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Home My WebLink About200-150 ECEIVED • • STATE OF ALASKA • FEB 0 2 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 0 ' Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.: 12/19/2016 200-150/316-462 ' 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 October 27,2000 50-029-22976-60-00 • 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 31,2000 MPU J-24L1 , 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 MD/TVD: 18. Property Designation: 422'FSL,2757'FEL,Sec 19,T13N,R10E,UM,AK 7,560'MD/3,628'TVD ADL 025515 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 12,114'MD/3,825'TVD N/A TPI: x- y- Zone- 12.SSSV Depth MDTrVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 541972 y- 6018037 Zone- 4 N/A 2,000'MD/-1,800'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 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) giV ' / 3SIc 0' 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED APP I I2Af 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 108' Surface 108' 30" 260 sx 7" 26# L-80 Surface 8,264' Surface 3,855' 9-7/8" 1025 sx 4-1/2" 12.6# L-80 8,284' 11,987' 3,852' 3,819' 6-1/8' Uncemented Slotted Liner 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A yam= 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No Q 12./o/vue Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —� Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only 3/21// '7 2-ZZ---f7 RBDMS L L FEB - 3 2017 III ' 28.CORE DATA Conventional Co ): Yes ❑ No 2Sidewall Cores: Yes ❑ No ❑ If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 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(a�hilcorp.com Printed Name: Codv Dinner Title: Drilling Tech ...."Signature: 4./...„.., ` --� . Phone: 777-8389 Date: 274-40/ INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and 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 H Well: MPU J-24/L1 Schematic Abandoned: 12/19/2016 Hilcorp Alaska,LLC PTD: 200-149/200-150 Orig.KB Eley=66.5'GL Elev.36.3' CASING DETAIL RKB—Tbg Hngr:21.3'(Nabors 35) Size Type Wt/Grade/Conn Drift ID Top Btm id ii- '1)�+ kl 20" Conductor 92/H-40/Welded N/A Surf 108' 7" Surface 26/L-80/BTC 6.151" Surf 8,664' 20" !., 4-1/2" Liner Ll 12.6/L-80/IBT 3.833" 8,284' 11,987' izr el 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' ES CementerTUBING DETAIL i 2,397' 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" 7,891 8,208' k 44 As4 e ""41 JEWELRY DETAIL 4 No Depth Item 4,17 1 7,577' Cement Retainer(Squeeze 46 bbl(193 sx)of 15.8 ppg Cement below) T2 7,891' Cut 4-1/2"Tubing 44 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) !, 0 4 8,073' Baker S-3 Packer 9Cr ?l 5 8,136' HES X Nipple—3.813"ID +1" 6 8,196' HES XN Nipple—3.725"ID !X 7 8,207' WLEG 8 8,296' Baker ML Torque Master Packer 0; 9 8,315' WLEG + 10 8,563' Baker HMC Liner Hanger Window for J- 11 11,964' OA Lateral 4-1/2"Pack-off Bushing 24A@7'560 12 11,987' OA Lateral 4-1/2"Btm of Guide Shoe k- ND s 13 11,952' OB Lateral 4-1/2"Pack-off Bushing R 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe '`}f4 OPEN HOLE/CEMENT DETAIL {' 2 20" 260 sx Arctic Set cmt to surface "o 7" 1600 sx Cement,2 stages,cmt to Surface *,gra_ *ty GENERAL WELL INFO API:50-029-22976-00/(60)00 ;� _ " Drilled and Cased by Doyon 141-11/9/2000 02'4 '1 4 ESP Installed by Nabors 4ES—11/21/2000 ESP Replaced by Nabors 4ES—5/20/2005 x. t �� ESP Replaced by Nabors 4E5-9/01/2005 'r,'^ + ESP Replaced by Nabors 4ES—9/10/2006 Mn ID:3.725" .3 I ESP Replaced by Nabors 3S—7/02/2007 f+ i Convert to Jet Pump by Nabors 3S—4/15/2008 It 4'• Decomplete/Abandon by Innovation Rig— RATag: v. 11 12/19/16 8,254' t�,. k . r,%,„:, I. �i X 12 .1 "1 8 ti ', 19 ti,, 10 \ - 13 4. 14 7, TD=11,975'(MD)/TD=3,858'(TVD) PBTD=11,975'(MD)/PBTD=3,858'(TVD) Downhole Proposed Updated By:CJD 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 11130k,s/o U110k,massage derrick work f/120k-U145k multiple times,p/u U150k and hold,cont.Umassage;Set over pull 11140k and work,stage up over pull 11142k 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 c/o 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 Upits. R/U steam Upit#5 and 11140 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. Retested 250 5000 psi good.;Tested Both manual and Hyd TD valves to 250/5000 psi. Performed accumulator test. 3050 psi Starting pressure 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&#2 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 Iines.;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/O 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:L/D 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. 12/17/2016 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 cement retainer,retainer only=2.65',OA=14.16' Note:use 10 bph hole filI;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 f/3156'to 6994'(111 stds DP)Single in with 19 jts DP to 7585',P/U 94K,S/O 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 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 tJ 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 DrIg 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,X0,20 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 J f/7488'to 7549'. ✓ Pump on P/U 104K,S/0 60K,pumps off P/U 117K,S/O 60K.;M/U stand 110 and top drive, work out torque,check tool face,holding 51 Left.S/O tagging yd 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 N. 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 0, 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 to well,0 bbls drlg mud for total=0 bbls Hauled 0 bbls to B-50 for total=580 bbls Hauled 0 bbls to ORT for total=190 bbls.;Hauled 150 bbls from 6 mile lake for total=1090 bbls • • yorTq „4\" i y/,..s. THE STATE Alaska Oil and Gas ice fLASI�:A Conservation Commission o A - f{ 333 West Seventh Avenue 2 �- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 S1iFax: 907.276.7542 www.aogcc.alaska.gov Bo York SWIMMAY 0 3 20 It. Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU J-24L1 Permit to Drill Number: 200-150 Sundry Number: 316-462 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, r2912-4-.4 Cathy P. Foerster Chair DATED this 6day of October, 2016. RBDMS L& Uu 11 0 2016 • 0 RECEIVED STATE OF ALASKA S p P 0 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION a7-1 /8 lc /1,,66 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well n Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing t 7 Change Approved Program❑ Plug for Redrill 2. Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ - 200-150 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 50-029-22976-60-00 7.If perforating: 8.Wel Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0J MPU J-2411 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025515/025517/025906 ' Milne Point Unit/Schrader Bluff Oil 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): 12,114' • 3,825' • 12,114 v 3,825 . 1,173 WA N/A Casing Length Size MD ND Burst • Collapse Structural Conductor 108' 20" 108' 108' 1530 psi 520 psi Surface 8,264' 7" 8,264' 3,855' 7240 psi 5410 psi Intermediate Production Liner 3,703' 4-1/2" 11,987' 3,819' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): 8,374'-11,964' . 3,873'-3,819' 4-1/2"/12.6# 1-80 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'TVD(Torque Master) 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 2 Exploratory ❑ Stratigraphic ❑ Development 2• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/15/2016 OIL ❑ WINJ 0 WOSPL ❑ Suspended 0 ' 16.Verbal Approval: Date: GAS p WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: 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 Pothole /, Email sDorhola( hilcorp.com Printed Name 1. yi,f� Title dt'. ri r Signature -'---------'r-77/2Phone % / -- t/334 J'-- Date Cl �iA- `1 b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry lumber. L 3kL2 - 9622 Plug Integrity ❑ BOP Test i Mechanical Integrity Test 0 Location Clearance ❑ Other: 4( 3cvo P sL e C)P `T (-- [ Z--5--bb P S A r'i r.wit-A_ .7 T -- Post Initial Injection MIT Req'd? Yes ❑ No ❑ 41107 /1 T Spacing Exception Required? Yes ❑ No l.ld" Subsequent Form Required: I�C3— ( --7 " RBDMS Lv 00,0 1 0 2016 APPROVED BY Approved by:Cd��7,P ✓✓✓��' 4,��,V—........, COMMISSIONER THE COMMISSION Date: /61-6,—/ ,, Submit Form and Form 10-4031Revs iii20'y5 c nARo�e Ili�7t�D lid 2 f FyS from the date Of approve !� Attachments in Duplicate 4110 Well Prognosis Well: MPU J-24 llikurp Alaska,LL 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: 44414evattarrItigtrrigt ��,�✓ Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: @c t,'c,llr° iLl C 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. The tubing was cut using coil tubing in August 2016. CohGu r. �/J j 144 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. • 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 ppg 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 BOPS. 3c( (, z,9 v� y` `I•L`I " 4. Test BOPE to 250 psi Low/'5;999-psi High, annular to 250 psi Low/377560-psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. The initial test of all • Well Prognosis Well: MPU J-24 Ilileorp Alaska,LL Date:9/6/2016 rams, hoke ma . • : kill line valves, standpipe equipment,floor& top drive valves wi •e to 250/5000 psi(An lar t 50/3501 •si)per API 'P 317.3.2.2 prior the equipme t being pinto ••erational service. b quent tests o e BO' equi.• ent will a to 2 /3000fi fo /5 min (annular to 50% rated WP, 00 psi on the high : for initia •nd ubsequent ests 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 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 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. 13. MU cement retainer. RIH on 4" drillpipe.Set retainer at+/-7,585' MD. 14. Unsting from retainer. Set down 10k to confirm set. '---- 15. RU cementers. Mix and pump 40 bbl of 15.8 ppg cement below retainer. 16. Unsting from retainer. Circ btms up. 17. Close pipe rams and test 7"casing to 1,500 psi for 30 min and chart. ! • Well Prognosis Well: MPU J-24 Hulcorp Alaska,LL Date: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 • • Milne Well: Point MPU J-24 Unit SCHEMATIC Completed: 4/15/2008 Hilcorp Alaska,LLC PTD: 200-149 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Hey=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' 4-1/2" Liner Ll 12.6/L-80/IBT 3.833" 8,284' 11,987' { y 1L 4 4-1/2" Liner 12.6/L-80/IBT 3.833" 8,554' 11,975' i TUBING DETAIL '4; 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' ' Esc ter JEWELRY DETAIL $" 2,39T 4 44 '47 No Depth Item 7 2 1 21.3' Tubing Hanger :f, 2 2,838' ST:1 KBG-2 GLM(DGLV 4/24/08) o k+ � 3 8,010' HES XD Sliding Sleeve(Closed 7/18/08) V I�'. 4 8,073' Baker 5-3 Packer 9Cr 5 8,136' HES X Nipple—3.813"ID y 6 8,196' HES XN Nipple—3.725"ID arit 7 8,207' WLEG A° 8 8,296' Baker ML Torque Master Packer . 9 8,315' WLEG 4 8 ' ,'‘ 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 10 ►a 13 11,952' OB Lateral 4-1/2"Pack-off Bushing i-i 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe .`,1,, OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set cmt to surface 7" 1600 sx Cement,2 stages,cmt to Surface a ,41 t41GENERAL WELL INFO `: API:50-029-22976-00/(60)-00 F e Drilled and Cased by Doyon 141-11/9/2000 Jet Cut Tbg: ¢ ESP Installed by Nabors 4ES—11/21/2000 7,900 CTM r( ESP Replaced by Nabors 4ES-5/20/2005 , - ESP Replaced by Nabors 4ES—9/01/2005 absorber+jet Fish:Cel shock/ ESP Replaced by Nabors 4ES—9/10/2006 a anter head I s 1 3 ', ESP Replaced by Nabors 3S—7/02/2007 (Lost during ad) az t" Convert to Jet Pump by Nabors 3S—4/15/2008 4 # 1 r it � 9 ;11 ri Mn ID:3.725'_. _+fes" 6 +% 4 41 8,254' *! 11 4 Fill Cleanout 12 8,280 CTM eb :r ' 8 10 t. ?r' \ _; 13 ii a 4 11 A 14 TD=11,975'(MD)/TD=3,858'(TVD) PBTD=11,975'(MD)/PBTD=3,858'(TVD) Downhole Revised:8/05/2016 Updated By:CJD 9/01/2016 • • Mime PointMPUe Pop• fi We PROPOSED Completed: 4/15/2008 I lilcorp Alaska,LLC PTD: 200-149 Orig.KB Elev=66.5'GL Elev.36.3' CASING DETAIL RKB—Tbg Hngr:21.3'(Nabors 35) Size Type Wt/Grade/Conn Drift ID Top Btm L j 20" Conductor 92/H-40/Welded N/A Surf 108' 7" Surface 26/L-80/BTC 6.151" Surf 8,664' 20' 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' TUBING DETAIL 0 ES Cementer 239 7 4-1/2" Tubing 12.6/L-80/IBT-M 3.833" Surf 8,208' JEWELRY DETAIL No Depth Item 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) 4 8,073' Baker 5-3 Packer 9Cr 5 8,136' HES X Nipple—3.813"ID 6 8,196' HESXN 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 • 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 14 11,975' OB Lateral 4-1/2"Btm of Guide Shoe r1 OPEN HOLE/CEMENT DETAIL 2 20" 260 sx Arctic Set cmt to surface 7" 1600 sx Cement,2 stages,cmt to Surface 0l 3. GENERAL WELL INFO API:50-029-22976-00/(60)-00 Drilled and Cased by Doyon 141-11/9/2000 z z 4 ESP Installed by Nabors 4E5 11/21/2000 ESP Replaced by Nabors 4ES—5/20/2005 5 ESP Replaced by Nabors 4ES—9/01/2005 ESP Replaced by Nabors 4ES—9/10/2006 Mr 6 ESP Replaced by Nabors 3S—7/02/2007 Convert to Jet Pump by Nabors 3S—4/15/2008 7 ' RA Tai: i*) . '• 11 8,254' 12 ., 4M 26 6�� ►_�I►_ 8 £ riS 10 filg;W:•.43:151515:51514:4 14 r A ► TD=11,975'(MD)/TD=3,858'(TVD) PBTD=11,975'(MD)/PBTD=3,858'(TVD) Downhole Proposed Updated By:CJD 9/01/2016 • • 18.0 BOP Schema tic o II II 'IItati III 1IIFI 5M Control T. ology Annular BOP L n. I 1 11 13.58'5M Control Technology Double Ram01 i oc ® Ii 1� I��i1 �a•, 3.118"Kill Line — ,•�'�': Ili 3.1'8"Choke Line ,o ;;, o x--13 518"5M Control Technology Single Ram 13.518"5M X 11"5M DSA 2.1116'FMC HWO Valve 11"x 11'5M FMC Gen 5 Tubing Spool Qu uu# ---FMC Starting Head ---2-1116"FMC HWO Valve mow►, J ----20"Conductor .-- 7"Casing • • 19.0 Wellhead Schematic MPJ-24 0.4 N ...Mt.., —,---.—..- Immo 1111211T lit .P1Mill *T.7. ;4l \7-4 1;111.40' let•LSI 11111 I ii.i(): -! 4 1/16 CIW Tree ; . i All:L 1 i --) MIN Slit 'sum L • \'. 4,0'04 illi itille Ill i Emenmili NN . lifidlifiN --ii imisms. ir x irSMFMCGenS — ... tubing spool 111 ( , 1 9 I all :de 11•• 2 U16 FM<HWO valve 11 . veiekil 1 F MC I111 ti 1 1 C'Tel g..) il • 21/16 tINC HWO VA* ill • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box 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 Geologist work)the initial reviewer will cross out that erroneous entry and initial J 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. ge 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 RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) [] ~ items: ,~,,,,~ Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Diskettes. No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~INDY [] Maps: · [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scanning Preparation _~_ x 30 = BY: BEVERLY ROBIN VINCENT SHERY~~)NINDY 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) DISCREPAN~'~FOUND: YES ,, NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA ~NDY ~,~ DATE:~ ~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDI~I~,IAL-.'"F'AGE BASIS v RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked ' III IIIllllllllllill 12/10/02Rev3NOTScanned,wpd STATE OF ALASKA .s-.qd8 A~ OIL AND GAS CONSERVATION COM ION ......,v1,....i YC~ MAY ~ 9 2008 REPORT OF SUNDRY WELL OPERATIONSIaska Oi! & Gas Cons. Commissiara AIIChnrann 1. Operations Performed: ^ Abandon ®Repair Well . ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Replace ESP, Desander 8 Screens ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-150 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22976-60-00 r 7. KB Elevation (ft): 66.05 - 9. Well Name and Number: _ MPJ-24L1 8. Property Designation: 10. Field /Pool(s): ADL 025515 ' Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 12114 - feet true vertical 3825 ~ feet Piugs (measured) N/A Effective depth: measured 12114 feet Junk (measured) N/A true vertical 3825 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8235' 7" 8264' 3855' 7240 5410 Liner 3703' 4-1/2" 8284' - 11987' 3860' - 3819' 8430 7500 ~~ Mai ~ ~ 2000 Perforation Depth MD (ft): Slotted Liner 8374' - 11964' Perforation Depth TVD (ft): Slotted Liner 3873' - 3819' 4-1/2", 12.6# L-80 8208' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-112" 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 Numt~er or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist S Prepared By Name/Number: ' ~ ~' ~ nature Phone 564-4750 Date 1 Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ ~ ~ A ~ ~y~w ~~ ~~~~ ~ I~~ Submit Original Only Tree: 4-1/16" SM FMC Tree ~ Wellhead: 11" x 11" 5M tbg. spool, 11 " x 4-1 /16" 4 1 /2" TC-I I (top & twttom) 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° Co? ' 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' Milled window from 8264'-8276' Baker HR setting sleeve 8284' 4 1/2" HES XD Durasleeve 8010' 3.81" polish bores 4 1/2" x 7" Baker S-3 Packer 8073' 3.875" ID 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 8296' I 2jts. of solid liner (82') 8291'-8373' Wireline entry 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' Halliburton landing collar 8577 I \ ~ ® ® ®~ Halliburton float collar 8620' ~ I 4.5" 12.6#, L-80 IBT tubing. Halliburton float shoe 8664' Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (8656'-11953') 4-il2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- 8,656' - 11,953' MD (3296') Mid-lateral TVD @ 3877' 5/20/05 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 M P J ~24~ ~ I - KB elev. = 28.55' DF elev. = 66.05' GL elev. = 36.30' i SLB 4 1/2" x 1" KBG-2 SPM 2838' MILNE POINT UNIT WELL J-24 API NO: 50-029-22976-00 °oc~ 5`0 -v29 ~ Zzq~L, ~c~t BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 4/9/2008 06:00 - 10:00 10:00 - 17:00 17:00 - 19:30 19:30 - 22:00 22:00 - 23:30 23:30 - 00:00 4/10/2008 00:00 - 02:00 02:00 - 03:30 03:30 - 04:30 04:30 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 16:30 16:30 - 17:00 17:00 - 20:00 20:00 - 22:00 22:00 - 23:30 23:30 - 00:00 4/11/2008 00:00 - 00:30 00:30 - 01:00 BP EXPLORATION Operations Summary Report MPJ-224 MPJ-224 WORKOVER NABOBS ALASKA DRILLING I NABOBS 3S Hours Task Code I NPT 4.00 I MOB I P 7.00 I MOB I P 2.50 MOB P 2.50 MOB P 1.50 MOB P 0.50 MOB P 2.00 MOB P 1.501 MOB I P 1.00 MOB P 3.50 MOB P 2.00 RIGU P 2.00 WHSUR P 1.00 WHSUR P 3.50 KILL N 0.50 KILL P 3.00 KILL P 2.001 KILL I N 1.50 KILL P 0.50 KILL P 0.50 KILL P 0.50 KILL P Start: 4/9/2008 Rig Release: 4/16/2008 Rig Number: Page 1 of 5 Spud Date: 10/9/2000 End: 4/16/2008 Phase Description of Operations PRE R/D floor, lower mast, move pipeshed, pits and move carrier off of P-21. 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. PRE Wait on Milne Point crew bus change out. PRE Move from Texaco Pad to Milne Point J-pad. PRE Move equipment on pad and spot camp, shop, generator and parts house. PRE Spot BOP cradle behind well MPJ-24 PRE Line up BOP cradle, Line up c'a er and lay herculite. Back carrier up toward well. Lost power in carrier. PRE Broken drive line on carrier. Remove broken shaft and spot over well using forklift. PRE Jack and level carrier, Spot pipeshed. 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. PRE PJSM. Raise and scope the Derrick. MU Flow Line and pin the wind wall. DECOMP The Rig was accepted at 10:00 hrs on 4/10/2008. 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. DECOMP PU and RU Lubricator with Well Support Techs. Pressure test the Lubricator to 500 psi with diesel. Pull the BPV. Pressure on the Tubing = 60 psi and pressure on the IA = 50 psi. 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. DECOMP Pressure test all surface lines to 2,500 psi. 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 Tiger Tank with no returns. Line up to Bullhead down IA 4bpm at 380 psi, with 80 bbls away lost rod oilers on Mud Pump. 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. DECOMP Continue with Bullhead kill down IA at 4bpm with 480 psi. Pump 172 bbls and lost rig power. DECOMP Work on fuel system on rig. C/O primer pump on generator. Bled fuel injector and get generator restarted. DECOMP Continue Bullhead down the IA 4bpm with 480 psi. A total of 355 bbls was pumped down IA. 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 W ell Name: MPJ-224 Spud Date: 10/9/2000 Event Nam e: WORKO VER Start : 4/9/2008 End: 4/16/2008 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 4/16/2008 Rig Name: NABOR S 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-Bar and install 3" type H TWC with FMC wellhead tech. Test from above to 3,500 psi 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 ROPE 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 bbls 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 Valves 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 L/D 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 type 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, L/D 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 existing ESP Assembly. 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 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 3S Date From - To '~ Hours I Task Code NPT 4/12/2008 16:00 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 00:00 4/13/2008 00:00 - 01:00 01:00 - 06:00 06:00 - 07:00 07:00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 20:00 20:00 - 22:00 22:00 - 00:00 4/14/2008 00:00 - 01:00 01:00 - 04:30 04:30 - 06:00 1.00 PULL P 1.00 CLEAN P 0.50 CLEAN P 5.50 CLEAN P 1.00 CLEAN P 5.00 CLEAN P 1.00 CLEAN P 5.00 EVAL P 0.50 EVAL P 0.50 EVAL P 1.00 EVAL P 1.00 EVAL P 0.50 EVAL P 1.50 EVAL P 3.00 BOPSU P 2.00 WHSUR P 2.00 WHSUR P 1.00 WHSUR P 3.50 BOPSU P 1.50 BOPSU P Page 3 of 5 Spud Date: 10/9/2000 Start: 4/9/2008 End: 4/16/2008 I Rig Release: 4/16/2008 Rig Number: Phase Description of Operations DECOMP LaSalle Clamps. DECOMP PUMU 7" Scraper Assembly. PU (3) 2-7/8" EUE 8rd Tubing Joints that were laid down in the Pipe Shed. DECOMP Service crown sheaves, wireline anchor, blocks and drawworks. Inspect brake bands and rollers. DECOMP RIH with 7" Scraper Assembly on 2-7/8" EUE 8rd Tubing from derrick to 7,910'. Maintain 30 bph continuous hole fill. 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. 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. DECOMP Pre-tour checks. Break out and lay down Scraper Assembly. RD ESP Single Sheave and Elephant Trunk Containment. 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. 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 rep. Slack off 15K and overpull 5K to confirm set. Stand back 1 stand (2 Jts) in the Derrick. DECOMP MU TIW and Headpin. Fill the well with 34 bbls of seawater. Close the Annular. DECOMP Pressure test the 7" Casing against the RBP to 3,500 psi for 30 charted mins -good test. The first 15 mins lost 100 psi and the second 15 mins lost 50 psi with signs of stabilization. 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. DECOMP Set the 7" RTTS with Sub.Surface Control Valve at 39' in with Halliburton rep. DECOMP Test the 7" RTTS with Sub Surface Control Valve against the Blind Rams to 3,500 psi for 10 charted mins -good test. Bleed down all lines. 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. DECOMP N/D Casing/Tubing Head. Wipe head down and remove from cellar. Had no problems removing head. DECOMP N/U new FMC 11" 5k Casing Head, Isolation Sleeve and new FMC 11" x 11" 5k Tubing Spool. Locking pins on Casing Head were torqued to 350 fUlbs as per FMC procedure. 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. 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. 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 Operations Summary Report Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Event Name: WORKOVER Start: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/16/2008 Rig Name: NABOBS 3S Rig Number: Page 4 of 5 Spud Date: 10/9/2000 End: 4/16/2008 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 rep. 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 taking returns up 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 L/D 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, 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. 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 leak on stand pipe. Bleed off, tighten connection and re-pressure tubing to 3500 psi w/ 96 strokes. Lost 90 psi 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, pumping SW. Chart for 30 minutes. Tbg pressure to 2000 psi. Bleed Tbg to 1550 psi and shear DCK valve. Establish circulation both ways ~ 2 BPM, 110 psi. 16:00 - 18:00 2.00 WHSUR P RUNCMP Dry rod TWC (CIW 4" Type 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 UD 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: MP)-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 WH P's= MPJ-24 1/18/2008 (Ice Plug in FL) T/I/0= 500/0 Pump 2 bbls Heel 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 @ 8010' MD/8021 SLM PULL BAR & ROD C~ 8197 SLM MADE ATTEMPT TO PULL SHEAR VALVE C 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 @ 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/O=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 ALASKA ~ RECEIVED ALA~ OIL AND GAS CONSERVATION COM.ION h:, G 0 1 Z007 REPORT OF SUNDRY WELL OPERATIONS.", I'~O' ,,\1881\<:1 ¡I & Gas Cans. Cammission . 1. Operations Performed: <111 ¡'!I U¥ ('tit: o Abandon l8I Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing l8I Pull Tubing o Perforate New Pool o Waiver l8I 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. ~ Development o Exploratory 200-150 ,- 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22976-60-00 / 7. KB Elevation (ft): 66.05 ' 9. Well Name and Number: MPJ·24L 1 / 8. Property Designation: 10. Field 1 Pool(s): ADL 025515 Milne Point Unit 1 Schrader Bluff ./ 11. Present well condition summary Total depth: measured 12114 ' feet true vertical 3825 , feet Plugs (measured) N/A Effective depth: measured 12114 feet Junk (measured) N/A true vertical 3825 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8235' 7" 8264' 3855' 7240 5410 Liner 3703' 4-1/2" 8284' - 11987' 3860' - 3819' 8430 7500 S[;,HJ'lNED AUG 0 8 2007 Perforation Depth MD (ft): Slotted Liner 8374' - 11964' Perforation Depth TVD (ft): Slotted Liner 3873' - 3819' 2-7/8",6.5# with 4", 9.5# Excluder L-80 8164' Tubing Size (size, grade, and measured depth): 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 tinal pressure: 13. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casino 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: l8I Daily Report of Well Operations o Exploratory l8I Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram l8I 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 NIA if C.O. Exempt: Contact Frank Roach, 564-4373 N/A Printed Name Sondra Stewman Title Technical Assistant S(9riatur~~ Prepared By Name/Number: . '«^'~~~." "..",¡.,~ Phone 564-4750 Date Dl-l70l Sondra Stewman, 564-4750 Form 1 O~evísed 04/2006 .", Submit Ori inal Onl ORIGINAL I j RBDMS 8Fl Ave 0 81DD7 /~...¢7 9 y Tree: 3-1/8" FMC horizontal tree 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. ~ Halliburton ES cementer I 2,397' I "\ MP J-24\L FMC Horizontal tree Model 120 KB elev. = 28.55' OF elev. = 66.05' GL elev. = 36.30' Cameo 2-718" x 1" KBMM SPM 145' 27/8" 6.5 ppf, L-80 8rd eue tbg. Cameo 2- 7/8" x 1 KBMM SPM I 7830' I (drift id = 2.347" cap. .00592bpf) I 7973' I HES 2-7/8" XN nipple 2.25" 10 7" 26 ppf, L-80, BTC production casing I I ( drift 10 = 6.151 ", cap. = 0.0383 bpf ) Discharge Head GPDIS 8016' (capacity wi tubing inside = 0.0275B bpf) Pump 137 Stage/538P17 I 8016' I PM8XD 1:7 KOP @ 600 . Gas Separator GRSFTX AR H6 I 8035' I Max wellbore Angle: 750 @ , MD Tandem Seal Section I I Hole angle through peris = 90 deg. GSB3DA FER HL SSCV HA SB/SB PFSA 8040' Motor 152 hp KMH 2325 volt, 40 amp I 8054' I PumpMate XTO wi fin centralizer I 8067' I PumpMate TVD: 3796' I I Shear sub & Cavins Desander 8071' Baker Excluder Screens wi I 8079' I RA tag at B254' 3 Short joints B 119' -B242' centralizers and end bull plug Milled window from B264'-8276' Baker HR setting sleeve I 8284' Baker 7" ML torque master pkr 600-47 Wireline entry guide 8296' 8315' Baker HR setting sleeve Baker HMC liner hanger 8553' 8563' Halliburton landing collar Halliburton float collar Halliburton float shoe B577' B620' B664' 4-1/2" SLOTTED INTERVALS OB- 8,373' - 11,964' MD (3590') OA- B.656' - 11,953' MD (3296') DATE 11/09/00 1/.,1/00 REV. BY MDO 1\1, Linder COMMENTS Initial casing completion Doyon 141 Initi<:11 ESP 'orr IBtion 4-ES 5/20/05 L. Hulme MOO REH ESP replacement by 4ES ESP Replacement by 4ES ESP Replacemenl by 4ES ESP wi desander & screens replacement by 3S MILNE POINT UNIT WELL J-24 API NO: 50-029-22976-00 -00 60'Gó1'i 'dáAÎI¿f~ BP EXPLORATION (AK) 9/01/05 9/10/06 7/2/07 L. Hulme 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of Slotted liner (3296') (B656'-11953') Mid-lateral TVD @ 3877' . BP Operations . Page 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-~24 ~ J11Þ:J -04 LI MPJ-\?24 WORKOVER NABORS ALASKA DRILLING I NABORS 3S 6/21/2007 6/2212007 6/2312007 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-23i. 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. R/U 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 psi. PJSM DECOMP Pump 50 Bls @ 3.5 BPM down tubing, fluid returns to Tiger tank. Close choke, bullhead 75 Bbls @ 3.5 BPM, 440 psi. SITP of 0 psi. 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). WellheadlTree successfully flushed and cleaned. DECOMP Re-rig circulation lines on tree. NU tree cap on top of tree. Test hardline to 2500 psi. DECOMP 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 psi. 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 psi. 