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208-100
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cR OS - J t O Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Ma s: rayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: MEIMP Date: /s/ (A/i Project Proofing BY: Maria Date: 58/5 /s/ Ito P Scanning Preparation 4- x 30 = 1 cd + az = TOTAL PAGES 1 143 (Count does not include cover sheet) BY: gr Date: 51// s /s/ Production Scanning Stage 1 Page Count from Scanned File: 1 1+4 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: CV Date: 51/ 1/ ' /s/ imp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc O , O o O N O — n ' 0 in 40 zl N m 1 D > .co coO00 . • , C in 0 H • • E y ai ai O n 0 ,y a o) O Z 0 0 E E v v 0 -6 v v 5 -o •o -0 0 v •0 z m > o -1 0 -1 CO co E E 2 E w w F .'. E E 2 E .�. 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CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 153' Surface 153' 24' Driven 10-3/4" 45.5# L-80 BTC Surface 4973' Surface 3438' 13-1/2" 433 sx PF'L';768 sx Class'G' 7-5/8" 29.7# L-8o BTC. Surface 11,377' Surface 5412' 9-7/8" 166 sx Class'G' 6 x 7-5/8" 18.6# xPc 10,806' 13,513' 5239' 6071' 6-3/4" 74 sx Class'G' 24.Open to production or injection? Yes❑ No0 If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) N/A EZSV @ 10,100'MD/5017'TVD None 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10,104' 394 sx Class'G'(w/12 sx above EZSV) 10,040' Perf Squeeze w/158 sx Class'G' 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 -4 28. CORE DATA Conventional Core(s)Acquired? Yes El No❑ Sidewall Cores Acquired? Yes ❑ No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. I COMPLE loi None la:LI EP,IFIEt3 RADM5 Sim tp ''q_01' Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit iginal only lZ•/L/.�� �� `/�y�� 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? [_ Yes Ri No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 843' 842' and submit detailed test information per 20 AAC 25.071. Permafrost- Base 1678' 1663' Top Wes Sak 2343' 2280' Top Torok 10,036' 4996' Top HRZ 12,276' 5693' Top Kuparuk 13,101' 5953' Top Nuiqsut 13,827' 6157' None Formation at total depth: 13,866' 6166' 30. List of Attachments: Summary of Daily Drilling Operations,Well Schematic Diagram,Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343-2186 Printed Name: Ver Jo Title: Sr. Staff Drilling Engineer 12-/ Signature: 7( Phone: 343-2111 Date: 12/7/2009 ODSN-45i Permit To Drill#208-100 Prepared By:Kathy Campoamor,343-2183 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. 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. Item la: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: 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. Form 10-407 Revised 7/2009 ODSN-45i Nuiqsut Injector, P&A/Operation Shutdown Schematic Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor Ai ` 153'MDrkb/153'TVDrkb 2-7/8"6.5#L-80 IBT-M,2100'TVDrkb Diesel to-2100'TVDrkb Seawater from—2100'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3438'TVDrkb . 1EZSV 10100'MDrkb/5017'TVDrkb Estimated Top of Cement @ Cement above packer:2.5bbl/50' 10100'MD/5017'TVDrkb Cement below packer:79.5bbl/1277'to 7-5/8"shoe+ 100'w/30%excess bullhead below shoe Top of 6"liner, 10,806'MDrkb/5239'TVDrkb ITop of Inner String fish,10,825MDrkb Live Severing Charge w/2.0"OD 7-5/8",29.7#L-80 BTC-M,6.875"ID Debris Catcher,2.0"ID 11377'MDrkb/5412'TVDrkb 12413'MDrkb,Top of Expanded Section, / \i 6", 18.6#L-80 Expanded to / 6.767"OD,6.19"ID,6.131"Drift The highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section ' below the liner from 13513' and Connection unable to hold pressure,13,433 MDrkb \I to the top of the Nuiqsut ‘`'‘A•••."dte", Expansion Cone formation at 13812' and will (� <f__, collapse and effectively seal \1 k Expandable csg shoe 13,513'MDrkb/6071'TVDrkb above the Nuiqsut—qualifying as \--i ____.