 90.740 270.360 3855.63 3921.68 9086.22 91.360 268.980 3855.03 3921.08 9118.92 90.860 268.580 3854.40 '3920.45 9148.45 89.020 268.240 3854.43 3920.48 9182.28 89.080 266.030 3854.99 3921.04 9216.32 89.510 263.730 3855.41 3921.46 9245.62 89.380 263.930 3855.69 3921.74 9277.41 89.690 264.330 3855.95 3922.00 9309.89 89.570 263.480 3856.16 3922.21 9339.80 89.260 263.740 3856.47 3922.52 9374.48 88.710 262.910 3857.08 3923.13 9406.02 90.250 262.400 3857.37 3923.42 9434.84 90.680 263.780 3857.13 3923.18 9469.42 92.030 263.260 3856.32 3922.37 9501.90 92.030 263.540 3855.17 3921.22 9529.56 91.910 263.850 3854.21 3920.26 2517.36 N 6598.26W 6017581.78 N 545298.63 E 2523.12 N 6629.43W 6017587.32 N 545267.41 E 2529.01N 6863.06W 6017592.98 N 545233.75 E 2533.39 N 6690.81W 6017597.17 N 545205.96 E 2537.70 N 6725.44W 6017601.23 N 545171.30 E 2541.10 N 6758.99W 6017604.40 N 545137.73 E 2543.79 N 6787.39W 6017606.89 N 545109.31 E 2546.17 N 6820.84W 6017609.03 N 545075.85 E 2547.66N 6852.62W 6017610.30 N 545044.06 E 2548.36 N 6883.78W 6017610.79 N 545012.89 E 2548.17 N 6916.55W 6017610.37 N 544980.12 E 2547.48 N 6949.24W 6017609.45 N 544947.44E 2548.66 N 6978.76W 6017608.43N 544917.93 E 2544.97N 7012.54W 6017606.50 N 544884.16 E 2541.93 N 7046.44W 6017603.23 N 544850.29 E 2538.78 N 7075.57W 6017599.87N 544821.18 E 2535.53 N 7107.19W 6017596.40N 544789.58 E 2532.08 N 7139.48W 6017592.73 N 544757.31 E 2528.75 N 7169.21W 6017589.19 N 544727.61 E 2524.72 N 7203.64W 6017584.92 N 544693.20 E 2520.69 N 7234.92W 6017580.67N 544661.95 E 2517.22 N 7263.53W 6017577.01N 544633.37 E 2513.32 N 7297.88W 6017572.87 N 544599.05 E 2509.62 N 7330.13W 6017568.94 N 544566.82 E 2506.61N 7357.61W 6017565.74 N 544539.37 E Dogleg Rate (°/lOOft) 2.002 0.838 2.906 3.546 7.974 0.737 3.148 5.491 2.915 6.262 4.615 1.958 6.336 6.534 6.873 0.814 1.592 2.643 1.353 2.871 5.143 5.015 4.183 1.169 0.874 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 7022.00 7053.62 7O87.63 7115.59 7150.17 7183.48 7211.63 7244.57 7275.69 7306.00 7337.64 7369.07 7397.40 7429.63 7461.64 7489.00 7518.75 7549.10 7576.99 7609.27 7638.48 7665.26 7697.48 7727.72 7753.52 Comment m Continued... 11/09/2000 13:49:03 PM - 6 - DrillQuest 1.05.05 North Slope Alaska Measured Depth Incl. Azlm. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for MPJ-224 mwd Your Ref: API.500292297600 Surveyed: 21 October, 2000 9564.16 91.480 262.950 3853.19 3919.24 9596.43 92.220 262.490 3852.15 3918.20 9629.56 92.030 262.650 3850.92 3916.97 9660.78 91.780 262.660 3849.88 3915.93 9693.14 91.540 262.690 3848.95 3915.00 9722.16 92.030 264.300 3848.04 3914.09 9756.29 92.030 265.780 3846.83 3912.88 9788.90 91.780 267.340 3845.75 3911.80 9816.91 91.420 268.980 3844.97 3911.02 9851.26 91.790 270.460 3844.00 3910.05 9883.67 91.660 271.550 3843.03 3909.08 9912.53 91.290 272.400 3842.29 3908.34 9947.69 91.110 272.640 3841.55 3907.60 9980,45 92.280 272.890 3840.58 3906.63 10007.05 92.590 272.160 3839.45 3905.50 10039.32 91.540 273.300 3838.29 3904.34 10072.21 90.800 272.630 3837.62 3903.67 10101.83 90.180 271.850 3837.36 3903.41 10137.04 91.170 271.440 3836.95 3903.00 10169.42 91.600 271.100 3836.17 3902.22 10199.54 91.660 271.790 3835.31 3901.36 10231.80 91.230 272.250 3834.49 3900.54 10265.51 90.800 270.910 3833.90 3899.95 10293.92 89.820 270.530 3833.74 3899.79 10329.94 91.540 269.810 3833.32 3899.37 Local Coordinates Northings Eastings (fi) (fi) 2502.63 N 7391.96 W 2498.54 N 7423.96 W 2494.26 N 7456.79 W 2490.27 N 7487.73 W 2486.15 N 7519.81 W - 2482.86 N 7548.63 W 2479.91 N 7582.61 W 2477.96 N 7615.14 W 2477.06 N 7643.13 W 2476.89 N 7677.46 W 2477.46 N 7709.85 W 2478.45 N 7738.69 W 2480.03 N 7773.80 W 2481.58 N 7806.51 W 2482.75 N 7833.06 W 2484.29 N 7865.27 W 2485.99 N 7898.11 W 2487.15 N 7927.71 W 2488.16 N 7962.90 W 2488.87 N 7995.26 W 2439.63 N 8025.36 W 2490.77 N 8057.59 W 2491.70 N 8091.28 W 2492.06 N 8119.69 W 2492.16 N 8155.70 W Global Coordinates Northings Eastings (ft) (ft) 6017561.52N 544505.04 E 6017557.21N 544473.08 E 6017552.70 N 5~4~0.28 E 6017548.50 N 544409.36 E 6017544.15 N 544377.31E 6017540.66 N 544348.51E 6017537.48 N 544314.55 E 6017535.30 N 544282.04 E 6017534.20 N 544254.06 E 6017533.79 N 544219.73 E 6017534.14 N 544187.33 E 6017534.93 N 544158.49E 6017536.23 N 544123.37E 6017537.58 N 544090.65 E 6017538.57 N 544064.09 E 6017539.88 N 544031.87E 6017541.35 N 543999.02 E 6017542.30 N 543969.42E 6017543.07N 543934.22 E 6017543.56 N 543901.85 E 6017544.11N 543871.75 E 6017545.02 N 543839.51E 6017545.72 N 543805.82 E 6017545.88 N 543777.41E 6017545.73 N 543741.39 E Dogleg Rate (°/lOOft) 2.882 2.700 O.75O 0.801 0.747 5.797 4.334 4.842 5.992 4.440 3.385 3.211 0.853 3.652 2.979 4.801 3.035 3.364 3.043 1.693 2.299 1.952 4.174 3.700 5.177 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 7785.73 7815.62 7846.28 7875.18 79o5.15 7932.18 7964.29 7995.25 8o22.08 8055.23 8086.70 8114.83 8149.18 8181.21 82o7.18 8238.72 827o.91 8299.82 8334.11 8365.59 8394.88 8426.34 8459.15 8486.71 8521.57 Continued... 11/09/2000 13:49:05 PM . ?. DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API-500292297600 Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eaatings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10362.12 91.910 270.050 3832.35 3898.40 10389.52 92.160 270.050 3831.37 3897.42 10423.45 92.160 269.850 3830.10 3896.15 10455.75 91.970 269.280 3828.93 3894.98 10483.69 91.780 269.610 3828.02 3894.07 10520.10 91.600 269.460 3826.94 3892.99 10551.81 91.480 269.350 3826.09 3892.14 10581.57 91.110 268.460 3825.42 3891.47 10616.88 90.860 268.600 3824.81 3890.86 10649.20 90.620 268.350 3824.39 3890.44 10677.97 90.370 268.370 3824.15 3890.20 10712.20 91.410 269.300 3823.61 3889.66 10745.19 91.540 270.560 3822.77 3888.82 10773.57 91.480 270.780 3822.02 3888.07 10807.85 91.360 270.130 3821.17 3887.22 10840.37 91.170 269.640 3820.45 3886.50 10868.74 91.110 270.350 3819.89 3885.94 10904.54 91.850 271.310 3818.96 3885.01 10936.93 91.720 272.440 3817.95 3884.00 10964.91 91.420 272.080 3817.19 3883.24 10999.07 90.920 272.040 3816.49 3882.54 11031.51 92.830 273.540 3815.43 3881.48 11060.40 92.150 273.990 3814.17 3880.22 11095.08 90.920 272.430 3813.24' 3879.29 11127.78 90.550 271.770 3812.82. 3878.87 2492.12 N 8187.87 W 2492.15 N 8215.25 W 2492.12 N 8249.16 W 2491.87 N 8281.44 W 2491.60 N 8309.36W 2491.31N 8345.75W 2490.98 N 8377.45W 2490.41N 8407.20W 2489.50 N 8442A9W 2488.64 N 847429W 2487.82 N 8503.55W 2487.12 N 8537.77W 2487.08 N 8570~5W 2487.42 N 8599.12W 2487.69 N ' 8633.38W 2487.62 N 8665.90W 2487.62 N 8694.26W 2488.14 N 8730.04W 2489.20 N 8762.40W 2490.30 N 8790.35W 2491.53 N 8824.48W 2493.11N 8856.86W 2495.00 N 8885.66W 2496.94 N 8920.27W 2498.14 N 8952.95W 6017545.47 N 543709.23 E 6017545.30 N 543681.85 E 6017545.04 N 543647.94 E 6017544.57N 543615.66 E 6017544.10 N 543587.74E 6017543.55 N 543551.35 E 6017543.00 N 543519.66 E 6017542.23 N 543489.92 E 6017541.08 N 543454.63 E 6017539.99 N 543422.33 E 6017538.97N 543393.58 E 6017538.03 N 543359.37E 601753726 N 543326.39 E 6017537.90 N 543298.02 E 6017537.93 N 543263.75 E 6017537.64 N 543231.24 E 6017537.44N 543202.88 E 6017537.71N 543167.09 E 6017538.54 N 543134.73E 6017539~5 N 543106.78 E 6017540.44N 543072.64 E 6017541.79 N 543040.25 E 6017543.49 N 543011.43 E 6017645.19 N 542976.81E 6017546.16 N 542944.13 E Dogleg Rate (°/lOOft) 1.370 0.912 0.589 1.859 1.362 0.643 0.513 3.238 0.811 1.072 0.872 4.076 3.838 0.803 1.928 1.616 2.511 3.385 3.510 1.674 1.468 7.485 2.822 5.727 2.314 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 8552.66 8579.14 8611.92 8643.07 8670.00 8705.12 8735.68 8764.30 8798.20 8829.22 8856.81 8889.72 8921.60 8949.12 8982.32 9013.74 9041.17 9075.90 9107.46 9134.76 9168.08 9199.79 9228.13 9262.09 9293.99 Comment Continued... 