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. DECOMP 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 psi. Tubing and IA on vacuum. Total fluid lost to formation - 491 Bbls. DECOMP 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 From - To Hours Task Code NPT 00:00 - 01 :30 DEMOB ¡ P DECOMP I 101 :30 - 02:30 1.00 DEMOBlp DECOMP 02:30 - 03:30 1.00 DEMOB f P DECOMP 03:30 - 05:30 I 2.00 DEMOB I P DECOMP 05:30 - 06:00 0.50 BOPSU1 P POST 06:00 - 00:00 18.00 DEMOB P POST I 00:00-17:00 I 17.00 MOB P PRE 17:00 - 22:00 5.00 MOB P PRE 22:00 - 00:00 2.00 RIGU P PRE 00'00 - 01'30 I 1.50 RIGU PRE . . i 01 :30 - 03:00 I 1.50 RIGU PRE 03:00 - 06:00 3.00 RIGU PRE 06:00 - 09:00 3.00 R/GU PRE 09:00 - 12:00 3.00 KILL DECOMP 112:00 - 13:30 1.50 KILL 13:30 - 15:00 1.50 KILL 15:00 - 15:30 0.50 KILL 115:30 - 17:30 ""'" - 22030 I 2.00 KILL 5.00 WHSUR I Start: Rig Release: Rig Number: Spud Date: 10/9/2000 End: 7/2/2007 6/20/2007 7/2/2007 Description of Operations Printed: 7124/2007 5:05:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/23/2007 6/24/2007 6/25/2007 . . BP EXPLORATION Operations Summary Report MPJ~24\L\ MPJ-~'24 \L\ WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: Code I NPT Phase ¡ 1 ¡ i DECOMP 17:30 - 22:30 From - To Hours 5.00 WHSUR 122:30 - 23:15 23:15 - 00:00 . 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 104:00 - 04:30 I 04:30 - 08:30 ' 08:30 - 11 :30 11:30-12:301 I 12:30 - 14:00 I 14:00 - 14:30 14:30 - 15:30 15:30 - 17:30 17:30 - 00:00 00:00 - 02:00 Task 0.751 WHSUR 0.75 WHSUR 1.50 WHSUR P 1.50 DHB Ic 1.00 DHB C 0.50 WHSUR C 4.00 WHSUR C 3.00 WHSUR C 1.00 WHSUR C 1.50 WHSUR C 0.50 WHSUR C 1.00 WHSUR C 2.00 WHSUR C I 6.50 WHSUR C 2.00 WHSUR P I I I Page 2 of 7 6/20/2007 7/2/2007 Spud Date: 10/9/2000 End: 7/2/2007 Description of Operations 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 C/O TWC. ! DECOMP R/U DSM lubricator and pull TWC. Set redressed TWC. RID I DSM. ! DECOMP I 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. 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. Confer with town engineer. Decision made to set 2-7/8" WRP with e-line in TBG at 150'. Make arrangements to change i scope. Contact SLB a-line and Weatherford. ; DECOMP Contact DSM. R/U DSM lubricator and pull TWC. RID DSM. i DECOMP R/U DSM and shoot fluid levels in TBG at 2035' and in the I annulus at 385'. Continue gravity feeding 20 BPH in annulus. ! I Plan on shooting fluid levels hourly. I 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' I DECOMP SlB on location. Call Weatherford for a 2 7/8" WRP. PJSM. ! RU SLB e-line. SLB getting variance for running explosive I setting tool @ depth less than 200' (SlB policy). Fluid level @ i 10:30 in IA -412'. I DECOMP BOPE on wellhead, lubricator and grease head rigged up on rig ! floor. Wait on SlB., I DECOMP Model 505 E charge setting tool on location. PJSM. MU WFD I plug to setting tool. MU to wellhead, pressure test lubricator to I 500 I 3000 psi. Open well to 0 psi. AIH wi WFD 2 7/8" WRP I on SLB e-line wI Baker setting tool. log up from 200'. Tie into 1 GlM @ 176' ELM. Set WAP @ 145' (middle of 1st full joint I above GLM). POOH. . DECOMP Break lubricator off of tree. Confirm setting of WAP. Close I' master valve and test Tubing and WRP to 500 13500 psi for 5 I minutes each, and chart. Bleed and drain tree. I DECOMP RD SlB e-line lubricator and grease head from Rig floor. I Break off wireline BOPE from tree and remove from cellar. I Continue to put 20 Bbl SW in Annulus every 1 hour. 'I: DECOMP ND tree. Pull sleeve from top of hanger. Screw 3 1/2" RH Acme XO into top of hanger wI 9-1/2 turns. Inspect TWC I 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. I DECOMP Shoot fluid level on fA. Fluid @ 400'. NU 13-5/8" x 11" double flange spool piece to tubing head. NU BOPE, C/O unibolt on t BOPE, NU kill line and choke line, function test, install riser and i flow line, center BOP stack. Shoot fluid level at 24:00 @ 440'. I DECOMP R/U BOPE testing equipment and purge air. Pressure up on I BOPE body and check for leaks. Valves connecting to TBG head leaking slightly. Call for grease crew to service wellhead I valves. Service valves. I ·1 i DECOMP I I i DECOMP I 1 ¡ Printed: 7/24/2007 5:05:12 PM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ~24\LI MPJ-~'24\LI WORKOVER NABORS ALASKA DRILLING I NABORS 3S Date From - To Hours Task Code NPT 6/25/2007 02:00 - 06:00 4.00 WHSUR P 06:00 - 09:00 3.00 WHSUR N 09:00 - 16:00 7.00 WHSUR N I I 16:00 - 17:00 1.00 WHSUR N I 17:00 - 21:45 ! 4.75 WHSUR N 21 :45 - 22:30 0.75 WHSUR P I 122:30 - 00:00 1.50 WHSUR P I 6/26/2007 100:00 - 01:30 ' 1.50 WHSUR P 01 :30 - 03:30 I 2.00 WHSUR P 03:30 - 04:30 1.00 DHB P 104:30 - 05:30 1.00 DHB P 105:30 - 06:00 0.50 DHB P 06:00 - 09:00 I 3.00 DHB P I 09:00 - 09:30 0.50 WHSUR P 09:30 - 11 :00 1.50 I PULL P 11 :00 - 12:30 1.50 PULL P 12:30 - 14:00 1.50 PULL P 14:00 - 23:00 9.00 PULL P ! 23:00 - 00:00 1.00 PULL P 6/2712007 00:00 - 02:00 2.00 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 03:30 0.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P Page 3 of 7 . Spud Date: 10/9/2000 End: 7/2/2007 Start: 6/20/2007 Rig Release: 7/2/2007 Rig Number: Phase l Pe$Criþtion otQp.er~tioh~ DECaMP ¡Test BOPE to 250 psi low pressure and 3,500 psi high ¡ pressure. Each test was held for 5 minutes. AOGCC witness I lof test was waived by Bob Noble. Test was witnessed by I I Nabors tool pusher and BPX WSL. I I Shoot fIIuid levels at 03:00 - 330', 06:00 - 280'. DECaMP I Continue testing BOPE. Troubleshooting annular preventer. DECaMP I Break down annular preventer. Inspect and replace seals. i Shoot FL in IA @ 11 :30 - 400'. 1 DECaMP I MU test joint and position in annular preventer. Attempt to I I pressure test. Leaking by element. I DECaMP I Break off Hydril cap. Remove and replace hydril element. I Called AOGCC and informed them of changes made to kill i linelmud manifold. Also discussed current BOPE testing I problems (Hydril annular preventer). shoot Fluid level @ 17:30 1- 400'. i DECaMP I Continue testing BOPE. Test Annular and TIW to 250 psi low pressure and 3,500 psi high pressure. Perform Accumlator ! draw down test. RD BOP testing equipment. DECaMP ! Drain BOPE, BID lines. RD bell nipple and flow line. DECaMP ! PU and install shooting flange on hydril. DECaMP I PU SWS lubricator extension, BOPE, lubricator and packoff. i RU same. DECaMP I PJSM. MU WRP retrieving tool and enter TBG. Fill lubricator wI seawater and pressure test SWS lubricator to 500 psi low I i 3000 psi high. DECaMP: RIH to 149' WLM. Latch to WRP and jar attempt to shear I I loose. POOH wlo WRP. DECaMP Examine retreiving tool. MIU and RIH to retrieve WRP. DECaMP ¡1st run unable to latch WRP. Re-dress pulling tool RIH. 2nd run unsuccessful as well. Dogs on pulling tool bent in which I prevented being able to latch 1-1/8" fishing neck. RIH wI 2.25" i LIB and get impression of fishing neck -looked good. RIH wI WFD pulling tool. Hand spang and equalize plug, latch and POOH DECaMP 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. DECaMP RD SLB wireline equipment. ND shooting flange, NU pitcher nipple and flow line. RU floor to pull completion. DECaMP Hang ESP sheave in derrick. Continue to filllA wI seawater @ 20 bph. DECaMP Pull tubing hanger to floor. LD hanger and landing joint. DECaMP 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. DECOMP Cut cable and check conductivity to motor (no good). LD pump sections & motor. Continue to fill hole wI seawater @ 20 bph. LD Centrilift ESP assembly. Clear rig floor. PU test joint and set wear ring wI 9" 10. RILDS (4). LD cable spooler elephant trunk. DECOMP DECaMP DECOMP DECOMP Printed: 7/24/2007 5:05:12 PM . . BP EXPLORATION Operations Summary Report of 7 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 Date From - To Hours Tåsk Code NPT Phase Description of OperatiÒh~ 6/27/2007 04:00 - 07:00 3.00 CLEAN P DECOMP MU BHA #1: 2-7/8" muleshoe, 7" casing scraper, 2 boot I baskets, oil jars and 4 DCs on 2-7/8" tubing. 07:00 - 11 :30 4.50 CLEAN P DECOMP TIH with SHA #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 I TIH to tag fill. Pipe arrives on location at 12:30 hrs. Load and 1.50 I CLEAN strap in the Pipe Shed. 13:00 - 14:30 P DECOMP Establish parameters: UW = 45K , OW = 25K. Continue TIH I with single Joints of 2 7/8" Tubing from the Pipe Shed. Tag 18' I 1 in on Jt #258. Re-confirm tag depth 5 times to ensure, tag I depth = 8,279' 3SMD. Did not encounter any obstructions to TO. 14:30 - 20:00 5.50 CLEAN IP i DECOMP TOH with BHA #1 standing back 27/8" Tubing in the Derrick (129 stands). Double displace with seawater while TOH. Soot 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 SHA #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 I EVAL P DECOMP RIH wI HES RSP. Test-set & release RSP w/2 stands in hole to insure RSP still attached to string - OK. Increase hole fill rate to 40 bph while RIH wi RSP. 6/28/2007 00:00 - 05:30 5.50 EV AL P DECOMP Continue RIH wI HES RSP. Shoot fluid level @ 400-600' at 0300 hrs. Continue filling hole wI seawater @ 40 bph. Found I bad pin & collar threads in stand 126 (out of 129). Replace 2 IDECOMP jts tubing. Continue RIH. 05:30 - 09:00 3.50 EV AL P 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 RSP out of the hole and run another 7" RSP in to the original set depth of approximately 8,250' +1-. 09:00 - 15:00 6.00 EV AL C DECOMP POOH with 7" RSP 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" RSP or a 7" Champ IV Packer run. ,15:00 - 17:00 2.00 EVAL C DECOMP On surface with 7" RSP. Inspect the RSP with the Halliburton I 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. Sreak out and lay Ic down the 7" RBP. PU and MU the 7" Champ IV Packer. 117:00 - 22:30 1 . 5.50 EV AL 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 I I I #15 due to galled threads. Replace with 31.37' and 31.75' I Printed: 7/24/2007 5:05:12 PM . . 7 BP EXPLORATION Operations Summary Report MPJ-~24\ LI MPJ-~24 \ L.. I WORKOVER NABORS ALASKA DRILLING I NABORS 3S From - To I Hours I Task I ! 17:00 - 22:30 ! 5.50! EV AL 22:30 - 23:30 ! 1.00 i EV AL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/28/2007 Code I NPT C I C I Phase DECOMP DECOMP Ii I I 23:30 - 00:00 0.50! EVAL C DECOMP ! 6/29/2007 00:00 - 08:30 8.50 EV AL C DECOMP 08:30 - 09:30 1.00 EVAL C 109:30 - 15:00 5.50 EVAL C 15:00 - 16:00 1.00 EVAL C DECOMP DECOMP DECOMP I DECOMP DECOMP ! DECOMP DECOMP DECOMP DECOMP 16:00 - 16:30 0.50 EVAL Ic 16:30 - 23:00 6.50 EVAL P I 23:00 - 00:00 1.00 EVAL P 6/30/2007 00:00 - 02:00 2.00 EVAL P I 02:00 - 04:30 2.50 EVAL P 04:30 - 12:00 7.501 EVAL P i i I 12:00 - 13:00 1.00 EVAL P DECOMP 13:00 - 16:30 3.50 EV AL P DECOMP 16:30 - 17:00 0.50 EVAL P DECOMP 17:00 - 18:00 1.00 EVAL P DECOMP 18:00 - 18:30 I 0.50 EVAL Ip DECOMP 18:30 - 23:30 ! 5.00 EVAL P DECOMP 23:30 - 00:00 0.50 EVAL P DECOMP Start 6/20/2007 Rig Release: 7/2/2007 Rig Number: Spud Date: 10/9/2000 End: 7/2/2007 Description of Operations 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. Close annular BOP. Pressure-test 7" casing to 1,500 psi for 30 charted minutes - good test. 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. On surface with 7" HES Champ IV Packer. Break out and lay down. PU and MU 7" HES RBP. TIH with 7" RBP on 2 7/8" Tubing from the Derrick. 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. Pressure test the 7" Casing against the 7" RBP at 8,250' to surface to 1,000 psi for 30 charted minutes - OK. 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. Set back DC's. Break out and lay down RBP setting tool. Clean & clear rig floor. Drain BOP stack. NO flow nipple & flange. Install & NU shooting flange. RU SWS wI lubricator extension, pump-in sub and packoff. Test shooting nipple to 1000 psi for 5 minutes - OK. RIH wI USIT logging tool. Log in cement evaluation/corrosion 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 well bore to 500 psi. Run the USIT tool from 500' to surface. 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. NO 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. PU and MU 7" RBP Retrieving Tool Assembly with Halliburton rep. TIH with Retrieving Tool Assembly on 2 7/8" Tubing from the Derrick. RU and circulate wellbore at 500'. Finish TIH with RBP retrieving tool to top of RBP. RU and circulate 60 bbls seawater at 4bpm 1710 psi to ensure clean fluid above RBP prior to releasing plug. Printed: 7/24/2007 5:05: 12 PM MPJ~24\Ll MPJ-~24\'-- \ WORKOVER Start: 6/20/2007 NABORS ALASKA DRilLING I Rig Release: 7/2/2007 NABORS 3S Rig Number: From -To Hours Task I Code I NPT I Phasê DescriþtiOn of Operations 00:00 - 00:30 0.50 EV AL I P i DECOMP Latch and release HBP. PUW / SOW = 40K 125K Ibs. RBP I I I released without a problem. 100:30 - 08:00 7.50 EVAL i P ,DECOMP LD 10 joints 2-7/8" tubing (7 extra + 3 for completion). POOH with 124 stands to Derrick. Double displace tubing while TOH. DECOMP On surface with 7" RBP. Break down and lay down with Halliburton rep. DECOMP Pull Wear Ring. Prepare to run completion. 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. i RUNCMP PU and MU completion jewelry with Baker Completions rep. ¡ Torque up the 4" Imp Buttress Tubing Screens connection to 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 Centrilift reps - OK. RUNCMP RIH with new ESP Completion on 27/8", 6.5#/ft, L-80, EUE 8rd Tubing. Using Best-O-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. RUNCMP Replace top coupling on stand #63. Replace bottom joint on stand #64 due to damaged pin threads. RUNCMP RIH 90 stands. Pump 10 bbls seawater down tubing to flush ,pump @ 1 bpm / 1,450 psi. RUNCMP I Splice electric cable at approximately 6,500'. RUNCMP Complete reeHo-reel electric cable splice. Pump 20 bph seawater in hole during splice. RUNCMP Continue RIH with 251 jts 2-7/8" ESP completion to 8,159'. RUNCMP PU and MU 2 7/8" Tubing Hanger with FMC rep. Final PUW / SOW = 48K Ibs / 26K Ibs. Ran a total of 124 LaSalle Clamps in the completion. 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. RUNCMP Land Tubing Hanger with FMC rep utilizing alignment pin. RILDS. 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. PJSM. NO BOPE and lay in Cradle. NU Adapter Flange and Tree. 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 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/1/2007 08:00 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 15:00 I I I 15:00 - 21:00 21 :00 - 21 :30 21 :30 - 23:30 7/2/2007 23:30 - 00:00 00:00 - 03:30 03:30 - 06:30 06:30 - 08:00 08:00 - 10:00 10:00 - 11:00 11 :00 - 12:00 12:00 - 14:30 114:30 - 16:30 16:30 - 18:00 . . BP EXPLORA TJON Operations Summary Report Page 6 of 7 Spud Date: 10/9/2000 End: 7/2/2007 1.00 EV AL i P I I 1.00 WHSUR I P 1.00 RUNCO~P I 4.00 RUNCOfl/lP I I 6.00 RUNCO~P 0.50 RUNC0r-rP RUNCO~P RUNCO P RUNCO P , I RUNCOMP RUNCO~P I RUNCO~P ! ! 2.00 0.50 3.50 3.00 1.50 2.00 i 1.00 RUNcotp 1.00 WHSUR P 2.50 I Bopsu~1 P 2.00 WHSUR P 1.50 WHSUR P I ! RUNCMP RUNCMP RUNCMP I Printed: 7/24/2007 5:05:12 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/2/2007 16:30 - 18:00 18:00 - 18:30 18:30 - 20:00 I I . . BP EXPLORATION Operations Summary Report Page 7 of 7 MPJ~24~\ MPJ-~24 L\ WORKO R Start: 6/20/2007 NABORS ALASKA DRilLING I Rig Release: 7/2/2007 NABORS 3S Rig Number: Hours Task Code I NP~I Phase 1--- 1.50 WHSUR pi! RUNCMP ! charted - OK. 0.50 WHSUR P I ¡ RUNCMP . Held prejob safety meeting. Service rig. 1.50 WHSUR P i i RUNCMP ¡Pull TWC wi lubricator. Set BPV. Make final ESP check. I Secure tree and cellar. Release rig @ 20:00 hrs. I I i I i I Spud Date: 10/9/2000 End: 7/2/2007 Description of Operations i I ¡ Printed: 7/24/2007 5:05:12 PM R~C .. STATE OF ALASKA· .