___ 20AAC25.112(a)(3) \ 1-r- 13866'MDrkb/6166'TVDrkb Hole Fill and Un-consolidated Cement Date: Revision By: Comments JDF n v2 PIONEER9/22/2008 1013 208Alex Vaughan . Proposed P&A/Operation ShutdownConditionCondition ODSN-45i Injector Nal RESOURCESAIASKA . well Schematic PIONEER iperations Summary Report NATURAL RESOURCES Well Name: ODSN-45i Contractor: NABORS DRILLING Rig Number: 19AC Job Category: DEVELOPMENT DRILL Spud Date: 8/4/2008 Rig Release Date: ----------- Depth Start Foot/Meters Last Mud Start Date End Date (ttKB) (ft) Dens(Ib/gal); Summary 8/2/2008 8/3/2008 44.0 0.00 8.80 RD lines.Move rig f/ODSN-4011ODSN-45i. RU lines in HUTZ and cuttings transfer lines from CCU to RSC. PU&spot head on ODSN-45i, install 16"riser and test starting head to 500 psi for 10 min.-OK. Install 4"annular valve and insure environmental seal on conductor inflated. Replace TDS service loop due to damage.Transfer spud mud to rig pit system. 8/3/2008 8/4/2008 44.0 0.00 8.80 Replace Top Drive Umbilical.Spot E-line for Gyro survey.PU 5"drill pipe and rack in derrick, move pipe in derrick to off drillers side. 8/4/2008 8/5/200844.0 312.00 8.90 PU 5"drill pipe and rack in off drillers side of derrick. Adjust Top Drive brakes,slip and cut drill line,PU and MU BHA, PJSM for spud,Clean out conductor to 153'. Drill 13-1/2"surface hole f/153'11356'. ,8/5/2008 8/6/2008 356.0 1,697.00, 9.30 Drill 13-1/2"Surface Hole per HES DD&Well Plan#14a, drilling&surveying f/630't/722'. i Continue drilling ahead 1/722't/2053'. I 8/6/2008 8/7/2008 2,053.0 1,419.00 9.40 Drill 13-1/2"open hole section per HES DD&Well Plan#14a.CBU Hi-Vis sweep.Continue drilling ahead f/2,053'113,472'MD. r '; �/ r e 3,472.0 1,513 i t V; 9.50 Drill 13-1/2"open hole'section per HES DD&Well Plan#14a,drilling&surveying 1/3,472 t/4,91 , (4985'TD for Surface Hole) Pump 60 BBL's Hi Vis sweep&CBU 3.5x,prior to wiper trip to bit 8/8/2008 8/9/2008 4,985.0 0.00 9.70 Wiper trip BHA#1 f/4,985't/180'(pump out f/1,477 t/180'). RIH w/ledge seen @ 1,500'&tight spot @ 2,241'.Continue to RIH f/2,241't/4,609',where slightly tight.Wash/Clean(/4,609' t/4,985'. RSC pumps down, repair RSC. Wash/Ream f/4,605't/4,985'&CBU until MUD in shape. 008 8/10!2 8 4,985.01,1912 0.00! 9.90 Finish POOH w/BHA#1,racking back as much in Derrick.PJSM&RU to&Run3!4 10 "Casing per program (Ledge n 1,500',tight @ 3,510'). Land casing per Vetco Gray Rep. @ 4,973 { Break circulation&stage up per schedule(PJSM held). ' '%7.4:-7,4g,',4' 8/10/2008 8/11/2008 4,985.0 0.00 9.70 Continue to stage up to 10-12BPM&condition mud(PJSM).Once completed,test Cement lines to 3500psi&Cement 10-3/4"Casing into place per program 324 bbls(433 sx) PF'L', 183 bbls 768 sx)Class'G'. Recieved 90 BBLs contaminated mud&90 BBLs good cement back to surface. :ump p ugs w/500psi over 3 mins-ok,w/CIP @ 07:21 hrs 08/10/08. RD Cement& casing running equipment&LD landing Jt&PU Johnny Wacker(flush Riser). LD tool&ND 16" Riser system, Install Vetco Gray M233 Well Head,test seal element to 5000psi-ok.NU 11"-5K rated BOP stack&Risers. Q e - v `. .s NCU'8OP ;LD BHA#1,Set wear rin PU 150 is 5' ;f -' ', ; 4904; g, j drillpipe from pipe shed.with with same if„awo 2 POOH,Stand back 5"dnlipipe in derrick. PU 5"drillpipe from pipe shed. RIH same 8/12/2008 8/13/2008 4,985.0 0.00 9.70 Finish PU total of 120 jts of 5"DP f/1,297'113,897'&circ DP volume.Slip&Cut drilling line per NAD procedures. POOH racking back 40 Stands of 5"drillpipe. Finish racking pipe&PU BHA #2&rack back.Set test plug& attempt to test BOPE,but AP high test failed due to test plug leak. Unable to retrieve test plug.Separate wellhead sections A&B of M233 Well head(find faulty VG Seal Ring). Dummy run test plug-ok. NU sections on Well Head.Unsuccessful dummy run with two different test plugs.Unable to set in wellhead profile.ND and seperate wellhead sections A&B for inspection. 