11/09/2000 13:49:06 PM - 8 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API,500292297600 Surveyed: 21 October, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Depth (fi) 11156.03 90.990 271.700 3812.44 3878.49 11188.75 91.720 273.220 3811.67 3877.72 11221.45 91.540 272.360 3810.74 3876.79 11250.86 90.250 272.070 3810.28 3876.33 11284.58 91.660 271.610 3809.72 3875.77 11316.90 93.640 272.240 3808.22 3874.27 11347.06 93.260 273.030 3806.41 3872.46 11377.44 92.710 272.560 3804.83 3870.88 11409.58 91.970 272.100 3803.51 3869.56 11443.54 90.800 271.730 3802.69 3868.74 11476.08 90.370 272.230 3802.36 3868.41 11508.71 90.000 272.180 3802.26 3868.31 11538.50 89.880 272.270 3802.29 3868.34 11572.03 89.940 272.330 3802.34 3868.39 11606.09 90.430 271.600 3802.23 3868.28 11633.85 91.170 272.640 3801.84 3867.89 11668.66 90.680 272.210 3801.28 3867.33 11701.27 90.550 272.010 3800.93 3866.98 11729.42 90.430 271.480 3800.69 3866.74 11762.43 90.490 272.110 3800.42 3866.47 11794.66 90,310 271.660 3800.20 3866.25 11824.01 91.970 271.800 3799.62 3865,67 11860.41 92.460 271.810 3798.21 3884.26 11892.50 92.400 272.180 3796.85 3862.90 11922.09 92.460 271.920 3795.59 3861.64 Local Coordinates Northings Eastings (fi) (ft) Global Coordinates Northings Eastings (ft) (ft) 2499,00 N 8981.18W 6017546.81N 542915.89 E 2500.40 N 9013.86W 6017547.99 N 542883.20 E 2501.99 N 9046.51W 6017549.35 N 542850.54 E 2503.13 N 9075.89W 6017550.29 N 542821.15 E 2504.21N 9109.59W 6017551.13 N 542787.44E 2505.29 N 9141.86W 6017551.99 N 542755.17 E 2506.68 N 9171.93W 6017553.17 N 542725.09 E 2508.16 N 9202.23W 6017554.44N 542694.78 E 2509.46N 9234.32W 6017555.52N 542662.68 E 2510.60 N 9268.25W 6017556.42 N 542628.75 E 2511.72 N 9300.77W 6017557.31N 542596.22 E 2512.98 N 9333.37W 6017558.34N 542563.61E 2514.13 N 9363.14W 6017559.29 N 542533.83 E 2515.48 N 9396.64W 6017560.40 N 542500.32 E 2516.65 N 9430.68W 6017561.33 N 542466.27 E 25t7.67 N ' 9458.42W 6017562.17 N 542438.53 E 2519.15 N 9493.19W 6017563.40N 542403.75 E 2520.35 N 9525~8W 6017564.37N 542371.15 E 2521.20 N 9553.92W 6017565.03N 542343.01E 2522.24 N 9586.91W 6017565.84 N 542310.01E 2523.30 N 9619.12W 6017566.67 N 542277.79 E 2524.18 N 9648.45W 6017567.35 N 542248.46E 2525.33 N 9684.80W 6017568.25 N 542212.10 E 2526.45 N 9716.85W 6017569.14 N 542180.05 E 2527.50 N 9746.39W 6017569.99 N 542150.50 E Dogleg Rate (°/lOOft) 1.577 5.152 2.686 4.496 4.398 6.428 2.902 2.380 2.710 3.613 2.027 1.144 0.504 0.253 2.581 4.598 1.873 0.731 1.930 1.917 1.504 5.676 1.346 1.167 0.901 Alaska State Plane 4 Milne Point MPJ . Vertical Section (ft) Comment 9321.51 9353.47 9385.44 9414.14 9447.00 9478.48 9507.91 9537.59 9568.95 9602.05 9633.78 9665.63 9694.71 9727.44 9760.66 9787.74 9821.74 9853.56 9880.98 9913.15 9944.56 9973.15 10008.60 10039.86 10068.70 Continued... 11/09/2000 13:49:07 PM - 9 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API-500292297600 Surveyed: 21 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 Dogleg Northings Eastings Rate (~t) (~t) (°/lOOft) 11975.00 92.460 271.920 3793.32 3859.37 2529.27 N 9799.22W 6017571.39 N 542097.65 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-224. Northings and Eastings are relative to MPJ-224. 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) Comment 10120.24 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-224 and calculated along an Azimuth of 284.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11975.00ft., The Bottom Hole Displacement is 10120.37ft., in the Direction of 284.473° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11975.00 3859.37 2529.27 N 9799.22 W Projected Suwey Continued... 11/09/2000 13:49:00 PM - 10- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPJ-224 mwd Your Ref: API,500292297600 Surveyed: 21 October, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ ~..~urvey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (fi) 11975.00 Vertical Depth (ft) 3859.37 Survey Tool Description MWD Magnetic 11/09/2000 13:49:09 PM - 11- DrillQuest 1.05.05 bp November 7, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Davies: Subject: Well Re-Naming The operator request the following Milne Point Wells be re-named as follows: APl num Permit Number Current Name New Name Sincerely, Troy D, W'~ei's ACT, Production Optimization Team Leader TDW:mw CC: Well Files S. Copeland, MB LR-2 Gary Benson, MB 12-4 Larry Niles, MPU Chuck Mallary, MB 8-1 'Mike Bill, MB 7-5 500292296600 200-109 MPI-210 MPI-10 500292297000 200-120 MPJ-223 MPJ-23 500292297600 200-149 MPJ-224 MPJ-24 500292298000 200-166 M PE-225 M PE-25 500292298060 200-167 MPE-225L1 MPE-25L1 MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: Jeff Jones ,~'~' J · Petroleum Inspector Operator Rep.: Eddie Vau.qhn Contractor Rep.: Bobby In.qram MISC. INSPECTIONS: Location Gen.: P Well Sign:~ Housekeeping: P (Gen.) Drig. Rig: Reserve Pit: N/A Flare Pit: State !r Alaska Alaska Oil and Gas Conservation Commission DATE: October 8, 2000 SUBJECT: Diverter Function Test Doyon 141 BPX J-2241J-224L1 200-149 MPUIKRFISchrader Bluff NON- CONFIDENTIAL Op. phone: 670-3366 Rig phone: 670-3483 P P NIA Op. e-mail: Rig e-mail: ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig Pressure After Closure: 1850 psig 200 psi Recharge Time: 0:34 FullRecharge Time: 2:56 Nitrogen Bottles: 5 (~ 1950 psi avg. PIF P P min:sec P min:sec P MUD SYSTEM INSPECTION: Light Alarm Trip Tank: P P Mud Pits: P P Flow Monitor: P P GAS DETECTORS: Light Alarm Methane P P . H2S: P P DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Tums Targeted I Long Radius: 21 114 in. YES YES 16 in. -, 110 ft. _ NIA YES YES NIA !~"~... Flowline Wind Direction Pad Access North ~ -,-~ X~ South Test's Details Sunday, October 8, 2000: I traveled to BPX's Milne Point Unit, J-Pad, to witness the Diverter Function Test on Doyon Rig 141 drilling well J-224/J-224L1. The function test of the diverter system went well. The 21 inch annular preventer had a closure time of 43 seconds with the knife valve opening in 15 seconds, both operating simultaneously. The accumulator had a recharge time of 2 minutes 41 seconds. The gas detection system was tested and operated properly. The 16 inch vent line was of sturdy construction, solidly anchored with warning signs in place, and the layout allowed for escape from the pad if necessary. I was concerned about the close proximity of the discharge end of the vent line to the pad's flowiine. Doyon personnel had added another length of pipe and angled the vent line away as much as was possible. Although this is not the ideal situation, the construction of and access to the pad as well as the design of the rig preclude a better arrangement on this well. The rig and its equipment were clean and in good condition, and the pad was well organized. Summary: I witnessed a successful Diverter Function Test on Doyon Rig 141, no failures were witnessed. Total Test Time: 1.5 hrs Number of failures: 0 Attachments: 0 cc._.[: Diverter Doyon 141 10-8-00 JJ 3.xls r, ALASKA OIL AND GAS CONSERVATION CO~IPllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Miine Point Unit MPJ-224 BP Exploration (Alaska) Inc. Permit No: 200-149 Sur Loc: 2713'NSL, 3402'WEL, Sec. 28, T13N, RIOE, UM Btmhole Loc. '10'NSL, 2633'WEL, Sec. 19, T13N, R10E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 'Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this '~J ~ day of October, 2000 dlf/Enclosurcs CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. RE: Well MPJ-224 Multi-Lateral early approval of Permit ( Subject: RE: Well MPJ-224 Multi-Lateral early approval of Permit Date: Mon, 2 Oct 2000 23:51:26 +0100 From: "Bourne, Dan" <BoumeD~BP.com> To: "'Blair Wondzell'" <blair_wondzell~admin. state.ak.us> Blair, Our estimated spud is now 9th October, not the 17th. Is it still feasible to get the Permit reviewed before 9th? We have about a week left on this current well. Dan Bourne Drilling Engineer Schrader Bluff BP Alaska Drilling & Wells ? (907) 564-4787 (office) ? (907) 240-8050 (cell) ..... Original Message ..... From: Blair Wondzell [mailto:blair wondzell@admin.state.ak.us] Sent: 02 October 2000 14:49 To: Bourne, Dan Subject: Re: Well MPJ-224 Multi-Lateral early approval of Permit Dan, The 17th should not be a problem. Blair "Bourne, Dan" wrote: > Blair, > > By early approval, I meant would you be able to move it up in priority so > that the Permit can be reviewed as soon as possible? We're worried that with > the original spud estimate of 17th October the Permit would not be read > until too late a date as we may now be within a week of spud. > > Hope this helps, > > Dan Bourne > Drilling Engineer > Schrader Bluff > BP Alaska Drilling & Wells > ? (907) 564-4787 (office) > ? (907) 240-8050 (cell) > > > From: > Sent: > To: > Cc: ..... Original Message ..... Blair Wondzell [mailto:blair wondzell6admin.state.ak.us] 02 October 2000 14:26 Bourne, Dan AOGCC (E-mail 2); Wolfson, Larry (Hallib) ; Steve M Shultz (ARCO) (E-mail) Subject: Re: Well MPJ-224 Multi-Lateral early approval of Permit Dan, What do you mean by "early approval"? Blair "Bourne, Dan" wrote: > Gentlemen, 1 of 2 10/3/00 11:06 AM RE: Well MPJ-224 Multi-Lateral early approval of Permit ( Due to the accelerated progress of our current Milne Point well, MPJ-223, we > are trying our best to get the drilling procedures and well plan for the > next Multi-Latreal, MPJ-224, in as soon as possible. > > Would it be possible to get an early approval for the MPJ-224 Permit, since > the estimated spud date has now changed from 17th October to the 9th October? Yours sincerely, Dan Bourne Drilling Engineer Schrader Bluff BP Alaska Drilling & Wells * (907) 564-4787 (office) * (907) 240-8050 (cell) 2 of 2 10/3/00 11:06 AM STATE OF ALASKA ,, ~t~ , ALASKI["'~ ,IL AND GAS CONSERVATION COMI. ,~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work B Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 29.75' Milne Point Unit/Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 t) zs-~,-/? ~, A.D.L 025515 4. Location of well at surface 7. Unit or P'C"'"cCerty Name 11. Type Bond (See 2O AAC 25.025) 2713' NSL, 3402' WEL, Sec. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 5121' NSL, 4551' WEL, Sec. 29, T13N, R10E, UM (OB) MPJ-224 Number 2S100302630-277 At total depth 9. Approximate spud date 10' NSL, 2633' WEL, Sec. 19, T13N, R10E, UM 10/17/00 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 025517, 10' MDI No Close Approach 2560 11961' MD / 3891' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 91 ° Maximum surface 1255 psig, At total depth (TVD) 3885'/1700 psig 18. Casing Program. Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casin.q WeiQht Grade Couplin.q Len.qth MD TVD MD TVD (include sta.qe data) 30" 20" 92# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7" 26# L-80 Hydri1521 8710' 30' 30' 8740' 3951 905 sx Arctic Set II1~ 609 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 3321' 8640' 3951' 11961' 3891' Uncemented Slotted Liner 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 M D TVD Structural Conductor Surface Intermediate Production Liner RECEIVEDORiGiNAL SEP 20 2000 Perforation depth: measured AJasJ{8 0W &'Gas C0m,,, · '." L;~:.mmlssmrt"' · ' ' ' true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Boule, 564-4787 ,.. _ Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoin~-/~s~_ue anja'~?¢ect/~,~the best of my knowledge / Signed SteveShultz ~I ~ ,.>'K/~.. ~ Title Senior Drilling Engineer Date Permit Number APl Number Approval Date See cover letter ~ "'/~f/'? 50- ~ Z..'~-- 2Z~ '7~ "' (-~.*) for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes ,1~ No Hydrogen Sulfide Measures [] Yes I~1 No Directional Survey Required J~"Yes [] No Required Working Pressure for BOPE J~2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: by order of ORIGINAL SIGN~!':: Commissioner the commission Date / ~ - ~"~") _Approved By D Tc';~c.;' S~.¢, .... Form 10-401 Rev. 12-01-85 Submit In Triplicate Drillinq Hazards and Contin.qencies MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed 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. MPJ-224 is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.7 lbs/gal equivalent. The plann~~"~i~,. 9.1 lbs/gal which provides a 0.4 lbs/gal overbalance (80 psi). Kick tolerance- Infinite @ 11961' MD ~C~c 0 ~ ~000 Lost Circulation Alaska 0il & Gas Co~'~s. Commissi~ · Lost circulation has not been encountered while drilling this interval on previous J-Pa(~ wells. · A major fault (+ 150' throw) will be drilled in the surface hole at approximately 3535' SSTVD (7450' MD). This fault is not expected to cause lost circulation. · Clean hole ECD in the 9-7/8" surface hole is estimated to be 10~1 lbs/gal. Clean hole ECD in the 6-1/8" horizontal holes is estimated to be 11.7 lbs/gal. · Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Unexpected Hi.qh PressUres - No Issues Stuck Pipe The J-224 directional plan has a 5820' interval of high angle (72°) in the surface hole with 3600' and 3220' 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. · Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! The 7" casing must be run all the way to TD to allow for the multilateral to be drilled. Similar wells in the past have experienced problems running the 7" casing to TD due to the high drag and differential sticking. There is a risk of differentially sticking the 4 ~" slotted liners. The 9.1 lbs/gal mud will be 0.4 lbs/gal overbalanced to the 8.7 lbs/gal OA/OB sand reservoir pressure (81 psi differential pressure @ 3885' TVD). The liner should be kept moving as much as possible while running in the open hole. Pad Data Sheet - Please Read the J-Pad Data Sheet thoroughly Hydrates - No Issues Hvdro=en Sulfide - No Issues Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit 1. Well Plan Summary I Well Name: I Type of Well (producer or injector): I MPJ-224 & MPJ-224L1 Producer (Multilateral) Surface Location: 2713' NSL, 3402' WEL, Sec. 28, T13N, R10E X = 551,914.26 Y = 6,015,110.45 '"'J-224:"' ........ :"'OB'"':Target":' ...... ' ...... startl "' '158' ;'~'NLi' .... 72'"8'Ew1""' "", ......... S~'~"~. 29,"T1:3Ni"R10'E~' ' .... ...... " "' "'":" ':' ....... '" J-224 OB Target End: J-224 L10A Target Start: X = 545,463 Y = 6,017,476 Z = 3874' TVDss 5269' SNL, 2601' EWL, Sec. 19, T13N, R10E X = 542,100 Y = 6,017,625 Z = 3825' TVDss 229' SNL, 942' EWL, Sec. 29, T13N, RIOE X = 545,678 Y = 6,017,406 Z = 3813' TVDss J-224 L10A Target End: 5269' SNL, 2601' EWL, Sec. 19, T13N, R10E X = 542,100 Y = 6,017,625 Z = 3752' TVDss I AFE Number: 1337196 I Estimated Start Date: I Oct. 17'n 2000 I OA MD: 11954' OATVDrkb: 13904' OB MD: 11961' OB TVDrkb: 1 3951' I Rig: I Doyon 141 Operating days to complete: I 40.9 IOA Max. Inc.: 94° I KBE: OB Max. Inc.: 91° 129.75' I Well Design (conventional, slim hole, etc'): I Grassr°°tSlaterals. Jet multi-lateraIpump completion.With extended horizontal IDrill 9-7/8" mainbore hole to +/- 8740' MD. Land mainbore hole in OB reservoir. Run and cement 7" casing. Drillout shoe and drill 3220' horizontal well in OB. Run 4 ½" slotted liner with hanger. Run multilateral packer & whipstock at top of OA interval at +/- 8360' MD. Mill window in 7" casing. Drill 3600' horizontal well in OA. Run 4 Y2" slotted liner plop and drop. Complete well with a 3 Y2" tubing jet pump completion. Objective: Jet Pump Completion: MPJ-224 will be completed with a jet pump as the means of artificial lift. The jet pump completion on J-224 consists of 3 Y=" completion tubing and a 7" x 3 ~" packer set at +/- 7750' 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 flow path for the power fluid. During operation power fluid is pumped down the tubing/casing annulus to the sliding sleeve. The power fluid then flows through the sliding sleeve and jet pump nozzle creating the draw down 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-224 will be 2500 psi water. Version #2, 9/18/2000 m Current Well Information Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit 2.1 2.2 2.3 Well Name: APl Number: Well Type: Current Status: BHP: BHT: MPJ-224 Development - Schrader Bluff Multilateral Producer New well, 20" conductor set 1,750 psi Schader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4,020' SS Estimated Mechanical Condition MPJ-224: Doyon 141: Conductor: Cellar Box MSL = 36.30' KB / MSL = 66.05' 20", 921b/ft, H-40 Welded set at 110' RKB Tamet Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserves 2.2 MMbbl Production rate: 1,500 b/d Production rate: 1,000 b/d Materials Needed Production Casing: 8740' 1 each 1 each 60 each 1 assembly 1 assembly 1 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 9-5/8" Rigid SB Casing Centralizers FMC 11" 5m x 3 Y2" Horizontal Wellhead/Tree Baker Level 2 Multilateral Equipment 7" casing pups 5', 10', 20' Production Liner: L-80 Completion: 7320' 200 off 4-5/8" x 5 3~,, x 8" 7" x 4 Y2" 4 ½" 7800' 3 ½" CMU SSD 3 x 3 1/2" Landing nipples 7"x 3 Y2" Packer 3Y2" 1 assembly 1 assembly I each I lot 4 Y2", 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 3 1/2" 9.3 Ib/ft, L-80, 8 round 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 ½" tubing pup joints RECEIVED am Schrader Bluff Tract 14 2000 Pro~lram MPJ-~4 Permit Drillin_ Hazards and Contin.qencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.1.1. 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. MPJ-224 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 provides a 0.4 lb/gal overbalance (80 psi). 3.2. Kick tolerance 3.2.1. 3.2.2. 3.3. Lost 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 11961' 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. The 7" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 7000'..