~ ;E:/IISD ALASKA t AND GAS CONSERVATION CO. 1JISSION OCT I (J 2 . REPORT OF SUNDRY WELL OPERATH9tI$6ìG oog lM Cons AnchOlJn;1l' COf11f11isSiQ r¡ Change OutE'SP 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate III Other III Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well III 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 12114 3825 12114 3825 Casing Structural Conductor Surface Intermediate Production Liner Length 108' 8235' 3703' 4. Current Well Class: III Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-150 6. API Number: 50-029-22976-60-00 99519-6612 9. Well Name and Number: MPJ-24L 1 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 108' 108' 1530 520 7" 8264' 3855' 7240 5410 4-1/2" 8284' - 11987' 3860' - 3819' 8430 7500 Perforation Depth MD (ft): Slotted Liner 8374' - 11964' Perforation Depth TVD (ft): Slotted Liner 3873' - 3819' æANNED NO\I ~ 8 2005 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 8080' Treatment description including volumes used and final pressure: RBDMS 8Ft 0 CT ] J 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run III Daily Report of Well Operations III Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubina Pressure 15. Well Class after proposed work: o Exploratory III Development 0 Service 16. Well Status after proposed work: III 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 Si~~' Form 10-404 Revised 04/2004 Title Technical Assistant Phone 6~ 0 ,¡r~lf\' L \," 'J \ \ "",' a U J 1"'0! ~7 . ......... Prepared By Name/Number. DateV I ~ D -t) ') Sondra Stewman, 564-4750 Submit Original Only ~ 3-1/8" FMC horizontal) M P J -24\ L) Wellhead: 11" x 11" 5M tbg. 51-',,",01, FMC Horizontal tree Model 120 11" x 3.5" RH Acme & 8rd EUE (lop & bottom) j FMC TBG HNG w/ 3.5" 'H' BPV profile. I 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 ID = 6.151", cap. = 0.0383 bpf) (capacity w/ 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' DF elev. = 66.05' GL elev. = 36.30' ~ Cameo 2-7/8" x 1" side pocket KBMM GLM 173' Cameo 2-7/8" x 1" sidepocket KBMM GLM 7,860' I HES 2-7/8" XN nipple 2.205" ID 8,003' MS-1 Pressure Head 8,021' Tandem Pumps 100GC1150 & 19GC8200 GPMTAR1:1 8,033' Gas Separator GRSFTX AR H6 Tandem Seal Section GSB3DB UT/L T ABlHSN PFSA/FSA CL5 8,040' 8,045' 114 KMH 2330 volt, 30 amp Motor 8,059' Centrilift Pumpmate w/ fin centralizer I 8,074' ~ .JIll( ~ ~ 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 11/09/00 MDO 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'ù 5/20/05 L. Hulme ESP replacement by 4ES p.¥I.1\\)~ 00-02.9 ~ 2a.~l~.IdJ~ 9/01/05 MOO ESP Replacement by 4-es BP EXPLORATION (AK) ~) ') BP EXPLORATION Operations Summary Report Page 1 of 1 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 DECOMP 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 DECOMP 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 DECOMP 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 I Bull Head 250 bbls seawater 3 bpm 50 psi in Annulus Monitor I 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 DECOMP Set TWC and test 1000 psi 04:00 - 06:30 2.50 WHSUR P DECOMP NID Tree and Adaptor Flange. 06:30 - 08:30 2.00 BOPSUP P DECOMP Nipple-up Double stud adaptor, Test Spool, and BOP Stack. 08:30 - 12:00 3.50 BOPSUP 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 BOPSUP 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 DECOMP 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 DECOMP 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 DECOMP Clean and Clear rig floor 22:30 - 00:00 1.50 RUNCOtvP RUNCMP Pick up and assemble ESP Pump 9/2/2005 00:00 - 02:00 2.00 RUNCOtvP RUNCMP Service ESP pump Connect cable and test. 02:00 - 08:00 6.00 RUNCOtvP RUNCMP TIH with ESP Assembly and 2 7/8" Tubing by stands. Test cable every 2000'. Pump thru pump every 2000' ; 1 BPM @ 800 psi. Total Joints = 251ea. Make-up Tubing Hanger. 08:00 - 09:00 1.00 RUNCOtvP RUNCMP Slip and Cut Drilling Line (81'). 09:00 - 11 :30 2.50 RUNCOtvP RUNCMP Make upper ESP Cable splice. Attach to Penatrator and test. 11 :30 - 12:00 0.50 RUNCOtvP RUNCMP Land tubing Hanger. RILDS. Test. 12:00 - 12:30 0.50 RUNCOtvP 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. Perform final ESP Cable check. Good. Release Rig at 16:00 hrs. Printed: 9/12/2005 10:04:32 AM RECE'VEO . STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM ION OCT 0 4 2006 REPORT OF SUNDRY WELL OPERA TION~laska Oil & Gas Cons. Commission . 1. Operations Performed: M"""U' uti" o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 200-150 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage. Alaska 99519-6612 50-029-22976-60-00 7. KB Elevation (ft): 66.05 9. Well Name and Number: MPJ-24L 1 8. Property Designation: 10. Field 1 Pool(s): ADL 025515 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 12114 feet true vertical 3825 feet Plugs (measured) N/A Effective depth: measured 12114 feet Junk (measured) N/A true vertical 3825 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface Intermediate Production 8235' 7" 8264' 3855' 7240 5410 Liner 3703' 4-1/2" 8284' - 11987' 3860' - 3819' 8430 7500 Perforation Depth MD (ft): Slotted Liner 8374' - 11964' Perforation Depth TVD (ft): Slotted Liner 3873' - 3819' Tubing Size (size, grade. and measured depth): ?-7/R" 6 5# I-RO Ar\Ar\' 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 AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure TubinQ Pressure Prior to well operation: 0 0 0 350 0 Subsequent to operation: 445 173 290 200 280 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil 0 Gas DWAG 0 GINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knorcle~ge~ SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 ~ ,Q €:15 0 Printe<!\jame Sondra Stewman Title Technical Assistant {'--::i-::J --' Prepared By Name/Number: :~]50 .~ ~q{'C 'Sigoature---,Æ=>\.(Q~~~:c~.J---'______~ Phone Date~U-U - ) <?Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 no ~1 tstt OCT 0 f} 2006 Submit Original Only !f\lþl Tree: 3-118" FMC hOriZontal. Wellhead: 11" x 11" SM tbg. s , 11" x 3.5" RH Acme & Brd EUE (top & bottom FMC TBG HNG wi 3.S" 'H' BPV profile. . FMC ~oEn~ ~~~od~11~ I ~ Halliburton ES cementer I 2,397' I 2718" 6.S 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: 7So @ , MO Hole angle through perfs = 90 deg. RA tag at 8254' 3 Short joints B119'-B242' Milled window from 8264'-8276' Baker HR selling sleeve I 8284' Baker 7" ML torque master pkr 600-47 Wireline entry guide 8296' 8315' Baker HR selling sleeve Baker HMC liner hanger Halliburton landing collar Halliburton float collar Halliburton float shoe 8577' 8620' 8664' 4-1/2" SLOTTED INTERVALS 08- 8,373' - 11,964' MO (3590') OA- 8,656' - 11,953' MO (3296') DATE 11109100 11/21/00 5120/05 9101105 9110106 REV, BY MOO 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 . KB elev. = 28.55' OF elev. = 66.05' GL elev. = 36.30' Cameo 2-7/8" x 1" sidepockel KBMM GLM 173' Cameo 2-7/8" x 1" sidepocket KBMM GLM 7,860' HES 2-718" XN nipple 2.25" 10 8,002' GPOIS Pressure Head 8,021' Tandem Pumps: 86S/S38P11 & 16 GCNPSH GPMTAR':1 8,022' 8,032' Gas Separator GRSFTX AR H6 Tandem Seal Section I 8,041' GSB3DBFERHLSSCVH6SBlSBPRSNSBPFSA 133hp KMH 2205 volt, 37 amp Motor 8,055' Centrilift Pumpmate wi fin centralizer I 8,070' 4.S" 12.6#, L-80 IBT tubing. Baker Float shoe at 11975' 88jts. of SlollOO liner (3296') (8656'-11953') Mid-lateral TVO @ 3877' ~ ZoO- MILNE POINT UNIT WELL J.a24 fll API NO: 50-029-22976-00 -00 50·-z.q-Z:1.cnc,l.O 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: Rig Release: Rig Number: 9/5/2006 9/9/2006 Spud Date: 10/9/2000 End: 9/9/2006 9/5/2006 16:00 - 18:00 2,00 RIGD P PRE Scope down and lower derrick 18:00 - 19:30 1.50 MOB P PRE Move rig from J-06 to J-24 19:30 - 20:30 1,00 RIGU P PRE Prep location wI pit liner and spot rig, Move and spot camp 20:30 - 22:00 1.50 RIGU P PRE Raise and scope up derrick, Accepted Rig at 22:00 hrs, 22:00 - 23:00 1.00 KILL P DECOMP RU circulating lines to tree and to Tiger Tank for killing operations, Take on 2% KCI brine. 23:00 - 00:00 1,00 WHSUR P DECOMP PU lubricator and pull BPV. RD 9/6/2006 00:00 - 00:30 0.50 KILL P DECOMP Pressure test lines from 1000 to 3500 psi. 00:30 - 03:00 2.50 KILL P DECOMP 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 returns to surface in the annulas after pumping 116 bbls. Pumped a total of 580 bbls without brine returns. 03:00 - 06:00 3.00 KILL P DECOMP 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. 06:00 - 09:00 3.00 KILL P DECOMP Continue wait on additional 2% KCL. Service and maintain Rig. Check PVT Alarms, Inspect Derrick. 09:00 - 11 :00 2,00 KILL P DECOMP Bullhead KiIIlA at 6.0 bpm/240 psi. Bullhead tubing at 6.0 bpm/1500 psi. Both sides on a "screaming" vacuum, 11 :00 - 12:00 1.00 WHSUR P DECOMP 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, 12:00 - 12:30 0,50 WHSUR P DECOMP Rig-down test equipment. Blow down lines. 12:30 - 14:00 1.50 WHSUR P DECOMP Nipple-down Tree, Inspect lift threads (3" LH Acme). Good. 14:00 - 16:00 2.00 BOPSU P DECOMP Nipple-up Dual Stub Adaptor, Test Spool, and BOP Stack, 16:00 - 19:30 3.50 BOPSU P DECOMP PJSM. Test BOPE per BP/AOGCC requirements at 250/3500 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 19:30 - 20:00 0.50 WHSUR P DECOMP PU Lubricator and pull TWC. RU to pull 27/8" TBG, 20:00 - 20:30 0.50 PULL P DECOMP MU Landing Joint. Sting into HGR and pull to rig floor 57K to break loose, 52K to pull to floor. 20:30 - 00:00 3.50 PULL P DECOMP POOH w/2 7/8" ESP completion TBG. 9n 12006 00:00 - 01 :30 1.50 PULL P DECOMP Continue POOH w/2 7/8" Completion TBG. 01 :30 - 03:00 1.50 PULL P DECOMP POOH wI ESP and UD. Found broken shaft on upper pump. No sand was found in ESP. Printed: 9/11/2006 11 :50:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-224 MPJ-224 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/5/2006 Rig Release: 9/9/2006 Rig Number: Spud Date: 10/9/2000 End: 9/9/2006 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 M/U 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 2 7/8" 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 BPM/1200 psi. Drop ball, and pump to seat at 4.5 BPMl900 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. 9/8/2006 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 bpml 720 psi. Drop ball and pump to seat at 4.0 bpmSPMI 700 psi. Work RCJB several times at 97 SPM/1680 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 BPM/1700 psi. 19:00 - 22:00 3.00 RUNCMP Make reel to reel splice at 7584'1 77 stands in the hole. 22:00 - 22:30 0.50 RUNCMP Continue RIH wI ESP completion. 22:30 - 23:00 0.50 RUNCMP PUlMU HGR and install Penetrator. 23:00 - 00:00 1.00 RUNCMP Attach field connection. Plug into penetrator and test. 9/9/2006 00:00 - 00:30 0,50 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 1.00 RUNCMP Set TWC and test from top 1000 psi for 10 minutes. 02:30 - 04:00 1.50 RUNCMP ND BOPE 04:00 - 06:00 2.00 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 · STATE OF ALASKA ~ ALASKA....)L AND GAS CONSERVATION CGIw.~ISSION REPORT OF SUNDRY WELL OPERATIQMB~:I~{:~: ,- JUN ?, 0 200:1 Change Out ESR-" "",,_,.,)~,~.~,;il :fl 0<::,:::, C id,:h :,:.. "" .:J .1 ,: . 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate IBI Other IBI Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended \Àtel¡,h,:;J:~,'C:: IBI 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 12114 3825 12114 3825 Casing Structural Conductor Surface Intermediate Production Liner Length 108' 8235' 3703' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 200-150 6. API Number: 50-029-22976-60-00 99519-6612 9. Well Name and Number: MPJ·24L 1 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 108' 108' 1530 520 7" 8264' 3855' 7240 5410 4-1/2" 8284' - 11987' 3860' - 3819' 8430 7500 SCANNED ~JUN 2 1 2005 Slotted Liner 8374' - 11964' Slotted Liner 3873' - 3819' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 8100' Treatment description including volumes used and final pressure: RBDMS 8Ft ./UN 2 1 Z005 13, Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 15. Well Class after proposed work: o Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI 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 Print~~, Name_-f0ndra Stewman _____ .' ..' --zÇ..' '?7"-'~ (êi9~~~~re .ck~~:'/~ Jl~ I) Form 10-404 Revised 04/2004 Title Technical Assistant Pryo.(\e "".' 1564-4750, f U ~-< i b I ~'\~ i\ L /'v.' ./ Prepared By Name/Number: DateL..\!) 'l.O·C;::; Sondra Stewman, 564-4750 Submit Original Only Tree: 3-1/8" FMC horizontal t. ) 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. 1110' I MP J-24~-mp;S--2~JI FMC Horizontal tree Model 120 KB elev. = 28.55' DF elev, = 66.05' GL elev. = 36.30' :~ .41 ~ 143' 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 perfs = 90 deg. RA tag at 8254' 3 Short joints 8119'-8242' Milled window from 8264'-8276' Baker HR setting sleeve 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 W A I 8284' 8296' :~ 8315' 8553' 1= 8563' I~ 8577' '" 8620' 8664' 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 Camco 2-7/8" x 1" sidepocket KBMM GLM Camco 2-7/8" x 1" sidepocket 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 PFSA/FSA 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 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 -A PI n'D~ C)O:..02f1- Wl<O-(ct)-(Ù BP EXPLORATION (AK) ) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-t24 MPJ-i24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2005 Rig Release: Rig Number: Spud Date: 10/9/2000 End: 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 Dèg 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 BOPSUR P DECOMP Nipple up BOP Stack. Nipple up Kill and Choke Wing Valves. Torque all bolts. Hook up Koomey Hoses. Install 27/8" 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 BOPSUPP 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. LID 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 LID hanger. Pump 25 bbls of seawater down annulus. Monitor well. Cut & test ESP cable. LID 5 singles of 2 7/8" 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 27/8" 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 RUNCOrvP RUNCMP Pick-up and service ESP assembly. 