8/13/2008' t3/114/2008 4,985.0 000 . 9.70 Installed VG test plug&'Ntl,Vetco Gray Well Head section A&B.Install 16"Riser&fl. stale;""'''' Test BOPE per AOGCC requirements(Chuck Sheve waived witness).Attempt to�test plug (failed).Break apart Weil head sections A&B&retrieve test plug.NU Well Head&fill BOP stack&perform casing test to 3500psi for.5hr(ok).PU&RIH w/BHA#2(9-7/8"Bit RTTS type). Break in Geo Pilot seals&get past Tam Port collar @ 1,020'w/o issue. RIH t/4,906'&displace to seawater-based LSND mud type system. ,� ate,a �.. � f{, Page 1/9 Report Printed: 12/8/2009 PIONEER )perations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date End Date (ttKB) (It)r Dens(lb/gal) Summary 8/14/2008 8/15/2008 4,985.0 1,420.00 8.90 Finish circulating fresh 8.8ppg LSND mud&condition same.Clean out suction screens on pumps. Finish drilling cement, F/C&shoe @ 4,973'.Clean out rathole 114,985'&drill 9-7/8 hole to 5,005'.CBU&pull back into casing. Rig to&perform LOT/FIT to 14.81 ppg EMW. RD test equipment.Drill 9-7/8" Intermediate Hole Section to f/5,005't16,562'. 18/15/2008 8/16/2008 6,405.0 1,579.00: 9.10 Drill 9-7/8"open hole section t/6,562'.Circulate and condition hole.Make wiper trip f/6,562' t/4,950'.Service rig.RIH to bottom at 6,562'.Drill 9-7/8'open hole section f/6,562't/7,985 Circulate and condition hole for wiper trip. 8/16/2008 8/17/2008 7,984.0 791.00 9.101 Circulate and condition hole for wiper trip. Perform 13.0 ppg MWE FIT.Make wiper trip f/7,985' t/6,500'.Service Rig. RIH to bottom at 7,985'.Drill 9-7/8"open hole section f/7,985'V8,775'. 8/17/2008 8/18/2008 8,775.0 795.00 9.20 Drill 9-7/8'open hole section f/8,775'119,570'. 8/18/2008 8/19/2008 9,570.0 612.00 9.20 Drill 9-7/8"open hole section 119,973'.Circulate and condition mud. Make wiper trip f/9,973' t/7,995'. Hole in good condition.Service rig.Drill 9-7/8"open hole section f/9,973'1110,182'. 8/1 z"r wr 3 1.0,182.0 1,468.00 9.20 Drilled 9-7/8"open hole section to 11,650'MD(5,496'TVD). 8/20/2008 8/21/2008 11,650.0 673.00 9.30 Drill 9-7/8"Hole to 12323',Begin circ.bottoms up,well packed off,work to free pipe jarring up to 360K(200K over string wt),jarring down to 40k(120K below string weight at 160K neutral). ,� 12,323.0 0.00. 9.10 Work stuck pipe,jar up with 200K over neutral and 110K below neutral,work up to 485K and got Az pipe movement f/11,299'up V10,408.Pipe became stuck with no movement up or down. Unable to re-establish circulation.Continue to work pipe while mobilizing Free point and fishing tools. 8/22/2008 8/23/2008 12,323.0 0.00 9.20 Work stuck pipe,attempt to run dummy run with wire line to determine stuck point,max depth 4768'due to thick mud.Made blind back off,Circ and condition mud. 8/23/2008 8/24/2008 12,323.0 0.00, 9.20 Circ&condition after blind back off,SLM POOH,MU screw in sub and TIH to 1140' 8/24/2008 8/25/2008 12,323.0 0.00 9.20 TIH to casing shoe,change out encoder,TIH,B/C,tag fish at 9449'.Circ&condition while waiting on HES wire line tools. '8/25/2008 8/26/2008 12,323.0 0.00 9.20`Change TDS dies,POOH,LD backed out joints,TIH,tag and MU to fish,transfer torque,back out high,re-engage fish,Transfer torque,back out at screw in sub.Circ&Condition,RU HES 7/32"wireline,GIH to 6700',pump tools down,MU to screw in sub. 8/26/2008 8/27/2008 12,323.0 0.00 9.20 LD String shot#2.RIH with string shot#3 to 4000',pump down,re-gained returns with no losses.Observe on trip tank, pump down to depth,tool string lodged in jar mandrel!.Work free and attempt to shoot 1 joint above jars,miss fire, POOH,primer cord pulled out of firing head. B/C and work up to 600 GPM with no losses,work pipe F/40-480K and move up hole approximately 70'. Packed off and stuck. MU string shot Run#4,GIH to 4000',pump down to 9968', log up to screw in sub at 9371'WLM,had 140 lb over pull with string shot at sub. Log down to space out and log up to put string shot at 9964.5',attempt to shoot connection,no loss in torque or vibration. POOH with wire line miss fire. RD wireline. 