~,.~o~ o~ ',,3c~t,,,,3 ~ ~,~,~ Circulation 3.3.1. 3.3.2. 3.3.3. 3.3.4. 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. A major fault (+ 150' throw) will be drilled in the surface hole at approximately 3535' SSTVD (7450' 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. 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. 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 3.4. Unexpected High Pressures 3.4.1. 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 injecti%a,~~~e~lH~ressure is expected to be 1750 psi (8.7 lb/gal). In this well, the Schrader B~~a~ ~ll~[~lled with 9.1 ppg mud. 3 SEP 2. 0 ~000 Alaska 0~ & Gas C(~ns. Schrader Bluff Tract 14 2000 Pro~lram MPJ-PP4 Permit 3.5. Stuck Pipe 3.5.1. The J-224 directional plan has a 5820' interval of high angle (72°) in the surface hole with 3600' and 3220' 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. 3.5.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5.3. A major risk of the J-224 well is running the 7" casing to TD. The 7" casing must be run all the way to TD to allow for the multilateral to be drilled. Sticking the casing off bottom will result in not being able to drill the multilateral as planned. The 9-7/8" surface hole has a 5820' high angle tangent section that 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. 3.5.4. There is a risk of differentially sticking the 4 ~" slotted liners. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.7 lb/gal OA/OB sand reservoir pressure (81 psi differential pressure @ 3,885' TVD). The liner should be kept moving as much as possible while running in the open hole. In 1999, the 5 Y2" 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 Y2" 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 MPJ-09A well with 9.1 lb/gal mud and 300 psi differential pressure. 3.6. Pad Data Sheet 3.6.1. Please Read the J-Pad Data Sheet thoroughly 3.7. Hydrates 3.7.1. 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. 3.7.2. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Schrader Bluff Tract 14 2000 Pro~lram MPJ-~4 Permit Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflects actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) i) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. 3.8. Breathina 3.8.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.9. Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.10. Geosteerin.q 3.10.1. Two rig site geologists are required onsite for accurate geosteering through the thin OA/OA sands 3.10.2. It is critical that we achieve a high percentage of 6-1/8" hole in reservoir zone drilling in the ONOB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3.11. Hvdro_~en Sulfide 3.11.1. MPJ Pad is not designated as an H2S Pad. RECEIVED SEP 20 ~000 A~ska OJ~ & Gas Co.r~s. .A~ch0ra~e 1 Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit Drillin_ Pro.qram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPJ-224. Close Approach Wells: There are no close approach wells Well Name Current Status IProduction Priority Precautions 4.2. Well Control Expected BHP 1,700 psi, 3,885' TVD (estimated) Max Exp Surface Pressure 1,255 psi (0.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2,000/250 psi Rams and Valves 2,000/250 psi Annular 4.3. Mud Proqram 9-7/8" 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 50 - 150 40 -15 N/A 9.0 - 9.5 <6 <6.5 6-1/8" Production Hole Mud Properties: OB/OAI KCL - CaCO3 Baradril N Mud I Density (PPg) I Funnel visI YP I .THP p. APl Filtrate I LG Solids 9.1 40 - 55 20 - 27 <10 8.0 - 8.5 4 - 6. < 15 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or ARCO KRU 1R. 4.4. Formation Markers Formation Tops MD TVDss Pore Psi EMW (ppg) Base Permafrost 2115 1800 Top Ugnu 6273 3170 1427 8.66 Top Ugnu M 7015 3400 1530 8.65 NA 7793 3641 1638 8.65 NB 7890 3671 1652 8.65 NC 7993 3703 1666 8.65 NE 8064 3725 1676 8.65 NF 8219 3773 1698 8.65 Top OA 8339 3810 1715 8.66 Base OA 8443 3842 1729 8.65 Top OB 9200 3874 1743 8.65 Base OB 3897 1754 8.66 ECEtYED 4.5. Casin.q/Tubincl Pro;ram Schrader Bluff Tract 14 2000 Pro~lram M PJ-~4 Permit Hole Size Csg/ Wt/R Grade Conn Length Top Bottom Tbg O.D. MDn'VDrkb MD/TVDrkb 30" 20" 92# H-40 Welded 80' 30'/30' 110'/110' 9-7/8" 7" 26# L-80 Hydril 521 8710' 30'/30' 8,740'/3,951' 6-1/8" OB 4 Y2" 12.6# L-80 IBT-Mod 3,321' 8,640'/3,951' 11,961'/3,891' 6-1/8" CA 4 1~,, 12.6# L-80 IBT-Mod 3,594' 8,360'/3,882' 11,954'/3,818' Tubing 3 ½" Jet Pump 9.3# L-80 EUE-Mod 7,770' 30'/30' 7,800'/3,709' 4.6. Cement Calculations ICasin Sizoe 17" 26 Ib/ft L-80 Hydril 521 I BasisI 250 Yo excess over gau,g,e 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 Total Cement Volume: Spacer 75 bbls of B45 Viscosified Spacer Weighted to 10.5 ppg Lead 905 sx 716 bbl 10.7 lb/gal Arctic Set III Light Tail 609 sx 127 bbl 15.8 lb/gal Class G Temp BHST -80° F from SOR, BHCT 85° F estimated by Dowell 4.6.1. Casing Spaceout a) 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 CA sand to allow for the window to be milled just below the top of the CA sand and in the middle of a full joint of casing. Run full casing joints across the CA sand. Any casing pup joints required for spaceout should be placed below the base of the CA sand. b) A radioactive tag should be placed in the casing string at 100' above the CA sands. c) Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required spaceout. 4.6.2. 7" String Centralizer Placement a) b) Do not run centralizers on the 2 joints of 7" casing spaced across the upper CA sand. With the exception stated above, 7' straight blade rigid centralizers should be run floating in the middle of each joint of casing from the 7" casing shoe up to 7300' MD (500' MD above NA sand). Zonal isolation with cement is required between the top of the CA and base of the N sands. 4.6.3. 4 ½" Slotted Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint with no stop collar (i.e. free floating across the whole length of the joint). 4.7. Survey and Lo;~in_~ Program 9-7/8" Hole Section: Open Hole: Cased hole: 6-1/8" Hole Sections: Cased Hole: MWD / GR/Res / PWD / ABI / Caliper - (Resistivity over production interval only) None MWD / GR/Res I PWD / ABI I ABGR - (ABGR may re run if avai!e_ble) None 4.8. Bit Recommendations Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit BHA Hole Size Depths (MD) Bit Type Nozzle / K-Rev's Hours Number and Section Flow Rate I & 2 9-7/8" 0 - 8,740 Baker Hughes MX-C1 Roller Cone 600 gpm 3 (OB lat.) 6-1/8" 8,740'- 11,961' PDC 25O+ gpm ~ ~ 4 (OA lat.) 6-1/8" 8,740' - 11,954' PDC 250+ gpm - - 4.9. Motors and Required Doqle.qs Drilling Motor Size and Motor Required Flow Rate RPM's Required Doglegs BHA No. 1 & 2 6 s~,, Sperrydrill 7/8, 3 stg Slow Speed, 1.5° 600 gpm 170 4 degree initial build adj with 9.6" sleeve 8 degree final build 3 & 4 4 ~" Sperrydrill 4/5, 6.3 stg FTC 250 gpm 100 Build out of window at 10- Performance, 1.5° or 1.15° adj with 5.8" 14°/100 to horizontal. sleeve Schrader Bluff Tract 14 2000 Pro~lram MPJ-PP4 Permit 5. MPJ-224 Operations Summary 5,1, Pre-Ria Operations 1. Install 20" conductor 5.2. 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~,, Sperry MWD/LWD (GR-Res)/PWD and 5" drill pipe 3. Drill 9-7/8" surface hole as per directional plan Tangent angle 72°. Surface hole landed on OB at 91 ° 4. Wiper trip as required, condition mud with lubes and spot casing running lube pill prior to 7" casing run 5. 