09:00 - 17:00 8.00 RUNCOrvP RUNCMP TIH with ESP Assembly and 2 7/8" Tubing. Ran new XN-Nipple and new 27/8" 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 RUNCOrvP RUNCMP M/U 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 RUNCOi 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 BOPSU9 P RUNCMP N/D BOPE. I Printed: 5/23/2005 1 :37:45 PM ) ) BP Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPJ-f!24 MPJ-t24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2005 Rig Release: Rig Number: Spud Date: 10/9/2000 End: 5/20/2005 From - To Hours Ta.sk Code NPT Phase 21 :30 - 23:00 1.50 WHSUR P RUNCMP 23:00 - 00:00 1.00 WHSUR P RUNCMP DescriptionofÖperåtions 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 _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE o a:~ 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 Z Z To-- WELL LOG TRANSMI3~AL State of Alaska October 5, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, ~Ua~k~ 995o~ Fonuation Evaluation Log 1, MPJ-24 L1 PB1, MPJ-24 L1 PB AK-~-00220~- / MPJ-24: Digital Log Images: 2 CD Rom Discs ' PLEASE ACKNOWLEDGE RECEIFI' BY SIGNING AND RETURNING ~ ATTACHED COPIES OF THE TRANSMITI'AL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:. Signed: RECEIVED 007' 10 201)1 tdos~ Oil & Gas Cons. Comminion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _ NAM E CHANG E Pull tubing _ Alter casing _ Repair well _ Other_X NAME CHANGE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2713' FSL, 3402' FEL, Sec. 28, T13N, R10E, UM At top of productive interval 231' FNL, 1026' FWL, Sec. 29, T13N, R10E, UM At effective depth 422' FSL, 2757' FEL, Sec. 19, T13N, R10E, UM At total depth 422' FSL, 2757' FEL, Sec. 19, T13N, R10E, UM 5. Type of Well: Development _X Exploratonj_ Stratigraphic_ Service_ (asp's 551914, 6015110) (asp's 545762, 6017404) (asp's 541972, 6018037) (asp°s 541972, 6018037) 6. Datum elevation (DF or KB feet) RKB 66 feet 7. Unit or Property name Milne Point Unit 8. Well number MPJ-24L1 (MPJ-224L1) 9. Permit number / approval number 200-150 10. APl number 50-029-22976-60 11. Field / Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 108' Surface 8235' Production Slotted Liner 3703' 12114 feet Plugs (measured) 3825 feet 12114 feet Junk (measured) 3825 feet Size Cemented 20" 260 sx Arctic Set (Approx 1025 sx Arctic Set III, 7" 685 sx Class 'G' 4-1/2" Uncemented Measured Depth 137' 8264' 8284'-11987' True Vertical Depth 137' 3855' 3860'-3819' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2" Slotted Liner 8374'- 11964' 4-1/2" Slotted Liner 3873'- 3819' 2-7/8", 6.5#, L-80 TBG to 8131' with ESP to 8191 '. No Packer in Well. No SSSV in Well. RECEIVED SEP 3'8 ZOO1 Naska Oil & Gas Cats, Coa~i~o~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil MX Gas M Suspended Service 17. I hereby ce~fy that the foregoing is true and correct to the best of my knowledge. ~, Title: Milne Point Production Engineer · Form 10-404 Rev 06/15/88 · INAL Date September 26 2.~_~Q~.001 Prepared b~/DeWayne R, S=hnorr 564-5174 SUBMIT IN DUPLICATE bp (" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 26, 2001 Commissioner Julie Heusser Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Well Re-Naming Dear Commissioner Heusser: The operator requests the following Milne Point well be renamed as follows: APl Number Permit Number Old Name New Name 50-029-22976-60 200-150 MPJ-224L1 MPJ-24L1 Well MPJ-24L1 was part of the package of wells that we dropped the horizon designation in early 2001. The parent well was included, but we inadvertently forgot to specify the lateral in the original name change. Base Reservoir Management Team Leader TW:drs Cc: Well File Sharmaine Copeland (MB-2) Steve Davies AOGCC G ANC PDC WELL LOG TRANSMITr~ 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.,Evaluatio.n Logs: MPJ-24, L1,_L1 PB1 & L1 PB2, AK-MM-10127 o o - / q 1 LDWG formatted Disc with verification listing. APl#: 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 TI/ANSI~JTrAL L~'I'I'ER TO 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: $£P 1 £. 2001 STATE OF ALASKA ' ' ALASKa' ,,HL AND GAS CONSERVATION COMJ[,.,.,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 ~ ¥~.,'~,.:.,~:i(~t~7. Permit Number BP Exploration (Alaska) Inc.~: v[~_~ il 200-150 3. Address {~ ~,ur~~ ~- 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612~ .!~. Ht,WT~,.~ ~: 50-029-22976-60 4. Location of well at surface .~':.:..-.=. ----T---, -,--,-,~ 9. Unit or Lease Name 2713' NSL, 3402' WEL, Sec. 28, T13N, R10E, UM ~ Milne Point Unit At top of productive interval 5047' NSL, 4252' WEL, Sec. 29, T13N, R10E, UM (OA) .- ..- ,.-~, · At total depth~ '.. 10. Well Number 422' NSL, 2757' WEL, Sec. 19, T13N, R10E, UM ,, - . MPJ-24L1 !5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 66.05' ADL 025515 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 10/27/2000 10/31/2000 11/5/2000 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 12114 3825 FTI 12114 3825 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electdc or Other Logs Run MWD, GR, RES, PWD, ABI, Caliper 23. ' " ' CASING, LINER AND CEMENTI'~IG REC6R'I~ ...... CASING ' SE-I-rING DEPTH HOLE ' ' SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PU~ ~ Fr) 20" 94# H-40 Surface 1'08' 30" 260 ~,x Arcti~ Set (Approx.) ' '7" 26# L-80 29' 8264' 9-7/8" 1025 sx Arctic Set III, 685 sx Class 'G' 4-1/2" 12.6# L-80 8284' 11987' 6-1/8" Uncemented Slotted Liner 24. Perforations open to. P.roducti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and interval, s~ze ana number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 8191' MD TVD MD TVD 8374' - 11964' 3873' - 3819' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 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 Ho~rs tested PRODUCTION Fob" ' OIL-BBL GAs-Mc~= ' WATER-BBL CHOKE 'SIZE ~ GAS-OIL RATIO ' TEST PERIOD I J~Jow Tubing Casing Pressure CALCULAT~=D OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) " Press. 24-HOUR RATE , ~28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED FEB 4 00! Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. NA 7718' 3682' NB 7818' 3714' NC 7916' 3747' NE 7981' 3768' NF 8131' 3816' OA 8254' 3852' RECEIVED FEB 1 4 2001 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: SummarY of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~_~_,~_. ~ Title TechnicalAssistant Date' MPJ-24L1 200-150 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. IT;M 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. h'EM 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 (" (' VED BP EXPLORATION FEB 1_ & zDnPlage,,.,, 1 of 8 Operations Summary Report Alaska Oil & Gas Cons. Commission Legal Well Name: MPJ-224 Ancho[ag~ 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 Ph:aSe. . . .:..DeSCription of Operations · .. Daie .":.".,. Fr°rn..+'T0 HOurs.. : TaSk'"! Code .....:. · .... .. . : . · . 1018/2000 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 BOPSUF 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 3 112 to 5" drill pipe - Load pipe shed with 5" 19.51Wtt '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 & PVT alarms with Jeff Jones of AOGCC - all ok '19:30 - 00:00 4.50 DRILL INT1 Finish picking up 5" ddll pipe - Total 96 stands in derrick +/- 9100' - Pick up and stand back Flex collars, HWT drill pipe 10/9/2000 '00:00 - 00:30 0.50 DRILL INT1 Pre-Spud meeting with ddll crew and service personnel - Well plan & Hazards discussion ~00:30 - 03:00 2.50 DRILL INT1 Make up BI-IA #1' Pick up Spemj 6 3/4" Motor w/9 5/8" stablizer sleeve - adjust motor to 1.50 deg BH - Make up Sperry MWD I GR I PWD I 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 10/9/2000 - 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 fi/hr - 400 gpm 1500 psi - 70 rpm, 5,000 fi/lb torque - Wob 20k 110/10/2000 00:00 - 06:30 6.50 DRILL INT1 Continue Directional drilling 1825 to 2779' - Finish building angle to 72 06'30 deg at 290 deg Azimuth 4 deg 1100' build rate . - 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 Z50 DRILL INTI 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 10/11/2000 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 06:30 08:00 1.50 DRILL INT1 i Pumping, slight swabing - pooh to 2,238'- total 25 stands - 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 ( .... (" RECEIVED BP EXPLORATION FEB 1 zJ: ~{]~}~age2of8 Operations Summary Report Alaska Oil & Gas Cons. commission Anchorage · , Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 1019/2000 Event Name: DRILL+COMPLETE Start: 10/812000 End: 11122/2000 Contractor Name: NABORS Rig Release: 11122/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: · . ... · TaSk Phase 'From.To. na,~Uo:'--' SUb '~, ~ .pu~'e-'c";~'=on of':"':'::"' ':'oPerationS ...... "'":'"'::' '":' "" "... '" · . : '. ..... Code . . ....,. :....... :..: . . 10/11/2000 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 10/12/2000 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 I_IdVVD INT1 Trouble shoot MVVD 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 BI-IA - Down load MWD - Lay down pulser sub - Check bit & motor ok 18:00 - 19:30 1.50 DRILL LMWD ,INT1 Make up BI-IA #3 - Re-run bit #2 - Make up new pulser sub, Orient MWD and Program Sperry MWD / GR I Res I PWD ! 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 10/13/2000 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 fi/lb before lubetex addition - Last 24 hrs Art 12.0 hrs, Ast 4.75 hrs, Average Rop 121 fi/hr - Start building angle at 5 deg 1100' at +1- 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 motor 22:00 - 22:30 0.50 DRILL INT1 Service top drive 22:30 - 23:30 1.00 DRILL INT1 Make up BI-IA: Pick up 9 7~8" Hole opener, NIB stablizer, Sperry Acal tool wi 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 (" RECEIVED BP'EXPLORATION FEB 1 ~: ~00~age3of8 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage . . Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 1019/2000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11122/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: ., . . .. .. 'Date Erom- To' HOurs......TASk '.Sub ':'phase. :"'" '..'.':'""':: - DescriPtion of OperatiOns .. ~.. COde' ' .. "" .., '.' 10115/2000 00:00 - 00:00 24.00 DRILL INT1 5% lubricant to system while reaming starting at +1- 4,000' - Lower APl ~fluid loss to < 4.0 cc 10116/2000 00:00 - 04:00 4.00 DRILL INTl,. 'Finish reaming with packed hole opener assembly from 7,400 to bottom at 8,674' - Ream through tight spot until clean - PIU wt on bottom 155K, S/O 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 p/u 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 BI-IA - 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 Pm-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 its 1 - 40, none across 'OA' sand on its # 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 its 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 - +1- 6,500' -165 its in hole at 00:00 hrs - 10117/2000 00:00 - 01:30 1.50 CASE INT1 Finish running 211 its 7" 26~ L-80 BTC casing. 01:30 - 02:00 0.50 CASE INT1 M/U landing it. 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. Cimulate 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 ClP ~ 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 7-1116"-5M BOP 19:00 - 20:30 1.50 CASE INT1 Pick-Up 5" handling equipment. Hold pm-job safety meeting 20:30 - 00:00 3.50 CASE INT1 Lay down 5" drill pipe in mouse hole. 10/18/2000 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 ~ '~' ZDI~age4 of 8 Operations'Summary Report Alaska Oil & Gas Cons. Commission Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 10/912000 Event Name: DRILL+COMPLETE Start: 101812000 End: 1112212000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: · . .. ..... ·. . .. . '..Date.. From - To, Hours.. 'TaSk 'SUb 'Phase. ..~' ' DesCription of oPerations ~ . ' ,.. ' ...... .. COde ...'.' .... · .' .... . , , 10118/2000 01:30 - 02:30 1.00 CASE INT1 Nipple up flow line. Install wear ting. 02:30 - 05:00 2.50 CASE INT1 Pick up and stand back 37 stands 3-1/2" drill pipe. 05:00 - 11:00 6.00 BOPSUR INT1 Install test plug and test all rams and valves 250/2000; annular 250/2000. 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. 114:00 - 16:00 2.00 DRILL LNR1 Trip in hole picking up 3-1/2" 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 3-1/2" 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 1/2 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 PeRorm 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 psi, wob 5-8,000; Torque-7000 ft lbs 10/20/2000 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 ft 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 ft 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 ff 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 dean. 18:00 - 20:00 2.00 DRILL LNR1 Trip out to shoe ~ getting p/u & 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. 10/22/2000 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 MlU 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 I 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 F E B 1 4 ~ 0 01 Page 5 of 8 Operations Summary ReportAlaska 0il & Gas Cons. Commission ' ' Legal Well Name: MPJ-224 Common Well Name: MPJ-224 Spud Date: 1019/2000 Event Name: DRILL+COMPLETE Start: 1018/2000 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 .. " · DescriPti0n__ ~ °f'operati°ns':'_ ' ': · . . 10/23/2000 00:00 - 03:30 3.50 DRILL LNR1 Pump dry job and pooh. L/D hole opener, reamer and 2 stab. 03:30 - 04:30 1.00 CASE I LNR1 R/U to run slotted liner. Pre job safety meeting with all personnel. 04:30 - 07:30 3.00 CASE LNR1 Plu 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 M/u hanger and 1 stand drill pipe. Cir capacity of liner at 40 spT 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 1-114" ball and pump down. Ball did not set. Continue pumping at various rates in attempt to get ball to seat. Drop 1 314 ball and pressure to 1600 set hanger pressure to 3000 and release 21:00 - 00:00 3.00 CASE LNR1 Tripping out to 2 718, pulling wet pipe 10/24/2000 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 i 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 RA tag ~ 8119 '1012512000 i00:00 - 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 BHA 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 12000 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 free. 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 S'i'WHIP TGHT LNR1 Circ sweep 20:30 - 23:00 2.50 STWHIP TGHT LNR1 Trip out wi mill 23:00 - 00:00 1.00 STWHIP LNR1 Pick up whipstock and Tripping in 10/26/2000 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 BP EXPLORATION _ Page 6 of 8 FEB 4 ZOO1 Operations' Summary Report A!~ka Oil & Gas Cons. Commission Legal Well Name: MPJ-224 Anchorage Common Well Name: MPJ-224 Spud Date: 1019/2000 Event Name: DRILL+COMPLETE Start: 10/812000 End: 11/2212000 Contractor Name: NABORS Rig Release: 11/22/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: , , 'Date':''%''~ ...From ,'T0':' iH°urs :i.Task..:. :Sub' :.'Phase. '" Description.of.Operations' . · ..~.... ..'. ..~.... .... ... .... code. :.. '- .'.., . . . . ...... .:::'.:. '1 · 10/26/2000 04:30 - 05:00 0.50 STWHIP LNR1 '~ 05:00 - 09:30 4.50 STWHIP LNR1 Milled window from 8264'-8276'. Milled formation from 8276'-829 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 BH^. 16:30 - 19:00 2.50 DRILL . LNR1 Pick up new BHA 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 10/28/2000 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 fflbs, 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 fflbs, 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 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 I 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. 10/3012000 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 f/11880' to 12114'. Encountered shale at 12020'. 