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 return to surface on first stage 6. Install FMC 11" 5m wellhead 7. NU 13-5/8" 5m BOP. Test BOP to 2000/250 psi 8. Lay down 5" drill pipe, PU 3 1/2" drill pipe 9. MU BHA with 6-1/8" PDC bit, 4 ~" MWD/LWD (GR-Res)/PWD/ABI/ABGR, 3 1/2" drill pipe 10. Drill out float equipment 11. Displace hole to 9.1 lb/gal Bara Drill mud 12. Drill 20' of new hole and perform FIT to >11.0 lb/gal 13. Drill 3220' 6-1/8" OB lateral geosteering and short tripping as required. Maintain Bara Drill mud properties 14. Wiper trip or reamer trip with Hole Opener at TD 15. Displace OB lateral with clean Bara Drill mud 16. Run 4 Y2" slotted liner with inner string to OB lateral TD and hang off in 7" casing 17. Make 7" mill run trip to 7" casing TD prior to setting Baker ML packer 18. Run 7" Baker ML packer on 3 ~" drill pipe with drill pipe setting tool and RA marker tag 19. Rig up Schlumberger 1-11/16" GR. Log packer on depth to place window at top of the OA interval. Set packer 20. Run in hole with MWD to determine orientation of ML packer 21. Make up Baker Window Master milling assembly with retrievable whipstock and MWD 22. Install whipstock in ML packer. Verify whipstock orientation with MWD 23. Shear off and mill window 24. MU BHA with 6-1/8" PDC bit, 4 ~" MWD/LWD (GR-Res)/PWD/ABI/ABGR, 3 ~" drill pipe 25. RIH. Displace hole to clean Bara Drill mud 26. Drill 3600' OA horizontal lateral 27. Wiper trip at or reamer trip with Hole Opener TD. Displace OA lateral with clean Bara Drill mud 28. Run 4 1/2" slotted liner to OA lateral TD - plop and drop 10' to 20' outside window 29. MU whipstock retrieving tool and MWD. RIH. Orient and jet whipstock face 30. Engage and pull whipstock free 31. MU 2-7/8" tubing stinger. RIH and wash down thru ML packer 32. MU Baker flow thru hollow guidestock and MWD. RIH and set guidestock in ML packer 33. Verify guidestock orientation with MWD 34. Displace 7" casing to 9.1 lb/gal completion fluid 35. L/D 3 1/2" drill pipe 36. Run 3 Y2" tubing and packer completion. Space out packer with the tailpipe 50' above the NA sand 37. Freeze protect tubing and annulus 38. Drop ball and set packer Completion will include sliding sleeve (for jet pump application), Baker Sentry gauge and ~" TEC wire to surface 39. Set tubing plug and BPV. ND BOP. Install and test tree 4O. RDMO WELLHEAD:FMCHorizonta111",5Mtbg. head fJiP J-224 11" x 3-1/2", EUE (btm) · .= · ~ Cellar Box ELEV -- 35.50' FMC tbg. hanger, 'H' BPV profile '; I 110' I 20. 92 lb/fi, H_40 Welded ~, ~ · i 3-1/2", 9.3 lb/fi, L-80, EUE-M a. Coupling OD: 4.5" = Drift/ID' 2.867"/2.992" ~ f, ~ Phoenix TEC Wire i/ 3-1/2"x1" Gas Lift Mandrel I i Selective X Nipple 2.813" ID · . Jet Pump Installed in Sliding Sleeve III Baker CMU Sliding Sleeve with 2.813 ID Selective X Profile m Phoenix Pressure Gauge (Internal Pressure) ~ /i: -~-~ Baker S3 Packer 7", 26#, L-80, BTC-M ! ]:,, No Go XN Nipple 2.75" ID Casing Drift: ! 6.151" , Wireline Entry Guide Casing iD: Multi-Lateral Junction 8,357' 6-1/8" CA Lateral TD 11,954' I Window in 7" casing @ 8,357' Well Inclination @ Window = 72 Degrees I Flow Thru Hollow Guide StOCkMulti. Lateral Packer ~' I~~n-~l- ............. 6-1/8" Open Hole Completion as ~ngency 7" Casing Shoe @ 8,737' · Well Inclination @ Shoe = 91.3 Degrees Reference Directional Plan WP3 ~ ~ ~,. ~~...' '" "'- - - ---- ... OB .... Horizontal PBTD I I 4-1/2" Slotted Liner & Hanger TD I I 6-1/8" Open Hole Completion as Contingency DATE REV. BY COMMENTS Milne Point Unit WELL: J-224 ML APl NO: 7/16/00 FJ Level 2 Multi-Lateral, 3-1/2" Jet Pump Completion l _ BP Exploration (Alaska) I ~~I~T'~ I North Slope Alaska Alaska State Plane 4 MilneMpj.224Point wP3MPJ[ DrillQuest'_ Current Well Properties UP ~224 Hodzom~ Cnerdlr, m~: ~.i~es: 6ol 5110A IKef. Geegl~ C(xx~m;des: 70: 27'07. i Nalh Rake. e: Tree N~lh 3000 - 1500 ~ ~o 1500 - Z'" II 0- MPJ-224 6O15110.45 N. 55191426 E 1691.84 N. 4~0.96 E 70, 27' 072878' N, 140= 34" 35.0e~2' W 66];It above Ideen Sea Le~l ~6~Xt above Slmctum Re~mflce Scale: linch = 1500ft .. -9000 -7500" -6000 I I I 11961.10ft MD 3891.30ff '~/D 3891.30 TVD MPJ-24 T2 - 3~26.30 TVD 2393.24 N, 7697.77 W MP$-24 T3. 3891.30 ~ 2582.86 N, 9796.$0 W End Dir: 9853.53fl MD, 3926.30ft TVD Begin Dir O 6.000~/100ft: 9704.25ft MD, 3929.25ff TVD End Dir: 8916.46ft MD, 3947.22ft TVD Decrease in Dir Rate O 6.00(7'/100ft: 8736.69ft MD, 3951.30ft TVD Begin Dir ~ 8.00(TY100ft: 8442.73ft MD, 3908.46ff TVD Eastings -4500 I -3000 -1500 0 I I I I -g000 Scale: linch = 1500ft MPJ.24 TI. 3P51.$0 TT~ 2438.47 N, 6583.43 W ~ 7' Casing - 8738.68 MD, 3951.30 TVD i5.76ft MD, 2106.68ff TVD 043.74ff MD, 1820.43ft TVD End Dir: 1862.34ft MD, 1700.65ft TVD e ~ 3.500°/100ft: 700.66ft MD, 699.57ft TVD ir Rate ~ 2.500°/100ft: 500.00ft MD, 499.91lt TVD n DJr ~ 1.500°/100ft: 300.00fl MD, 300.00ft TVD -3000 - 1500 Dir 0 1.500°/10Oft: ~.~ MD, 300.00ft TVD 0 2.500°/100ft: 500.00ft MD, 499.91ff TVD Increase in Dir Rate ~ 3.500°/100ft: 700.66ft MD, 699.57ft TVD 1700.65ft TVD Dir O 4.000°/100ft: 2043.74ft MD, -7500 -~ !astings 0 Reference is True North Veal~l Beton Odgbt: ksured Noflflfngs Ea~tlng~¥~ Do~f~ ~e~tlon Rate Single Well Target Date for MPJ-224 Ceetdlnat$ Pdnt TVD '1YD No41hlngu Elstlngs N~thfngs Type ss MPJ-2~4 [~illers~y hit-/Point 2508.59 N 6168.93 w 6011576.00 N · ~J~dax)- Po~t A 2511.48 .~ 656).9z w ~17576.~ N C Z742.8i ~ 9~98.39 w ~1718f.~ N 2~7.~ N 9~2.~ W~17410.~ N F 2~9.49 N 6586.0~ W 6017414.~ N ~J-2~ Fa~t ~' ~t 3535.~ ~l.~ 3038.3~ ~ 5419.19 W ~17111.~ B~'~t A ~1257 X 61~21 W6017680.~ N a ~58.~3 N 7~5.93 W 601171t.~ N C ~32.85 X 9794.~ W ~J191~.~ N 2251.67 ~ 9798.11 W ~JT~.~ ~ 2228.2~ ~ 7~8 92 W ~t12S~.m ~ t .82. N616S.51 w ~1735o.~ N ~l-~ II En~' ~t 3885.~ 3951.30 ~39.47 S 656~.43 W 601750).~ N .... Base Pemutfro~t - 1866.~;0 ~ - 3000 3000 i-'iii .': .L-' :'--1 :'---' '--i-"-"-" .': i :' :'-: ;' :'-'1 i--'-'-:'-:'-"-:--' i :' ii ii :'i-:ii--' i-'iii i i--' ':-:-" ~ H .'-' .'-'-:-"-".-:iii.':-."-"-:ii .................................................................................... 2438.47 ~V, 6~85.43 W 0 1500 3000 4500 6000 Scale: linch = 150Oft Vertical Section .......... Top tJgntt - 3256 30 'IVD MPJ-24 T2 - 3926.30 2393.24 ~, 7697.77 W I 750O ............................ Top Ugnu M - $4~6.30 TVD 11;11 h ~- 2sSZS6~, 9796.S0 w Total Depth: 11~1.10ft MD, ~91.3~l WD I I 4 1~' Uner - 11961.10 MD, ~91.30 ~D 9000 10500 Section Azimuth: 284.770° (True North) ~- Z-, ,* II ",-. -o Elll]rlgl Talbot ~lape P~)gon Spe/. y-Sun Drilling S~i'vices Proposal Data - MPJ-224 - MPJ-224 Wp3 2393.24 N, 7697.77 W 2582.86 NI9796.50 W 29 August, 2000 - 8:32 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured Depth Incl. Azim. (~t) 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 1.500 290.611 500.00 3.000 290.611 600.00 5.500 290.611 700.00 8.000 290.611 700.66 8.016 290.611 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (~) (~) (~) (~) -66.30 0.00 0.00 N 0.00 E 33.70 100.00 0.00 N 0.00E 133.70 200.00 0.00 N 0.00E 233.70 300.00 0.00N 0.00E 333.69 399.99 0.46N 1.23W 433.61 499.91 1.64N 4.90W 533.33 632.62 633.27 800.00 11.493 290.611 731.17 900.00 14.993 290.611 828.49 1000.00 18.493 290.611 924.24 1100.00 21.993 290.611 1018.05 1200.00 25.493 290.611 1109.57 1300.00 28.993 290.611 1198.46 1400.00 32.493 290.611 1284.39 1500.00 - 35.993 290.611 1367.05 1600.00 39.493 290.611 1446.11 1700.00 42.993 290.611 1521.29 1800.00 46.493 290.611 1592.31 1862.34 48.675 290.611 1634.35 1900.00 48.675 290.611 1659.22 2000.00 48.675 290.611 1725.25 2043.74 48.675 290.611 1754.13 2100.00 50.926 290.611 1790.45 599.63 4.45N 11.84W 698.92 8.59 N 22.84W 699.57 8.62N 22.92W 797.47 14.55 N 38.67W 894.79 22.61N 60.11W 990.54 32.75 N 87.07W 1084.35 44.93 N 119.46W 1175.87 59.10 N 157.14W 1264.76 75.21N 199.98W 1350.69 93.20 N 247.82W 1433.35 113.01N 300.48W 1512.41 134.55 N 357.76W 1587.59 157.76N 419.46W 1658.61 182.53 N 485.34W 1700.65 198.73 N 528.41W 1725.52 208.69 N 554.88W 1791.55 235.12 N 625.18W 1820.43 245.69 N 655.92W 1856.75 261.81N 696.14W Global Coordinates Dogleg Northings Eeatings Rate (ft) (ft) (°/lOOft) 6015110.45 N 551914.26 E 6015110.45N 551914.26 E 0.000 6015110.45N 551914.26 E 0.000 6015110.45 N 551914.26 E 0.000 6015110.90 N 551913.03E 1.500 6015112.26 N 551909.35 E 1.500 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) 0.00 0.00 0.00 0.00 1.30 5.21 6015114.82 N 551902.39 E 2.500 12.58 6015118.88 N 551891.36E 2.500 24.27 6015118.91N 551891.28 E 2.500 24.36 6015124.73 N 551875.49 E 3.500 41.10 6015132.64 N 551853.99 E 3.500 63.89 6015142.59 N 551826.96E 3.500 92.55 6015154.54 N 551794.49 E 3.500 126.96 6015168.45 N 551756.72 E 3.500 167.01 6015184.27 N 551713.76 E 3.500 212.54 6015201.92 N 551665.80 E 3.500 263.39 6015221.36 N 551613.00E 3.500 319.36 6015242.51N 551555.57 E 3.500 380.24 6015265.28 N 551493.71E 3.500 445.82 6015289.60 N 551427.66E 3.500 515.83 6015305.50 N 551364.48 E 3.500 561.61 6015315.27 N 551357.94E 0.000 589.75 6015341.21N 551287.46 E 0.000 664.46 6015352.56N 551256.64 E 0.000 697.13 6015367.41N 551216.31E 4.000 739.88 Comment 3Be0~.in Dir @ 1.500°/100ft: 00fi MD, 300.00ft TVD Increase in Dir Rate @ 2.500°/100ft: 500.00ft MD, 499.91ft TVD Increase in Dir Rate @ 3.500°/100ff: 700.66ft MD, 699.57ff TVD End Dir: 1862.34ft MD, 1700.65ft TVD Be~in Dir @ 4.000°/100ft: 204~3.74ft MD, 1820.43ft TVD Continued... 29 August, 2000 - 8:32 - 1 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (~t) (ft) 2115.26 51.536 290.611 1800.00 1866.30 2200.00 54.926 290.611 1850.72 1917.02 2300.00 58.926 290.611 1905.28 1971.58 2400.00 62.926 290.611 1953.86 2020.16 2500.00 66.926 290.611 1996.23 2062.53 2600.00 70.926 290.611 2032.19 2098.49 2625.76 71.956 290.611 2040.38 2106.68 2700.00 71.956 290.611 2063.38 2129.68 2800.00 71.956 290.611 2094.35 2160.65 2900.00 71.956 290.611 2125.33 2191.63 3000.00 71.956 290.611 2156.30 2222.60 3100.00 71.956 290.611 2187.28 2253.58 3200.00 71.956 290.611 2218.25 2284.55 3300.00 71.956 290.611 2249.23 2315.53 3400.00 71.956 290.611 2280.20 2346.50 3500.00 71.956 290.611 2311.18 2377.48 3600.00 71.956 290.611 2342.15 2408.45 3700.00 71.956 290.611 2373.13 2439.43 3800.00 71.956 290.611 2404.10 2470.40 3900.00 71.956 290.611 2435.07 2501.37 4000.00 71.956 290.611 2466.05 2532.35 4100.00 71.956 290.611 2497.02 2563.32 4200.00 71.956 290.611 2528.00 2594.30 4300.00 71.956 290.611 2558.97 2625.27 4400.00 71.956 290.611 2589.95 2656.25 Local Coordinates Global Coordinates Northings Eastinge Northings Eastings (ft) (ft) (ft) (ft) 266.00 N 707.27 W 6015371.52 N 551205.15 E 289.89 N 770.80 W 6015394.97 N 551141.46 E 319.39 N 849.22 W 6015423.91 N 551062.84 E 350.15 N 931.01 W 6015454.10 N 550980.84 E 382.02 N 1015.77 W 6015485.39 N 550895.85 E 414.86 N 1103.09 W 6015517.62 N 550808.31 E 423.46 N 1125.95 W 6015526.05 N 550785.39 E 448.31 N 1192.02 W 6015550.44 N 550719.15 E 481.78 N 1281.01 W 6015583.29 N 550629.92 E 515.25 N 1370.01 W 6015616.14 N 550540.69 E 548.72 N 1459.01 W 6015548.99 N 550451.47 E 582.19 N 1548.00 W 6015681.84 N 550362.24 E 615.66 N 1637.00 W 6015714.69 N 550273.01 E 649.13 N 1726.00 W 6015747.54 N 550183.78 E 682.60 N 1814.99 W 6015780.39 N 550094.56 E 716.07 N 1903.99 W 6015813.24 N 550005.33 E 749.54 N 1992.98 W 6015846.09 N 549916.10 E 783.01 N 2081.98 W 6015878.94 N 549826.88 E 816.48 N 2170.98 W 6015911.79 N 549737.65 E 849.95 N 2259.97 W 6015944.64 N 549648.42 E 883.42 N 2348.97 W 6015977.48 N 549559.19 E 916.89 N 2437.96 W 6016010.33 N 549469.97 E 950.36 N 2526.96 W 6016043.18 N 549380.74 E 983.83 N 2615.96 W 6016076.03 N 549291.51 E 1017.30 N 2704.95 W 6016108.88 N 549202.28 E Dogleg Rate (°/lOOft) 4.000 4.000 4.0(X) 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (fi) 751.72 819.24 902.58 989.51 1079.60 1172.41 1196.70 1266.92 1361.51 1456.10 1550.69 1 645.28 1739.86 1834.45 1929.04 2023.63 2118.22 2212.81 2307.39 2401.98 2496.57 2591.16 2685.75 2780.34 2874.92 Comment Base Permafrost End Dir: 2625.76ft MD, 2106.68ft TVD Continued... 29 August, 2000- 8:32 - 2 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured- Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) 4500.00 71.956 290.611 2620.92 2687.22 4600.00 71.956 290.611 2651.90 2718.20 4700.00 71.956 290.611 2682.87 2749.17 4800.00 71.956 290.611 2713.85 2780.15 4900.00 71.956 290.611 2744.82 2811.12 5000.00 71.956 290.611 2775.79 2842.09 5100.00 71.956 290.611 2806.77 2873.07 5200.00 71.956 290.611 2837.74 2904.04 5300.00 71.956 290.611 2868.72 2935.02 5400.00 71.956 290.611 2899.69 2965.99 5500.00 71.956 290.611 2930.67 2996.97 5600.00 71.956 290.611 2961.64 3027.94 5700.00 71.956 290.611 2992.62 3058.92 5800.00 71.956 290.611 3023.59 3089.89 5900.00 71.956 290.611 3054.57 3120.87 6000.00 71.956 290.611 3085.54 3151.84 6100.00 71.956 290.611 3116.51 3182.81 6200.00 71.956 290.611 3147.49 3213.79 6272.68 71.956 290.611 3170.00 3236.30 6300.00 71.956 290.611 3178.46 3244.76 6400.00 71.956 290.611 3209.44 3275.74 6500.00 71.956 290.611 3240.41 3306.71 6600.00 71.956 290.611 3271.39 3337.69 6700.00 71.956 290.611 3302.36 3368.66 6800.00 71.956 290.611 3333.34 3399.64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1050.77 N 2793.95 W 6016141.73 N 549113.06 E 1084.24 N 2882.95 W 6016174.58 N 549023.83 E 1117.71 N 2971.94 W 6016207.43 N 548934.60 E 1151.18 N 3060.94 W 6016240.28 N 548845.38 E 1184.65 N 3149.93 W 6016273.13 N 548756.15 E 1218.12 N 3238.93 W 6016305.98 N 548666.92 E 1251.59 N 3327.93 W 6016338.83 N 548577.69 E 1285.06 N 3416.92 W 6016371.68 N 548488.47 E 1318.53 N 3505.92 W 6016404.53 N 548399.24 E 1352.00 N 3594.92 W 6016437.38 N 548310.01 E 1385.47 N 3683.91 W 6016470.22 N 548220.79 E 1418.94 N 3772.91 W 6016503.07 N - 548131.56 E 1452.41 N 3861.90 W 6016535.92 N 548042.33 E 1485.88 N 3950.90 W 6016568.77 N 547953.10 E 1519.35 N 4039.90 W 6016601.62 N 547863.88 E 1552.82 N 4128.89 W 6016634.47 N 547774.65 E 1586.29 N 4217.89 W 6016667.32 N 547685.42 E 1619.76 N 4306.89 W 6016700.17 N 547596.19 E 1644.09 N 4371.56 W 6016724.04 N 547531.35 E 1653.24 N 4395.88 W 6016733.02 N 547506.97 E 1686.71 N 4484.88 W 6016765.87 N 547417.74 E 1720.18 N 4573.87 W 6016798.72 N 547328.51 E 1753.65 N 4662.87 W 6016831.57 N 547239.29 E 1787.12 N 4751.87 W 6016864.42 N 547150.06 E 1820.59 N 4840.86 W 6016897.27 N 547060.83 E Dogleg Rate (°ll00ff) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (~) 2969.51 3064.10 3158.69 3253.28 3347.87 3442.45 3537.04 3631.63 3726.22 3820.81 3915.40 4009.98 4104.57 4199.16 4293.75 4388.34 4482.93 4577.51 4646.26 4672.10 4766.69 4861.28 4955.87 5050.46 5145.05 Comment Top Ugnu Continued... 29 August, 2000 - 8:32 - 3 - Dr#/Quest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) 6900.00 71.956 290.611 3364.31 3430.61 7000.00 71.956 290.611 3395.29 3461.59 7015.22 71.956 290.611 3400.00 3466.30 7100.00 71.956 290.611 3426.26 3492.56 7200.00 71.956 290.611 3457.23 3523.53 7300.00 71.956 290.611 3488.21 3554.51 7400.00 71.956 290.611 3519.18 3585.48 7500.00 71.956 290.611 3550.16 3616.46 7600.00 71.956 290.611 3581.13 3647.43 7700.00 71.956 290.611 3612.11 3678.41 7793.28 71.956 290.611 3641.00 3707.30 7800.00 71.956 290.611 3643.08 3709.38 7890.13 71.956 290.611 3671.00 3737.30 7900.00 71.956 290.611 3674.06 3740.36 7993.44 71.956 290.611 3703.00 3769.30 8000.00 71.956 290.611 3705.03 3771.33 8064.47 71.956 290.611 3725.00 3791.30 8100.00 71.956 290.611 3736.01 3802.31 8200.00 71.956 290.611 3766.98 3833.28 _ 8219.43 71.956 290.611 3773.00 3839.30 8300.00 71.956 290.611 3797.95 3864.25 8338.89 71.956 290.611 3810.00 3876.30 8400.00 71.956 290.611 3828.93 3895.23 8442.73 71.956 290.611 3842.16 3908.46 8500.00 75.676 287.824 3858.13 3924.43 Local Coordinates Northings Eastings (ft) (ft) 1854.06 N 4929.86 W 1887.53 N 5018.85 W 1892.62 N 5032.40 W 1921.00 N 5107.85 W 1954.47 N 5196.85 W 1987.94 N 5285.84 W 2021.41 N 5374.84 W 2054.88 N 5463.84 W 2088.35 N 5552.83 W 2121.82 N 5641.83 W 2153.04 N 5724.84 W 2155.29 N 5730.82 W 2185.46 N 5811.04 W 2188.76 N 5819.82 W 2220.03 N 5902.98 W 2222.23 N 5908.82 W 2243.81 N 5966.19 W 2255.70 N 5997.81 W 2289.17 N 6086.81 W 2295.67 N 6104.10 W 2322.64 N 6175.81 W 2335.65 N 6210.41 W 2356.11 N 6264.80 W 2370.41 N 6302.83 W 2388.50 N 6354.75 W Global Coordinates Northings Eastings (ft) (ft) 6016930.12 N 546971.60 E 6016962.96 N 546882.38 E 6016967.96 N 546868.80 E 6016995.81 N 546793.15 E 6017028.66 N 546703.92 E 6017061.51 N 546614.70 E 6017094.36 N 546525.47 E 6017127.21 N 546436.24 E 6017160.06 N 546347.01 E 6017192.91 N 546257.79 E 6017223.55 N 546174.56 E 6017225.76 N 546168.56 E 6017255.37 N 546088.14 E 6017258.61 N 546079.33 E 6017289.30 N 545995.96 E 6017291.46 N 545990.10 E 6017312.64 N 545932.58 E 6017324.31 N 545900.88 E 6017357.16 N 545811.65 E 6017363.54 N 545794.31 E 6017390.01 N 545722.42 E 6017402.78 N 545687.73 E 6017422.86 N 545633.20 E 6017436.89 N 545595.07 E 6017454.62 N 545543.02 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 0.000 0.000 o.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 8.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 5239.63 5334.22 5348.62 5428.81 5523.40 5617.99 5712.58 5807.16 5901.75 5996.34 6084.57 6090.93 6176.18 6185.52 6273.90 6280.11 6341.09 6374.69 6469.28 6487.66 6563.87 6600.65 6658.46 6698.88 6753.70 Comment Top Ugnu M Schrader NA Schrader NB Schrader NC Schrader NE Schrader NF Schrader OA 44492in Dir @ 8.000°/100ft: .73ft MD, 3908.46ft TVD Continued... 