05:30 - 08:00 2.50 DRILL LNR2 Pump 25 bbl weighted HiVis sweep, circulate hole clean Pdnted: 11/28/2000 8:49:37 AM fED ' i'~,i..i~F--.i v r_.... ~,,, BP EXPLORATION Page 7 of 8 FEB 1 4 ZOO1 Operations Summary Report Alask;l Oil & Gas Cons. Commission Legal Well Name: MPJ-224 Anchorage Common Well Name: MPJ-224 Spud Date: 10/912000 Event Name: DRILL+COMPLETE Start: 10/8/2000 End: 11/22/2000 Contractor Name: NABORS Rig Release: 11/2212000 Group: RIG Rig Name: NABORS 4ES Rig Number: Date ' From - To Hours Task ' Sub ..phase '.' · 'DesCription of Operations . . .~ Code : ' .... ..... .' ,'. :' 10/31/2000 08:00 - 12:30 4.50 DRILL LNR2 ~Pump out of hole f/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 BI-IA 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 10/31/2000. Tested choke manifold while POOH. Install wear bushing. 22:30 - 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. 11/1/2000 00:00 - 02:00 2.00 DRILL LNR,?. TIH w! 6 118" hole opener. 02:00 - 03:00 1.00 DRILL LNR2 Slip & cut drilling line i03:00 - 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 wi hole opener fl 8350' to 12112'. 120 rpm, 8000 fi-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 BI-IA 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 94jts 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 2 718" 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 wi liner on 3 1/2" drillpipe recording PUISO 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. 11/312000 00:00 - 00:30 0.50 DRILL LNR2 Continue POOH to window 00:30 - 02:00 1.50 DRILL LNR2 POOH to 2 718" inner string 02:00 - 06:00 4.00 DRILL LNR2 POOH laying down inner string 08:00 - 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 w/35000 lbs, did not jar, circ bottoms up 12:30 - 18:00 5.50 DRILL LNR2 Slug, POOH wi 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 FEB 1 4 Operations Summary Report Alaska 0il & Gas Cmn_. Legal Well Name: MPJ-224 Ar~'horage Common Well Name: MPJ-224 Spud Date: 101912000 Event Name: DRILL+COMPLETE Start: 101812000 End: 1112212000 Contractor Name: NABORS Rig Release: 11122/2000 Group: RIG ~Rig Name: N^BORS 4ES Rig Number: Date · " From To Hors Task Sub · phase." ." · " . ..'DescriPtion of oPeratiOns · ___. - ~.:~u._ Code .. .....:.:..' " ... " .' 11/4/2000 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 1/2" drillpipe 11:30 - 12:30 1.00 DRILL LNR2 Pull wear bushing, clear floor 12:30 - 13:00 0.50 DRILL LNR2 Service dg & 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 TWC/hanger/manual 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 1/8" 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/Ibe 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 11/22/2000 00:00 - 01:00 1.00 WHSUR COMP NlU X-MAS TREE. TEST HANGER & TREE TO 5000 PSI, OK. 01:00 - 01:30 0.50 WHSUR COMP PULL TVVC & INSTALL BPV. 01:30 - 02:00 0.50 WHSUR 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. Printed: 11/28/2000 8:49:37 AM (' RECEIVED BP EXPLORATION FEB 1 zJ: ZOl~ge 1 of 1 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: COMPLETION Start: 11120/2000 End: Contractor Name: NABORS Rig Release: 1112212000 Group: RIG Rig Name: NABORS 4ES Rig Number: Date:" From :iTO..iHoU.rs..TaSk. i Sub. . Phase'.'.l · . DescriptiOn..of OPeratiOnS . ........ · code : '. '. 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 bdne. 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 BOPSUF COMP Body test BOP E to 250/3500 psi and 2500 annular 03:00 - 04:30 1.50 WHSUR COMP Pull TWCV wi 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 RUNCO! COMP Clear dg floor. Prepare to run ESP. 10:00 - 12:30 2.50 RUNCO! COMP Make up & service ESP. 12:30 - 16:30 4.00 RUNCO! :COMP Run ESP & completion assy. 16:30 - 18:30 2.00 RUNCO! COMP Make mid-run cable splice ~ 7278'. 18:30 - 19:30 1.00 RUNCO! COMP Run in hole w/completion assy. 19:30 - 20:00 0.50 RUNCO! COMP Make up hanger & PlU landing jt. 20:00 - 21:30 1.50 RUNCO! COMP Make hanger connection splice & connect to hanger. 21:30 - 22:00 0.50 RUNCO! COMP Land Tbg Hgr & RILDS. 22:00 - 22:30 0.50 RUNCO! COMP L/D landing jt. & set TWC. Test to 2500 psi, OK. 22:30 - 00:00 1.50 BOPSUF COMP Niple down BOPE. Printed: 11/28/2000 8:49:53 AM 00000 00000 00000 00000 000~0 ~~0 000~ ~~ ~0~ ~~ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ~ ooooo ooooo ooooo ooooo ooooo ~ ~~ zzzzz zzzzz zzzzz zzzzz zzzzz ~ ~ ~~ ~~ .......... mmmmm mmmmm mmmmm mmmmm mmmmm e~eJoq,3u¥ uo!ss!mtuoo 'suoo se9 '~ I!0 eqsel¥ 0.0 0 ~ ~o ~)6moqou¥ Um. SS~LU09 'SUO0 Se9 ~ I!O e'4sel¥ mm uo!ss!~uruoo 'suoo mD ~ l!O ~ ~o oooo~ ooooo oo oo ~ooo ~'O.c: ::r~ 0 · ~i~ '-~'-' ' '- .............. 00000 00000 00000 ZZZZZ ZZZZZ ZZZZZ 00000 O0 O0 zzzzz zzzzz mmmmm mmmmm mmmmm mmmmm mmmmm a~e~oqou¥ uo!ss{tutuoo 'suo3 se9 ,~ I!0 e)iselV Q3A 303 I ss!mmoo .suoO se9 ~ I!o e~lSelV Z ~~ ~~ ~~ ~~ 0 0000 00000 00000 00000 ZZZZ ZZZZZ ZZZZZ ZZZZZ mmmm mmmmm mm'mmm mmmmm oaAlaOa uo!ss!touio9 .suoO s~9 ~ l!O e~seff 09AI909~1 ~m ............... ~~ O00OO 00000 00000 00000 00000 00~ 00000 0~~ zzzzz zzzzz zzzzz zzzzz zzzzz ~ ooooo ooooo ooooo ooooo ooooo , ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ~ ~ .... . .o.,o ..... mmmmm mmmmm mmmmm mmmmm mmmmm a6e~qou¥ uo~!uJmo3 'suo9 se9 ~ I!0 e~lsel¥ ~00~ 1~ T OBAIBOBW uo~.ss~.u~uloO .suoO ~ e6e~oqou¥ UO!SS!mLUO0 'SUO:) se~) ,~ I~ eNSel¥ 03A~303W or~.,4co.~ ~o~c~ .t....,m~,on0 ...,..,m-.~coo ooooo, m~ 0 eSe~oqouv uoissltumoO 'suoo se9 ,~ IlO e)lS~lV ~OOZ ~ I 8]~ OBAIBOB A i~ · ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ , o °°°°° °°°°° °°°°° °°°°° °°°°° ~ zzzzz zzzzz zzzzz zzzzz zzzzz ~ ~ ~ mmmmm mmmmm mmmmm mmmmm mmmmm A eSe~o~u¥ uo!ss!~umoo 'suoo se9 ~ I!0 e~lSelY ~OOZ T~ I 83:1 OBAIBOB~I m mmmffim mmmmm C13AI303~1 mm eOe~ttou¥ uo!ss!tutt~ 'suoo se9 ~, ID e~lsel¥ C~3A~303~1 ~ D~ °~ °~~ °~~ ~°~ ~ ~ ~ ~ ~ 0000 00000 00000 .... b~~ ~~ ZZZZ ZZZZZ .ZZZZZ ZZZZZ ~ ~ ~1~ · ~~ · · · · .~-- · · . . - uo!~!mm~'~uoo~o~l~~ mmmm mmmmm mmmmm mmmmm e6eJo~uv UOJSSJUJLUO9 'SUO'3 se9 ,~ I!0 uo!ss!mtuoo 'su~O se9 ~ !~ ~OOZ l~ I 0,.-~. 00030 030'103{30~,~ 010,30001 ~ mmrnm mmmrnm mmrnmm mmmrnm eSe~oqouv uo!ss?tumo3 'suoo se9 9 ID e)lselV ALASKA OIL AND GAS CONSERVATION CO]~llSSION Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Milne Point Unit MPJ-224LI BP Exploration (Alaska) Inc. Permit No: 200-150 Sur Loc: 2713'NSL, 3402'WEL, Sec. 28, TI3N, R10E, UM Btmhole Loc. 10'NSL, 2633'WEL, Sec. 19, TI3N, RIOE, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPJ-224, Permit No. 200-149, API 50-029-22976-00. Production should continue to be reported as a function Of the original APl number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AA.C 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. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION .DATED this 2.~ ~ day of October, 2000 dlf/Enciosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i: Well MPJ-224 Multi-Lateral early approval ofPL 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.eom> To: "'Blair Wondzell"' <blair_wondzell~admin.state.ak.us> Our 'estimated spud is now--~--~tober, 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 wondze11@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 wondzell~admin.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 Well MPJ-224 Multi-Lateral early approval of P > > 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) 10/3/00 11:06 AM STATE OF ALASKA ALASK,(" ,IL AND GAS CONSERVATION COMJ(' .,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Ddll [] Reddll 1 lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen [] Exploratory [] Stratigraphic Test [] Development Oil 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. _P.r,qp.erty Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 c~'~"i? ~DL 0251~1~ 4. Location of well at surface 7. Unit or Propertyl~,~me 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 5049' NSL, 4336' WEL, Sec. 29, T13N, R10E, UM (CA) MPJ-224L1 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' MD~ No Close Approach 2560 11954' MD / 3818' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8360' MD Maximum Hole Angle 94 ° 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 Wei_Qht Grade Couplin,q Len,qth MD TVD MD TVD (include stafle data) 30" 20" 94# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7" 26# L-80 Hydril 521 8710' 30' 30' 8740' 3951 905 sx Arctic Set III, 609 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 3594' 8360' 3882' 11954' 3818' Uncemented Slotted Liner 19. To be completed for Reddll, Re-entry, and Deepen Operations. ,' , \~.,~ ~_.~\ Present well condition summary '~ (~ ~ ~ (.~,~,,'~ ~ Total depth: measured feet Plugs (measured) "~".%~-~,\\ q.'~~.~.x~-..~,~'~- true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production LinerORIGINAL RECEIVED Perforation depth:measured SEP 2 0 2000 true vertical AJask8 0~t & ..... ~,.,. Cons. Co~'nmission Anch0rage 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 Bourne, 564-4787 Prepared By Name/Number: Sondra Stewman, 564~750 21. I hereby certify that the forego~ng/,is tru~)a~~ co, he best of my knowledge / / Si~ned Steve Shultz ~/~7-'~J ~ h~,~¥~ -- Title Senior Drilling Engineer Date ~/~/?/~ Permit Number APl Number ~2..]~ ~p...,ro~bDat~ See cover letter ~~:)'"' J-~"~) 50-(~-~"' ~-- ?~:~' GO / -- for other requireme, nts Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures [] Yes I~ No Directional Survey Required ]~ Yes [] No Required Working Pressure for BOPE ~K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of Approved By D Taylor Seamoun, Commissioner the commission Date r.=_ ~ .~ Form 10-401 Rev. 12-01-85 Submit In Triplicate 1. Well Plan Summary Schrader Bluff Tract 14 2000 Program MPJ-224 Permit IWell Name: I MPJ-224 & MPJ-224L1 I Type of Well (producer or injector): 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 Start: 158' SNL, 728' EWL, Sec. 29, T13N, R10E X = 545,463 Y = 6,017,476 Z = 3874' TVDss J-224 OB Target End: J-224 L10A Target Start: 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, R10E 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: I 337196 Estimated Start Date: IOAMD: 111954'I OB MD: 11961' I Oct. 17~n 2000 I I OATVDrkb: ', I OBTVDrkb: 13951 I I Rig: I Doyon 141 I Operatin9 days to complete: I 40.9 OAMax. Inc.: 94° IKBE: 129'75' OB Max. Inc.: 91 ° I Well Design (c°nventi°nal' slim h°le' etc'): I Grassr°°ts multi'lateral with extended h°riz°ntalIlaterals. Jet pump completion. Objective: Drill 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 Y2" 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 ½" tubing jet pump completion. 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 W' completion tubing and a 7" x 3 Y~" 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. R:C .IVED SEP 2.0 2000 Alaska 0i~ & Gas [.,o;t~. ~mmission Anch0rage Version ~2, 9/18/2000 Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit 2. Current Well Information 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 2.1 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 2.2 Tar.qet 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 2.3 Materials Needed Production Casing: 8740' 1 each 1 each 60 each 1 assembly I 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: 7320' 200 off 4-5/8" x 5 3,~" x 8" 7,, x 4 1/2,, 4 4 1/2", 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 L-80 Completion: 7800' 3 1/2" CMU SSD 3 x 3 W' Landing nipples 7"x 3 ½" Packer 3Y2" 1 assembly 1 assembly 1 each I lot 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 1/2" tubing pup joints SEP 20 2000 Aiaska 0i'~ & G~s Co;~,s. C0mmissiol~ Ancho~ge , Schrader Bluff Tract 14 2000 Program MPJ-224 Permit 3. Drillin Hazards and Contingencies 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 Th_~ 9-7/8" s,J.,'f.~cc hc!c '::!!! ~''J' 'J:'!!!c'J '::!t,", ... _:;'..., ,ct cc .......... 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. The 7" casing will be se[ 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. 3.2.2. The 7" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 7000'. \~', 3.3. Lost Circulation 3.3.1. 3.3.2. 3.3.3. ~.h. as_not been encountered wh~le' drilling this interval on. previous,, J-Pad wells. Three more recent w~lls J-17, J-20, J21) used the same s~ngle 7 casing string design. T. hes~ w~lls._dld n~t_,~xPerience~ing and cementing casing' , 50 MD). This fault is located in the Ugnu formation. This fault is not expected to cause ' ' but contingency plans should be developed should lost circulation occur. Maintain minimum ECD thru use of proper hole cleaning procedures and PWD monitoring. _~,l..o,, ~,,,[,, ,-r,n ;,, ,~,~, a_7/a,, ,,,,,,,.,, ~,,,[,, ;...,,.,:.....,.., ,.. ~... 10.1 '~'~~"' Clean hole ECD in the 6- va[I q&l~v v I virgil ilVlV kv~ iii q, llVv i iv IlYl%.~ I~,~ V~i~F. III 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. 3.3.4. 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 Hi.qh 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 injection support. Reservoir pressure is expected to be 1750 psi (8.7 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3 Schrader Bluff Tract 14 2000 Program MPJ-224 Permit 3.5. Stuck Pipe pJ ~-~ I,.. I,.. I I"~'~0~ 3.5.1. The J-224 directional an has ~, ~°~"~' :"'" ' ......... ~a, ~f,,,u,, ~, ~n '~ .... ~--- h~ "';*~ 3600' ~'~ l~l~ LI I~ GUI I~ VVILI I ~ ~' ~ori~o~t~l i~t~ls i~ the ~~ res~oim. ~11 thes~ ~o1~ i~t~ls he~ ~ssiv~ ~r~bl~ s~ i~t~ls, w~i~ ~ I~ to ~iff~re~fi~l sti~i~ of the ~rill stri~. ~oo~ ~rilli~ praGfi~ to ~voi~ differential sti~i~ ~re re~ire~ ~ro~r ~ ~ro~i~s ~ o~tli~ i~ the ~roi~ ~ ~m~ra~ ~st ~ ~los~l~ follow~. 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. ~k of the J-224 well is running the 7" casing to TD. The 7" casing must be run all the way to_TD to_a~ateral to be drilled. Sticking the casing off bottom will result in not being ~,~ able to drill the multilater~he 9-7/8" surface hole has a 5820' high angle tangent ~tal atTD. ~e past have experienced problems running wells it was ng. Past operations were successful in running the 7" casing using these techniques in additiona ' I 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 Y2" slotted liners. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.7 lb/gal CA/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 CA 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 l~l[ates have been encountered on H-Pad and mud returns should be monitored to determine if .~1~ h~/d~ountered on this well. 3.7.2. I~ the event.of h~ming, the following procedures should be undertaken: a) Remember that hydrat~ is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbe'~l~ gas is coming out of the hole. All that mud weight does is control hey[, radically the gas i3r~ut at surface allowing you to continue drilling and getting .. t_hr°~g~ th.e. ~ecfi°n a~ quicklY as p°ss'ibie'"'~_ b} 2_ p_~b_L~it_hi_n.~.ha~e in m. ud system prior t_o drilli~,~s ~). ~16% Drill.