29 August, 2000- 8:32 -4- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (fi) (ft) 8600.00 82.240 283.163 3877.28 8700.00 88.854 278.646 3885.04 8736.69 91.284 277.000 3885.00 8800.00 91.297 273.200 3883.57 8900.00 91.307 267.199 3881.30 8916.46 91.307 266.211 3880.92 9000.00 91.307 266.211 3879.02 9100.00 91.307 266.211 3876.74 9200.00 91.307 266.211 3874.45 9300.00 91.307 266.211 3872.17 9400.00 91.307 266.211 3869.89 9500.00 91.307 266.211 3867.61 9600.00 91.307 266.211 3865.33 9700.00 91.307 266.211 3863.05 9704.25 91.307 266.211 3862.95 9800.00 91.082 271.953 3860.95 9853.53 90.951 275.163 3860.00 9900.00 90.952 275.163 3859.23 10000.00 90.952 275.163 3857.57 10100.00 90.952 275.163 3855.91 3943.58 2414.65 N 6449.27W 6017480.11N 545448.33 E 3951.34 2433.48 N 6547.09W 6017498.26 N 545350.38 E 3951.30 2438.47 N 6583.43W 6017503.00 N 545314.00 E 3949.87 2444.10 N 6646.47W 6017508.18 N 545250.93 E 3947.60 2444.44 N 6746.39W 6017507.83 N 545151.00E 3947.22 2443.50 N 6762.82W 6017506.77 N 545134.58 E 3945.32 2437.98 N 6846.16W 6017500.67 N 545051.28 E 3943.04 2431.37 N 6945.91W 6017493.37 N 544951.58 E 3940.75 2424.77 N 7045.67W 6017486.07 N 544851.87 E 3938.47 2418.16 N 7145.42W 6017478.77 N 544752.16 E 3936.19 2411.55 N 7245.18W 6017471.47 N 544652.45 E 3933.91 2404.95 N 7344.94W 6017464.17 N 544552.75 E 3931.63 2398.34 N 7444.69W 6017456.87 N 544453.04 E 3929.35 2391.73 N 7544.45W 6017449.56 N 544353.33 E 3929.25 2391.45 N 7548.68W 6017449.25 N 544349.10 E 3927.25 2389.92N 7644.36W 6017447.05 N 544253.43 E 3926.30 2393.24 N 7697.77W 6017450.00 N 544200.00 E 3925.53 2397.42N 7744.05W 6017453.86 N 544153.70 E 3923.87 2406.42N 7843.63W 6017462.16 N 544054.06 E 3922.21 2415.41N 7943.21W 6017470.47 N 543954.41E Dogleg Rate (°/100ft) 8.000 8.000 8.000 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 6.000 6.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (ft) 6851.76 6951.14 6987.56 7049.94 7146.66 7162.30 7241.48 7336.25 7431.03 7525.80 7620.58 7715.35 7810.13 7904.90 7908.93 8001.05 8053.54 8099.36 8197.94 8296.53 Comment Decrease in Dir Rate @ 6.000°/100ff: 8736.69fl MD, 3951.30ft TVD 7' Casin= Target - ~PJ-24 T1 End Dir: 8916.46ft MD 3947.22ft TVD ' 9/~70q4in DJr @ 6.000°/100ft: .25ft MD, 3929.25ft TVD End Dir: 9853.53ft MD, 3926.30ft TVD Target - MPJ-24 T2 Continued... 29 August, 2000 - 8:32 - 5 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10200,00 90.952 275.163 3854.25 3920.55 10300.00 90.952 275.163 3852.59 3918.89 10400.00 90.952 275.163 3850.93 3917.23 10500.00 90.952 275.163 3849.26 3915.56 10600.00 90.952 275.163 3847.60 3913.90 10700.00 90.952 275.163 3845.94 3912.24 10800.00 90.952 275.1 63 3844.28 3910.58 10900.00 90.952 275.1 63 3842.62 3908.92 11000.00 90.952 275.163 3840.96 3907.26 11100.00 90.952 275.163 3839.30 3905.60 11200.00 90.952 275.163 3837.64 3903.94 11300.00 90.952 275.163 3835.98 3902.28 11400.00 90.952 275.163 3834.32 3900.62 11500.00 90.952 275.163 '3832.66 3898.96 11600.00 90.952 275.163 3831.00 3897.30 11700.00 90.952 275.163 3829.34 3895.64 11800.00 90.952 275.163 3827.68 3893.98 11900.00 90.952 275.163 3826.01 3892.31 11961.10 90.952 275.163 3825.00 3891.30 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2424.41 N 8042.79 W 6017478.77 N 543854.77 E 2433.41 N 8142.37 W 6017487.07 N 543755.13 E 2442.41 N 8241.95 W 6017495.38 N 543655.49 E 2451.40 N 8341.53 W 6017503.68 N 543555.85 E 2460.40 N 8441.11 W 6017511.98 N 543456.21 E 2469.40 N 8540.69 W 6017520.29 N 543356.57 E 2478.39 N 8640.27 W 6017528.59 N 543256.93 E 2487.39 N 8739.86 W 6017536.89 N 543157.29 E 2496.39 N 8839.44 W 6017545.19 N 543057.65 E 2505.39 N 8939.02 W 6017553.50 N 542958.01 E 2514.38 N 9038.60 W 6017561.80 N 542858.37 E 2523.38 N 9138.18 W 6017570.10 N 542758.72 E 2532.38 N 9237.76 W 6017578.41 N 542659.08 E 2541.37 N 9337.34 W 6017586.71 N 542559.44 E 2550.37 N 9436.92 W 6017595.01 N 542459.80 E 2559.37 N 9536.50 W 6017603.32 N 542360.16 E 2568.37 N 9636.08 W 6017611.62 N 542260.52 E 2577.36 N 9735.66 W 6017619.92 N 542160.88 E 2582.86 N 9796.50 W 6017625.00 N 542100.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPJ-224. Northings and Eastings are relative to MPJ-224. Dogleg Rate (°/lOOft) 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPJ Vertical Section (~) 8395.11 8493.70 8592.28 8690.86 8789.45 8888.03 8986.61 9085.20 9183.78 9282.37 9380.95 9479.53 9578.12 9676.70 9775.29 9873.87 9972.45 10071.04 10131.27 Comment Total Deoth: 11961.10ft MD, 3891.30ft TVD 4 1/2" Liner Target - MPJ-24 T3 The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPJ-ML2 and calculated along an Azimuth of 284.770° (True). 29 August, 2000 - 8:32 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 11961.10ft., The Bottom Hole Displacement is 10131.27ft., in the Direction of 284.770° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (fi) (ft) 300.00 300.00 0.00 N 0.00 E 500.00 499.91 1.84 N 4.90 W 700.66 699.57 8.62 N 22.92 W 1862.34 1700.65 198.73 N 528.41 W 2043.74 1820.43 246.69 N 655.92 W 2625.76 2106.68 423.46 N 1125.95 W 8442.73 3908.46 2370.41 N 6302.83 W 8736.69 3951.30 2438.47 N 6583.43 W 8916.46 3947.22 2443.50 N 6762.82 W 9704.25 3929.25 2391.45 N 7548.68 W 9853.53 3926.30 2393.24 N 7697.77W 11961.10 3891.30 2582.86 N 9796.50W Comment Begin Dir @ 1.500°/100ff: 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 2.500°/100ft: 500.00ft MD, 499.91ft TVD Increase in Dir Rate @ 3.500°/100ft: 700.66ft MD, 699.57ft TVD End Dir: 1862.34ft MD, 1700.65ft TVD Begin Dir @ 4.000°/100ft: 2043.74ft MD, 1820.43ft TVD End Dir: 2625.76ft MD, 2106.68ft TVD Begin Dir @ 8.000°/100ft: 8442.73ft MD, 3908.46ft TVD Decrease in Dir Rate @ 6.000°/100ft: 8736.69ft MD, 3951.30ft TVD End Dir: 8916.46ft MD, 3947.22ft TVD Begin Dir @ 6.000°/100ft: 9704.25ft MD, 3929.25ft TVD End Dir: 9853.53ft MD, 3926.30ft TVD Total Depth · 11961.10ft MD, 3891.30ft TVD Alaska State Plane 4 Milne Point MPJ Continued... 29 August, 2000 - 8:32 - 7- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (~t) 2115.26 1866.30 1800.00 266.00 N 707.27 W Base Permafrost 6272.68 3236.30 3170.00 1644.09 N 4371.56 W Top Ugnu 7015.22 3466.30 3400.00 1892.62 N 5032.40 W Top Ugnu M 7793.28 3707.30 3641.00 2153.04 N 5724.84 W Schrader NA 7890.13 3737.30 3671.00 2185.46 N 5811.04 W Schrader NB 7993.44 3769.30 3703.00 2220.03 N 5902.98 W Schrader NC 8064.47 3791.30 3725.00 2243.81 N 5966.19 W Schrader NE 8219.43 3839.30 3773.00 2295.67 N 6104.10 W Schrader NF 8338.89 3876.30 3810.00 2335.65 N 6210.41 W Schrader OA Casing details From Measured Vertical Depth Depth (ft) (ft) 9300.00 3938.47 <Surface> <Surface> To Measured Depth (ft) 8736.68 11961.10 Vertical Depth Casing Detail (ft) 3951.30 7" Casing 3891.30 4 1/2" Liner Continued... 29 August, 2000 - 8:32 - 8 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPJ Targets associated with this wellpath Target Name MPJ-224 polygon MPJ-24 T1 MPJ-24 T2 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 #5 #6 Mean Sea Level/Global Coordinates #1 #2 #3 #4 #5 #6 Geographical Coordinates #1 #2 #3 #4 #5 #6 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3926.30 2612.57 N 6166.21 W 3860.00 6017680.00 N 545730.00 E 70° 27' 32.9592" N 149° 37' 36.2714" W 3926.30 2612.57 N 6166.21 W 3926.30 2658.23 N 7695.93 W 3926.30 2932.85 N 9794.06 W 3926.30 2257.87 N 9798.77 W 3926.30 2228.24 N 7698.92 W 3926.30 2282.58 N 6168.51 W 3860.00 6017680.00 N 545730.00 E 3860.00 6017715.00 N 544200.00 E 3860.00 6017975.00 N 542100.00 E 3860.00 6017300.00 N 542100.00 E 3860.00 6017285.00 N 544200.00 E 3860.00 6017350.00 N 545730.00 E 70° 27' 32.9592B N 149° 37' 36.2714" W 70° 27' 33.3943" N 149° 38' 21.2216" W 70° 27' 36.0712" N 149° 39' 22.8836" W 70° 27' 29.4322" N 149° 39' 22.9957" W 70° 27' 29.1650" N 149° 38' 21.2966" W 70° 27' 29.7135" N 149° 37' 36.3309u W 3951.30 2438.47 N 6583.43 W 3885.00 6017503.00 N 545314.00 E 70° 27' 31.2433" N 149° 37' 48.5264" W 3926.30 2393.24 N 7697.77 W 3860.00 6017450.00 N 544200.00 E 70° 27' 30.7879" N 149° 38' 21.2678" W Target Shape Polygon Point Point Target Type 29 August, 2000 - 8:32 - 9 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPJ-224 Wp3 Revised: 29 August, 2000 North Slope Alaska Target Name MPJ-24 T3 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3891.30 2582.86 N 9796.50 W 3825.00 6017625.00 N 542100.00 E 70° 27' 32.6288' N 149° 39' 22.9418" W Alaska State Plane 4 Milne Point MPJ Target Target Shape Type Point 29 August, 2000 - 8:32 - 10 - DrillQuest 1.05.05a H 1 72561 ~o~/ooI ~o~==~ VENDOR ALASKASTAT 1_~_._~ DATE INVOI~E / CREDIT MEIVlO DESCRIPTION GROS~ DISCOUNT NET 100. O0 080200 ~K080200C ~ INST' SONDI I/~ X4750 100.00 THE A1TACHEO CHECK IS IN PAYMENT FQR ITEMS DESCRIBED ABOVE. :'~ ~IST':'~TI0~'~-:BAN I~':~F A~"H~AND ';-::-:?: ,:'~.::'-:" :'~,~i'~.~'UA'r,=;.i~ :-::~-":." ':::: :'-' .- -!::.?~? ::....'..-.. N:~,jC'lb~;~lTy:eAhK :...:: i'..; i: :.'::.?:.-:,::.;~' .'i~£~vsi~lO, 6'Hib '.:'.': ."..:'" 412 .... '~, ', ~n:~nqc~: OORt, t, WELL PERMIT CHECKLIST FIELD & POOL ,~*~"/~//,""'~) ADMINISTRATION COMPANY ENGINEERING DATE GEOLOGY II IA~P~A~R 'pATE '/. WELL NAME ~-/"~ PROGRAM: exp ~ dev~ GEOL AREA ~:~"~"~ 1. Permit fee attached ........................ 