& Slide-have in _m~d_ ~y_~te.rn prior_ t_~_drilling hYdr~,,,,,~,, ould usually cut te section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9. ud weight may vary from pad to pad depending on hydrate gas concentration. Schrader Bluff Tract 14 2000 Program MPJ-224 Permit e~,~Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized m~lects actual mud cut weight. f)-- Drill through th~ate section as quickly as possible, whi~e minimizing gas belching at bell nipple. Slower pump r~ay be applicable while monitoring torque and drag for potential ~'~' . ~i.°ble.ms'' ..... ~ g) Minimize circulation time. This ~ccelerates~t"~..h..ydrate thawing problem releasing more gas .. i.~t° the Wellbore-- ~ ~) Keep mu~ cir. c.ulating' temPerature as cold as.possible. ___ _ ~ (lower surface caliper log has shown gauge hole even through the permafrost by adjusting (opera 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. Geosteerinq 3,10,1, Two rig site geologists are required onsite for accurate geosteering through the thin ONOA 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. Hvdroaen Sulfide 3.11.1. MPJ Pad is not designated as an H2S Pad. 1 Schrader Bluff Tract 14 2000 Pro~lram MPJ-~4 Permit Drillin_ Program 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 I Well Name Current Status I Production Priority I 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 Program - rties,~ud - LSND Freshwater Mud ~ ~ Funnel_v_is__ ~ .... ~ APl Filtrate LG Solids 8.6- 9.2 50- 150 ~"~ --'~ ~ ~ 9.0~ ~-----<.6.,~, 6-1/8" Production Hole Mud Properties: OB/OAI KCL - CaCO3 Baradril N Mud I Density(PPg) FunnelvisI YP i ,,.. i ,. IAPIFiltrate ILGSolid__~ 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 To;) 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 m°p OA 8339 3810 1715 8.66 ,, BaseOA ., 8443, 3842 ........ 1729 , 8.65 ,, Top OB 9200 3874 1743 8.65 Base OB 3897 1754 8.66 4.5. CasincETubin.q Program Schrader Bluff Tract 14 2000 Pro~lram MPJ-~4 Permit Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tb~l O.D. MD/TVDrkb 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 Y=" 12.6# L-80 IBT-Mod 3,321' 8,640'/3,951' 11,961'/3,891' 6-1/8" OA 4 1/~,, 12.6# L-80 IBT-Mod 3,594' 8,360'/3,882' 11,954'/3,81 8' Tubing 3 1/~,, Jet Pump 9.3# L-80 EUE-Mod 7,770' 30'/30' 7,800'/3,709' 4.6. Cement Calculations I siz 17" 26 Ib/ft L-80 Hydril 521 I I Basis S..0° excess over gau,g,e hole in permafrost interval, 50% excess over gauge hole below permafrost I_Tan~ort Collar at 1000 MD as a contingency in case cement does not circulate to surface in single stage Total Cement,V,,o_lume: I Spacer 75 bbls of B45 Viscosified Spacer Weighted to 10.5 ppg ~ I Lead 905 sx 716 bbl 10.7 lb/gal Arctic Set III Light ~J Tail 609 sx 127 bbl 15.8 lb/gal Class G BHST -80° F from SOR, BHCT 85° F estimated by Dowell 4.6.1. Casing Spaceout a) Space 7" casing out and long/short joints as required to place the top of a long full joint at the actual top of sand to allow for the window to be milled just below the top of the OA sand and in the mi~ a full joint of casing. Run full casing joints across the OA sand. Any casing pup joints requ for spaceout should be placed below the base of the OA sand. b) A radioactive tag should be placed in sing string at 100' above the OA sands. c) Emergency 7" casing slips can be used 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 :he upper OA sand. With the exception stated above, 7' straight blade rigid centralizers be run floating in the middle of each joint of casing from the 7" casing shoe up to 7300' MD above NA sand). Zonal isolation with cement is required between the top of the OA ar 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 Loqain.q Program Open Hole: Cased hole: None ~ ~ c..,- 6-1/8" Hole Sections: Cased Hole: ~._=! ! r:.~liper - (Resistivity over production interval only) MWD / GPJRes I PWD / ABI / ABGR - (ABGR may re run if available) None Schrader Bluff Tract 14 2000 Pro~lram MPJ-224 Permit 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzle / K-Rev's Hours Number and Section Flow Rate i & ',, ~-//o u - o,/,,u ~r,=, ~u~,,=~ MX C'; p,c,',',~r ,-.A-~~,~ - ,.,,., ...... ~Fm 3 (OB lat.) 6-1/8" 8,740' - 11,961' PDC 250+ 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~,, o 0 o__.~zQ.Q_gg..~ 170 4 degree initial build adj with 9.6" sleeve ' ' - . . 3 & 4 4 3,~,, 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-224 Permit 5. MPJ-224 Operations Summary 5.1. Pre-Riq 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 Install FMC 11" 5m wellhead NU 13-5/8" 5m BOP. Test BOP to 2000/250 psi Lay down 5" drill pipe, PU 3 Y2" drill pipe MU BHA with 6-1/8" PDC bit, 4 ~" MWD/LWD (GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe 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 ~2" 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 3,~,, 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 1/2" 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 1~,, TEC wire to surface 39. Set tubing plug and BPV. ND BOP. Install and test tree 4O. RDMO 11' x 3-1/2", EUE (btm) . ~ Cellar Box ELEV = 3.5.50' FMC tbg. hanger, 'H' BPV profile I 110' 20" 92 Ib/ft, H-40 Welded ~ · ; ~ · 9.3 EUE-M ,, .. __ Coupling OD: 4.5" Drift/ID' 2.867"/2.992" ~ f ~ , Phoenix TEC Wire II: 1 3-1/2"x1" Gas Lift Mandrel I' ! Selective X Nipple 2.813" ID I II I , Baker CMU Sliding Sleeve with 2.813 ID Selective X Profile Jet Pump Installed in Sliding Sleeve ~. Phoenix Pressure Gauge (Intemal Pressure) 6,151" , --, Wireline Entry Guide Casing i~: 6.276:: ' Multi-Lateral Junction ' 8,357' ~ ~ 6-1/8" CA Lateral TD 11,954' Well Inclination @ Window = 72 Degrees~lJ-"'"'"'-- ~ Flow Thru Hollow Guide Stock ~ I ~ CA Horizontal , Multi-Lateral Packer. ....................... ' 4-1/2" Slotted Liner (Plop & Drop) 6-118" Open Hole ComDle. ti_or~.a~J;oatiaaert~% 7" Casing Shoe @ 8,737'.a SEP 20 ~'~' ~ OB Horizontal ,',,-~, 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 BP Exploration (Alaska) MPJ-224 L1 Drilling Hazards and Contingencies 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 6-1/8" horizontal 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 planned mud weight is 9.1 lbs/gal which provides a 0.4 lbs/gal overbalance (80 psi). Kick tolerance -Infinite @ 11961' MD Lost Circulation · Lost circulation has not been encountered while drilling this interval on previous J-Pad wells. · Clean hole ECD in the 6-1/8" horizontal hole 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 High Pressures - No Issues Stuck Pipe · The J-224 directional plan has a 3600' horizontal interval in the OA reservoir. This hole interval has 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! · There is a risk of differentially sticking the 4 %" slotted liner. The 9.1 lbs/gal mud will be 0.4 lbs/gal overbalanced to the 8.7 lbs/gal OA 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 Hydrogen Sulfide- No Issues 0 o 0 0 0 0 O-- 0 0 .E s6u!q~oN 0 ~0 LI.I s6u!q~oN 111; 11111 a / ::": ":":" ~ L °° § :::: ::::: ~- Z :: ,,,, ._..9. I 0 ~;009 = qou! I. :aleoS qldeo 0 0 0 II o ~ ~ 8Z o oooo = or ~ 8 8°000 · · , · . ~ 0000 ~ O~ ~ ...... 0000 = ~00 = 8°00 ~ == = .~oo . o~ = o 8°000 ~~ ~~ ~ ..... ~~ ~~ ..... ~~ ~ ooooo ooooo ooo~o ~ ~ ~ ~z~ ~ zzzz z ~zz~z ~z~ z~=zz 88888 88888 88888 ooooo~ ooooo ooooo 'c: 0 Z ZZZZZ ZZZZZ ZZ Or' 00888 ooooo oo ~ 0 Mn .eM ZZZ ZZZ o ADMINISTRATION 1. 2. . 4. 5. 6. 7. 8. 9. 10. 11. A:~.~.R DATE 12. ?.- 4~.Z'?--'~ 13. ~:NGINEERING 14. ,GEOLOGY Permit fee attached. Lease number approl~ri~t;.'~: i~.' i ~: ~4~.' ~:)~, i/:C~ -~ Unique well name and.number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 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 ~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA ~ UNIT# ~ ON/OFF SHORE N~ ~ QATE Permit can be issued wlo hydrogen sulfide measures ..... (~ N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones .......... ; '../~/l Y N Seabed condition survey (if off-shore) ....... : .~,~'.. Y N Contact name/phone for weekly progress reports ~ex151oratory only] Y N 30. 31. 32. 33. 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE Y N GEOLOGY:, (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20...AAC 25.252 or 20 AAC 25.412. ENGINEERING: UlCIAnnular COMMISSION: Y N Y N Y N Comments/Instructions: Z c:Vnsoffice\wordian~diana\checklist (rev. 02117100) Well Histo.ry File APPENDIX Information of detailed nature that is not 'particularly germane to the Well permitting. Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPE .N. DIX~ No'special'effO .rt has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Aug 21 16:16:10 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/21 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-224 L1 PB2 500292297671 BP Exploration (Alaska), Inc. Sperry Sun 21-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 5 MWD RUN 6 AK-MM-00220 AK-MM-00220 A. WEAVER A. WEAVER E. VAUGHN E. VAUGHN 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 8264.0 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, 3, 5 AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). THE GAP IN SROP FROM 8264' MD, 3855' TVD TO 8290' MD, 3861' TVD IS DUE TO A MILLING RUN. MPJ-24L1PB2 IS TIED INTO MPJ-24 AT THE KICKOFF POINT. MPJ-24L1PB2 IS TIED INTO MPJ-24L1PB1 AT THE KICKOFF POINT. MPJ-24L1PB2 KICKS OFF FROM MPJ-24 AT 8264' MD, 3855' TVD (TOP OF WHIPSTOCK MPJ-24L1PB2 KICKS OFF FROM MPJ-24L1PB1 AT 10291' MD, 3832' TVD. 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. 6. MWD RUNS 1 - 3, 5, AND 6 WITH API # 50-029-22976-71. DEPTH OF 11115' MD, 3828' TVD. REPRESENT WELL MPJ-24L1PB2 THIS WELL REACHED A TOTAL 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 ....... 01/08/21 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 GR 100.0 ROP 141.5 FET 2721.5 RPD 2721.5 RPM 2721.5 STOP DEPTH 11042.0 11115.0 11049.5 11049.5 11049.5 RPS 2721.5 11049.5 RPX 2721.5 11049.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 100.0 2779.0 2 2779.5 6437.0 3 6437.5 8264.0 5 8264.5 10291.0 6 10291.5 11115.0 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 11115 ROP MWD FT/H 4.93 756.33 GR MWD API 15.44 136.53 RPX MWD OHMM 0.26 1271.47 RPS MWD OHMM 0.51 2000 RPM MWD OHMM 0.11 2000 RPD MWD OHMM 0.67 2000 FET MWD HR 0.17 16.54 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 11115 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean Nsam 5607.5 22031 196,431 21897 68.9759 21885 13.0089 16657 14.5021 16657 15.5126 16657 16.381 16657 0.980445 16657 First Reading 100 141.5 100 2721.5 2721.5 2721.5 2721.5 2721.5 Last Reading 11115 11115 11042 11049.5 11049.5 11049.5 11049.5 11049.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/21 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: in$ite 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 ($): 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 Mean Nsam DEPT FT 100 2779 1439.5 5359 ROP MWD010 FT/H 4.93 546.06 169.656 5276 GR MWD010 A?I 20.47 117.42 63.7506 5261 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 ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 100 141.5 100 Last Reading 2779 2779 2730 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Nun{bet ........... 1.0.0 Date of Generation ....... 01/08/21 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 RPX 2721.5 6376.5 RPS 2721.5 6376.5 RPM 2721.5 6376.5 RPD 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: 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 Name Service Order 75.2 TOOL NUMBER PB01688HWGRM6 PB01688HWGRM6 9.875 Water Based 9.20 74.0 9.2 3OO 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 1 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 Mean 4579.25 248.934 65.6443 11.1415 11.605 12.3 12.7064 0.816222 First Reading For Entire File .......... 2721.5 Last Reading For Entire File ........... 6437 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 File Trailer Service name ............. STSLIB.003 Service Sub Level Name,,, Version Number ........... 1,0.0 Date of Generation ....... 01/08/21 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB,004 Service Sub Level Name... Version Number ........... 1,0,0 Date of Generation ....... 01/08/21 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 8264,0 RPX 6377,0 8264,0 FET 6377,.0 8264,0 RPD 6377,0 8264,0 RPM 6377,0 8264,0 RPS 6377,0 8264.0 ROP 6437.5 8264,0 $ 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): 8264.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 8264,0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8,90 MUD VISCOSITY (S): 67,0 MUD PH: 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: 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 5.000 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 20 6 24 7 28 8 65.0 Name Service Unit Min Max DEPT FT 6368.5 8264 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 ........... 8264 File Trailer Service name ............. STSLIB.004 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 01/08/21 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 7316.25 178.71 64.4486 12,9418 13.1205 13.8946 14.099 1.1663 Nsam 3792 3654 3792 3775 3775 3775 3775 3775 First Reading 6368,5 6437.5 6368.5 6377 6377 6377 6377 6377 Last Reading 8264 8264 8264 8264 8264 8264 8264 8264 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8264.5 10291.0 GR 8264.5 10291.0 RPX 8264.5 10291.0 RPM 8264.5 10291.0 FET 8264.5 10291.0 RPS 8264.5 10291.0 ROP 8290.0 10291.0 $ LOG HEADER DATA DATE LOGGED: 28-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): 10291.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.6 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01697HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB01697HAGR4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 48.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .155 82.4 MUD FILTRATE AT MT: .160 70.0 MUD CAKE AT MT: .200 70.0 # 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 MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HR Min 8264.5 10.32 44 46 0 26 0 51 0 11 0 67 0 44 Max 10291 553.41 117.22 1271.47 2000 2000 2000 5.94 Mean Nsam 9277.75 4054 168.41 4003 77.0455 4054 17.0814 4054 21.5778 4054 23.4835 4054 25.7269 4054 1.11488 4054 First Reading For Entire File .......... 8264.5 Last Reading For Entire File ........... 10291 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1,0,0 Date of Generation ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Reading 8264.5 8290 8264.5 8264.5 8264.5 8264.5 8264.5 8264.5 Last Reading 10291 10291 10291 10291 10291 10291 10291 10291 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1,0.0 Date of Generation ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: START DEPTH STOP DEPTH 10291.5 11049.5 10291.5 11049.5 10291.5 11049.5 10291.5 11049.5 10291.5 11042,0 10291.5 11115.0 10291,5 11049.5 31-OCT-00 Insite 4.05,2 65.44 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 ............. Uadefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,,.0 Name Service Order Memory 11115.0 76.6 95.0 TOOL NUMBER PB01697HAGR4 PB01697HAGR4 6.125 KCL 9.20 49.0 8.1 25500 3.6 Units Size Nsam Rep Code Offset Channel .180 70.0 .149 86.0 .160 70.0 .200 70.0 DEPT FT 4 1 68 ROP MWD060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD060 FT/H GR MWD060 API RPX MWD060 OHMM RPS MWD060 OHMM RPM MWD060 OHMM RPD MWD060 OHMM Min 10291.5 9 97 52 96 3 62 3 87 3 89 4 48 Max 11115 379.63 136.53 41.65 47.69 43.44 41.38 Mean 10703.3 156.427 93.0673 11.2926 12.9934 13.7202 14.7926 Nsam 1648 1648 1502 1517 1517 1517 1517 First Reading 10291,5 10291.5 10291.5 10291.5 10291.5 10291,5 10291.5 Last Reading 11115 11115 11042 11049.5 11049,5 11049.5 11049,5 FET MWD060 HR 0.47 3.09 0.950145 1517 First Reading For Entire File .......... 