2. Lease number appropriate,'~'.~c,¢...d.~3".;~. ~ ! .~O.- ~¢~/. 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... v/reddl )N N ~ serv ~ wellbore seg ann. disposal para req UNIT# ~) //,..~ ~-~. ON/OFF SHORE 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 ............. 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 ;~ ~r~ r~sig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... (~.. 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ........... ':...,/[,,~[ Y N 33. Seabed condition survey (if off-shore) ....... ; .,,~..: - Y N 34. Contact name/phone for weekly progress reports./,~W3'/omto~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste.... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEO_~~: ENGINEERING: U~lAnnular COMMISSION: Commentsllnstructions: O Z -I -r' c:\msoffice\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. o. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Aug 14 19:21:56 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ......... ' ........ STS LIS Writing Library. Scientific Technical Services 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: MWD RUN 1 AK-MM-00220 M. HANIK E. VAUGHN MPJ-24 500292297600 BP Exploration (Alaska), Inc. Sperry Sun 14-AUG-01 MWD RUN 2 MWD RUN 3 AK-MM-00220 AK-MM-00220 R. FRENCH R. FRENCH E. VAUGHN E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-00220 J. FOLEY J. PYRON 28 13N 10E 2713 3402 .00 66.05 36.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 20.000 110.0 2ND STRING 9.875 7.000 8663.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). SGRC IS LOGGED BEHIND CASING FROM 8603' MD, 3917' TVD TO 8663' MD, 3920' TVD. EWR4 IS LOGGED BEHIND CASING FROM 8613' MD, 3917' TVD TO 86633' MD, 3920' TVD. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE ON 04/19/01 FROM D. SCHNOOR FOR T. WALSH OF BP EXPLORATION ALASKA, INC.. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL MPJ-24 WITH API ~ 50-029-22976-00. THIS WELL REACHED A TOTAL DEPTH OF 11975' MD, 3858' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 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 START DEPTH STOP DEPTH GR 100 0 11901.'5 ROP 141 5 11974.5 FET 2721 5 11908.5 RPD 2721 5 11908.5 RPM 2721 5 11908.5 RPS 2721 5 11908.5 RPX 2721 5 11908.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 100.0 2779.0 2 2780.0 6437.0 3 6437.5 8674.0 4 8674.5 11974.5 MERGED MAIN PASS. $ 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 100 11974.5 ROP MWD FT/H 4.93 1273.69 GR MWD API 15.44 117.45 RPX MWD OHMM 0.27 1274.88 RPS MWD OHMM 0.33 1646.89 RPM MWD OHMM 0.2 2000 RPD MWD OHMM 0.2 2000 FET MWD HR 0.17 124.71 Mean Nsam 6037.25 23750 193.598 23667 66,7842 23604 12,7944 18375 14.1886 18375 19.8023 18375 20.6151 18375 1.84253 18375 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 11974.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,002 First Reading 100 141.5 100 2721,5 2721.5 2721.5 2721.5 2721.5 Last Reading 11974.5 11974.5 11901.5 11908.5 11908.5 11908.5 11908.5 11908.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 100.0 2730.0 ROP 141.5 2779.0 $ LOG HEADER DATA DATE LOGGED: 10-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05,2 DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2779.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 70.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01682HWGV6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Spud MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 152.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 420 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 69.4 MUD FILTRATE AT MT: ,000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max DEPT FT 100 2779 ROP MWD010 FT/H 4.93 546.06 GR MWD010 API 20.47 117.42 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 2779 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean 1439.5 169.656 63.7506 Nsam 5359 5276 5261 First Reading 100 141.5 100 Last Reading 2779 2779 2730 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name,,, Version Number ........... 1.0,0 Date of Generation ....... 01/08/14 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 2721.5 6376.5 RPD 2721.5 6376.5 RPS 2721.5 6376.5 RPX 2721.5 6376.5 FET 2721.5 6376.5 GR 2730.5 6368.0 ROP 2779.5 6437.0 $ LOG HEADER DATA DATE LOGGED: 12-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6437.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.1 MAXIMUM ANGLE: 75.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01688HWGRM6 PB01688HWGRM6 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 9.875 Water Based 9.20 74.0 9.2 300 5.2 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 I 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 5.000 72.0 5.420 65.9 9.000 72.0 3.500 72.0 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 2721.5 6437 ROP MWD020 FT/H 29.4 756.33 GR MWD020 API 15.44 117.45 RPX MWD020 OHMM 4.12 33.68 RPS MWD020 OHMM 4.04 1646.89 RPM MWD020 OHMM 1.85 2000 RPD MWD020 OHMM 1.68 1901.8 FET MWD020 HR 0.17 9.49 First Reading For Entire File .......... 2721.5 Last Reading For Entire File ........... 6437 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean 4579.25 248.934 65.6443 11,1415 11.605 12.3 12.7064 0.816222 Nsam 7432 7316 7276 7311 7311 7311 7311 7311 First Reading 2721.5 2779.5 2730.5 2721.5 2721.5 2721.5 2721.5 2721.5 Last Reading 6437 6437 6368 6376.5 6376.5 6376.5 6376.5 6376.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: ,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6368.5 8605.0 FET 6377.0 8613.5 RPD 6377.0 8613.5 RPM 6377.0 8613.5 RPS 6377.0 8613.5 RPX 6377.0 8613.5 ROP 6437.5 8674.0 $ LOG HEADER DATA DATE LOGGED: 14-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8674.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.8 MAXIMUM ANGLE: 87,1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01688HWGRM6 EWR4 ELECTROMAG. RESIS. 4 PB01688HWGRM6 $ BOREROLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 8663.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 67.0 MUD PR: 9,4 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3,000 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 31.804 76,5 MUD FILTRATE AT MT: 6.000 65.0 MUD CAKE AT MT: 5.000 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 6368.5 8674 ROP MWD030 FT/H 5.07 487.96 GR MWD030 API 21.07 111.19 RPX MWD030 OHMM 2.25 73.64 RPS MWD030 OHMM 2.2 79.74 RPM MWD030 OHMM 2,13 84.71 RPD MWD030 OHMM 2.32 86.84 FET MWD030 HR 0.2 16.54 First Reading For Entire File .......... 6368.5 Last Reading For Entire File ........... 8674 File Trailer Service name ............. STSLIB,004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record.,65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean Nsam 7521.25 4612 164.978 4474 66.9427 4474 12.5213 4474 12,6999 4474 13.4633 4474 13.5932 4474 1.15736 4474 First Reading 6368.5 6437.5 6368.5 6377 6377 6377 6377 6377 Last Reading 8674 8674 8605 8613.5 8613.5 8613.5 8613.5 8613.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name,.. Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8605.5 11901.5 RPD 8614.0 11908.5 RPM 8614.0 11908.5 RPS 8614.0 11908.5 RPX 8614.0 11908.5 FET 8614.0 11908.5 RO? 8674.5 11974.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ 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 22-OCT-00 Insite 4.05.2 65.44 Memory 11975.0 88.8 93.6 TOOL NUMBER PB01697HAGR4 PB01697HAGR4 6.125 Water Based 9.10 48.0 8.8 22000 4.8 1.400 1.095 1.400 1.300 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 i 68 16 5 63.0 82.4 63.0 63.0 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HR 4 1 68 20 24 28 Name Service Unit Min Max DEPT FT 8605.5 11974.5 ROP MWD040 FT/H 7.71 1273.69 GR MWD040 API 29.63 111.41 RPX MWD040 OHMM 0.27 1274.88 RPS MWD040 OHMM 0.33 1275.15 RPM MWD040 OHMM 0.2 2000 RPD MWD040 OHMM 0.2 2000 FET MWD040 HR 0.4 124.71 Mean 10290 170.802 70.3555 14.8137 18.0654 32.4289 34.1562 3.44628 First Reading For Entire File .......... 8605.5 Last Reading For Entire File ........... 11974.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Last Nsam Reading Reading 6739 8605.5 11974.5 6601 8674.5 11974.5 6593 8605.5 11901.5 6590 8614 11908.5 6590 8614 11908.5 6590 8614 11908.5 6590 8614 11908.5 6590 8614 11908.5 Physical' EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/14 Origin .................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