10291.5 Last Reading For Entire File ........... 11115 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 10291.5 11049.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/21 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 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Aug 16 17:53:25 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/16 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 MPJ-24 L1PB1 500292297670 BP Exploration (Alaska), Inc. Sperry Sun 16-AUG-01 MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: AK-MM-00220 AK-MM-00220 AK-MM-00220 LOGGING ENGINEER: M. HANIK R. FRENCH R. FRENCH OPERATOR WITNESS: E. VAUGHN 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 5 AK-MM-00220 A. WEAVER E. VAUGHN 28 13N 10E 2713 3402 .0O 66.05 36.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) iST STRING 20.000 110.0 2ND STRING 9.875 7.000 8264.0 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, 3, AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. THE GAP IN SROP FROM 8264' MD, 3855' TVD TO 8290' MD, 3861' TVD IS DUE TO A MILLING RUN. 5o MPJ-24L1PB1 IS TIED INTO MPJ-24 AT THE KICKOFF POINT. MPJ-24L1PB1 KICKS OFF FROM MPJ-24 AT 8264' MD, 3855' TVD (TOP OF WHIPSTOCK 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. 6. MWD RUNS 1 - 3 AND 5 REPRESENT WELL MPJ-24L1PB1 WITH APi % 50-029-22976-70. THIS WELL REACHED A TOTAL DEPTH OF 10867' MD, 3821' 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 ....... 01/08/16 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 10797.0 ROP 141.5 10870.0 FET 2721.5 10804.0 RPD 2721.5 10804.0 RPM 2721.5 10804.0 RPS 2721.5 10804.0 RPX 2721.5 10804.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 100,0 2779,0 2 2780.0 6437,0 3 6437,5 8264.0 5 8264.5 10870.0 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 Units Size Nsam Name Service Order DEPT FT 4 1 ROP MWD FT/H 4 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 FET MWD HR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Service Unit Min Max DEPT FT 100 10870 ROP MWD FT/H 2,17 756,33 GR MWD API 15,44 117,45 RPX MWD OHMM 0,26 1271,47 RPS MWD OHMM 0,51 2000 RPM MWD OHMM 0,11 2000 RPD MWD OHMM 0.67 2000 FET MWD HR 0,17 16,54 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 10870 File Trailer Service name ............. STSLIB,001 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 01/08/16 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,002 Mean Nsam 5485 21541 197,495 21407 68,0922 21395 13.0398 16166 14,4772 16166 15,4674 16166 16,3037 16166 0,997234 16166 First Reading 100 141,5 100 2721.5 2721,5 2721,5 2721,5 2721,5 Last Reading 10870 10870 10797 10804 10804 10804 10804 10804 Physical EOF File Header Service name ............. STSLIB,002 Service Sub Level Name,,. Version Number ........... 1,0o0 Date of Generation ....... 01/08/16 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 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 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 ....... 01/08/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean Nsam 1439.5 5359 169.656 5276 63.7506 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 ....... 01/08/16 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 RPM 2721.5 RPD 2721.5 RPS 2721,5 RPX 2721.5 FET 2721.5 GR 2730.5 ROP 2779.5 $ 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 $ STOP DEPTH 6376.5 6376.5 6376.5 6376.5 6376,5 6368.0 6437.0 12-OCT-00 Insite 4.05.2 65,44 Memory 6437.0 69.1 75.2 TOOL NUMBER PB01688HWGRM6 PB01688HWGRM6 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 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 5.000 72.0 5.420 65.9 9.000 72.0 3.500 72.0 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 ....... 01/08/16 Maximum Physical Record..65535 File Type ................ LO 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 Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/16 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 8264.0 FET 6377 0 8264.0 RPD 6377 0 8264.0 RPM 6377 0 8264.0 RPS 6377 0 8264.0 RPX 6377 0 8264.0 ROP 6437 5 8264.0 $ 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 8264.0 BOREMOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 67.0 MUD PH: 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 20 6 24 7 28 8 Name Service Unit Min DEPT FT 6368.5 ROP MWD030 FT/H 5.07 GR MWD030 API 21.07 RPX MWD030 OHMM 2.25 RPS MWD030 OHMM 2.2 RPM MWD030 OHMM 2.13 RPD MWD030 OHMM 2.32 FET MWD030 HR 0.2 Max 8264 487 96 111 19 73 64 79 74 84 71 86 84 16 54 Mean 7316.25 178.71 64.4486 12.9418 13.1205 13.8946 14.099 1.1663 First Reading For Entire File .......... 6368.5 Last Reading For Entire File ........... 8264 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/16 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB.005 Nsam 3792 3654 3792 3775 3775 3775 3775 3775 First Reading 6368.5 6437,5 6368.5 6377 6377 6377 6377 6377 Last Reading 8264 8264 8264 8264 8264 8264 8264 8264 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/16 Maximum Physical Record. o65535 File Type ................ LO Previous File Name ....... STSLIB,004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 8264.5 RPM 8264.5 RPS 8264.5 RPX 8264.5 GR 8264.5 FET 8264.5 ROP 8290.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 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): STOP DEPTH 10804.0 10804.0 10804.0 10804.0 10797.0 10804.0 10870.0 28-OCT-00 Insite 4.05.2 65.44 Memory 10867.0 76.6 95.0 TOOL NUMBER PB01697HAGR4 PB01697HAGR4 6.125 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 48.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 MUD AT MAX CIRCULATING TERMPERATURE: .155 MUD FILTRATE AT MT: .160 MUD CAKE AT MT: .200 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 70.0 82.4 70.0 70.0 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 16 20 24 28 Name Service Unit Min Max DEPT FT 8264.5 10870 ROP MWD050 FT/H 2.17 553.41 GR MWD050 API 44.46 117.22 RPX MWD050 OHMM 0.26 1271.47 RPS MWD050 OHMM 0.51 2000 RPM MWD050 OHMM 0.11 2000 RPD MWD050 OHMM 0.67 2000 FET MWD050 HR 0,4 5.94 First Last Mean Nsam Reading Reading 9567.25 5212 8264.5 10870 166.338 5161 8290 10870 78.8442 5066 8264.5 10797 15.8447 5080 8264.5 10804 19.6188 5080 8264.5 10804 21.1947 5080 8264.5 10804 23.1191 5080 8264.5 10804 1.13211 5080 8264.5 10804 First Reading For Entire File .......... 8264.5 Last Reading For Entire File ........... 10870 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/16 Maximum Physical Record.,65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/16 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 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Aug 23 13:57:21 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/08/23 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 L1 500292297660 BP Exploration (Alaska), Inc. Sperry Sun 23-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 5 MWD RUN 7 AK-MM-00220 AK-MM-00220 A. WEAVER A. WEAVER E. VAUGHN E. VAUGHN 28 13N 10E 2713 3402 .00 66.05 36.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 20.000 110.0 2ND STRING 9.875 7.000 8264.0 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, 3, 5 AND 7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). THE GAP IN SROP FROM 8264' MD, 3855' TVD TO 8290' MD, 3861' TVD IS DUE TO A MILLING RUN. MPJ-24L1 IS TIED INTO MPJ-24 AT THE KICKOFF POINT. MPJ-24L1 IS TIED INTO MPJ-24L1PB1 AT THE KICKOFF POINT. MPJ-24L1 KICKS OFF FROM MPJ-24 AT 8264' MD, 3855' TVD (TOP OF WHIPSTOCK). MPJ-24L1 KICKS OFF FROM MPJ-24L1PB1 AT 10035' MD, 3837' TVD. 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. MWD RUNS 1 - 3, 5, AND 7 WITH API # 50-029-22976-60. DEPTH OF 12115' MD, 3827' TVD. REPRESENT WELL MPJ-24L1 THIS WELL REACHED A TOTAL 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 ....... 01/08/23 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 GR 100.0 ROP 141.5 FET 2721.5 RPD 2721.5 RPM 2721.5 RPS 2721.5 STOP DEPTH 12041 0 12114 0 12048 0 12048 0 12048 0 12048 0 RPX 2721.5 12048.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 10029.5 10030.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 5 MWD 7 $ REMARKS: MERGED MAIN PASS, $ MERGE TOP MERGE BASE 100.0 2779.0 2779.5 6437.0 6437.5 8264.0 8264.5 10035.0 10035.5 12114.0 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 100 12114 ROP MWD FT/H 4.93 1239.19 GR MWD API 15.44 117.45 RPX MWD OHMM 0.26 1421.41 RPS MWD OHMM 0.51 2000 RPM MWD OHMM 0.11 2000 RPD MWD OHMM 0.67 2000 FET MWD HR 0.17 16.54 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 12114 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,002 Mean Nsam 6107 24029 196.979 23895 68.5924 23883 14.0629 18654 15,9326 18654 17,3795 18654 18.4168 18654 1,00865 18654 First Reading 100 141.5 100 2721,5 2721.5 2721,5 2721,5 2721.5 Last Reading 12114 12114 12041 12048 12048 12048 12048 12048 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 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 o0 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 Mean Nsam DEPT FT 100 2779 1439.5 5359 ROP MWD010 FT/H 4.93 546.06 169.656 5276 GR MWD010 API 20.47 117.42 63.7506 5261 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 ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 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 ....... 01/08/23 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 RPX 2721 5 RPS 2721 5 RPM 2721 5 RPD 2721 5 FET 2721 5 GR 2730 5 ROP 2779 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: STOP DEPTH 6376 5 6376 5 6376 5 6376 5 6376 5 6368 0 6437 0 12-OCT-00 Insite 4.05.2 65.44 Memory 6437.0 69.1 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 ..... i ............ 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN .Undefined Max frames per record ............ '' Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 75.2 TOOL NUMBER PB01688HWGRM6 PB01688HWGRM6 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 i 68 RPS MWD020 OHMM 4 1 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 Mean 4579.25 248.934 65.6443 11.1415 11.605 12.3 12.7064 0.816222 First Reading For Entire File .......... 2721.5 Last Reading For Entire File ........... 6437 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 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 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 8264 0 RPX 6377.0 8264 0 FET 6377.0 8264 0 RPD 6377.0 8264 0 RPM 6377.0 8264 0 RPS 6377.0 8264 0 ROP 6437.5 8264 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): 8264.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 8264.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 67.0 MUD PH: 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: 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 5.000 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 20 6 24 7 28 8 65.0 Name Service Unit Min DEPT FT 6368.5 ROP MWD030 FT/H 5.07 GR MWD030 API 21,07 RPX MWD030 OHMM 2.25 RPS MWD030 OHMM 2.2 RPM MWD030 OHMM 2.13 RPD MWD030 OHMM 2.32 FET MWD030 HR 0.2 8264 487 96 111 19 73 64 79 74 84 71 86 84 16 54 First Last Mean Nsam Reading Reading 7316.25 3792 6368.5 8264 178.71 3654 6437.5 8264 64.4486 3792 6368.5 8264 12.9418 3775 6377 8264 13.1205 3775 6377 8264 13.8946 3775 6377 8264 14.099 3775 6377 8264 1.1663 3775 6377 8264 First Reading For Entire File .......... 6368.5 Last Reading For Entire File ........... 8264 File Trailer Service name ............. STSLIB.004 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name.,. Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8264.5 10035 0 GR 8264.5 10035 0 RPX 8264.5 10035 0 RPM 8264.5 10035 0 FET 8264.5 10035 0 RPS 8264,5 10035 0 ROP 8290.0 10035.0 $ LOG HEADER DATA DATE LOGGED: 28-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): 10035.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.6 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01697HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB01697HAGR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6,125 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 48,0 MUD PH: 8.5 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 70.0 MUD AT MAX CIRCULATING TERMPERATURE: ,155 82.4 MUD FILTRATE AT MT: .160 70.0 MUD CAKE AT MT: .200 70.0 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 MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HR Min 8264.5 10.32 44 46 0 26 0 51 0 11 0 67 0 44 Max 10035 553.41 117.22 1271.47 2000 2000 2000 3.35 Mean 9149.75 168.225 76.5553 17.2669 21.9557 23.9288 26.3473 0.972236 First Reading For Entire File ' 8264.5 Last Reading For Entire File ........... 10035 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record,.65535 File Type ................ LO Next File Name ........... STSLIB.006 Nsam 3542 3491 3542 3542 3542 3542 3542 3542 First Reading 8264.5 8290 8264.5 8264.5 8264.5 8264.5 8264.5 8264.5 Last Reading 10035 10035 10035 10035 10035 10035 10035 10035 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name,.. Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB,005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 10035.5 RPM 10035.5 RPS 10035.5 RPX 10035.5 GR 10035.5 ROP 10035,5 FET 10035,5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 12048 0 12048 0 12048 0 12048 0 12041 0 12114 0 12048 0 31-OCT-00 Insite 4.05.2 65.44 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): Memory 12115.0 76.6 95.0 TOOL NUMBER PB01697HAGR4 PB01697HAGR4 6.125 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 49.0 MUD PH: 8.1 MUD CHLORIDES (PPM): 25500 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .180 MUD AT MAX CIRCULATING TERMPERATURE: .149 MUD FILTRATE AT MT: ,160 MUD CAKE AT MT: .200 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 MWD070 FT/H 4 i 68 GR MWD070 API 4 1 68 RPX MWD070 OHMM 4 1 68 RPS MWD070 OHMM 4 1 68 RPM MWD070 OHMM 4 1 68 RPD MWD070 OHMM 4 1 68 FET MWD070 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 86.0 70.0 70.0 Name Service Unit Min Max DEPT FT 10035.5 12114 ROP MWD070 FT/H 7.76 1239.19 GR MWD070 API 46.82 113.34 RPX MWD070 OHMM 4.34 1421.41 RPS MWD070 OHMM 4.73 1422.11 RPM MWD070 OHMM 5.18 1650.35 RPD MWD070 OHMM 6.11 1453.87 First Mean Nsam Reading 11074,8 4158 10035.5 180.429 4158 10035.5 77.1744 4012 10035.5 17.6004 4026 10035.5 21.1288 4026 10035.5 24.1094 4026 10035.5 25.8581 4026 10035.5 Last Reading 12114 12114 12041 12048 12048 12048 12048 FET MWD070 HR 0.4 6.05 1.24232 4026 First Reading For Entire File .......... 10035.5 Last Reading For Entire File ........... 12114 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 10035.5 12048 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/08/23 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