8/27/2008 8/28/2008 12,323.0 0.00 -2!..;4.20 Finish RD wire line,l Yke blind back off at 635'.POOH,Rt1'puf w ar buahing,PU 9" r;'6,5" DC,MU RTTS with storm valve.RIH to 350'and set RTTS @ 61'.POOH w/2 singles and SSCV stinger.Test RTTS to 1000 psi.Blow down lines,drain stack and ND BOP.Change out Multi bowl wellhead and test to 5000 psi.Install wellhead valves and RU riser.NU BOP,set test plug and Test BOP to 250 Low/3500 High.Witness waived by Jeff Jones of AOGCC.Pull test plug and RD test equipment.RIH and engage RTTS and release same and POOH.UO 3ea. 6-1/2'DC and rack back 6ea.DC.Install wear Bushing and prepare to PU Fishing assembly ' Page 2/9 Report Printed: 12/8/2009 PIONEER operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start DateEnd Date MKS) (ft) Dent"(ib/gal} Summary 8/28/2008 8/29/2008 12,323.0 0.00 9.20 MU screw in sub and RIH to top of 5"at 635',engage 5"and attempt to circulate,pressure climbed to 1000 psi and slowly bleeding off,got rate up to 2 BBI/min with 900psi and minimal returns,shut down.While rigging up wireline it was noted on the BOP chart that the 4500 high tests had not been achieved.Conduct Blind back off in order to rig up and test.Contact Chuck Sheave w/AOGCC for waiver on 3500 test until fishing operations are concluded.MU HES wireline,CCL and String shot. RIH to 3,500 line hit refusal. Pump line down to 9,964'.Log with CCL,Spot String shot and fire same. Back string out of box, PU,Circulate and condition mud. POOH f/9,955't/6,155'. ,323.0 0.00 9.20 POOH f/6,155'to,Surface.'LD 1 Stand of 5"with damaged threads.LD Screw in sub,9 Joints of 5"DP,and 10 Joints of HWDP.MU Fishing BHA and RIM 119,966'and engage fish.Jar on fish and slowly stage pumps up to 525 GPM w/Full returns.Continue to work on establishing rotation. 8/30/2008 8/31/2008 12,323.0 0.00 9.70 Continue Jarring down on pipe while holding torque.@ 01:30 Pipe became free, Full Circulation and Stage rotary to 130 RPM.Circulate and work pipe cautiously 1 complete B/U before attempting to rack a stand back.Continue Back Reaming(/10,272'V9,988'.POOH on Elevators f/9,988'119,296'PU Wt=250K S/O Wt=100K. Pump out f/9,296'V8,000'pumping @ 625 GPM.Hole packed off,Lost 30 BBL mud and High ECD's and lost Circulation. Re-establish Circulation and stage pumps up to 250 GPM and Pull f/8,000'V7,621'.Start Back Reaming f17,621'117,526'using 40 RPM and pumping @ 450 GPM.Gas rose to 3,838 units and losing mud over shakers,Stop Backreaming and Circulate and work pipe until gas dropped out. Resume Back reaming f/7,526'V7,246'working thru tight spots @ 7,508'and loss of returns at 7,410'. 18/31/2008 9/1/2008 12,323.0 0.00 9.40 Back Reaming f/7,246'V6,542'.Using 550 Gpm @ 2,075 psi,rotate @ 130 Rpm.Hole acting better.ECD 10.3 to 10.5,Gas 65 to 300 units and is associated with the cuttings load coming back over the shaker.Continue Backreaming f/6,542'V Shoe @ 4973'.Using 550 GPM w/2050 PSI, 140 RPM.Stop backreaming @ 5,089. Pull into shoe and CBU 2x.Conduct a FIT w/9.4 Mud weight, Pressure up to 610 PSI,shut down and obsenie',pressure and after 6 min.pressure stabilized @ 585 psi. Pumped 20 bbls and returned 19 BBIS pr a 11.45 down Hole EMW. Conduct Post Jarring inspection of Derrick,Slip and Cut Drill Line and POOH with Fish.POOH f/4,973'113,992'. 9/1/2008 9/2/2008 12,323.0 0.00 9.40,Back Ream f/3,992'V3,898'. Pump and POOH f/3,898'V3,760'. Pumping at 550 GPM w/1650 psi. Rotate slowly at 20 RPM.Attempt to pull on elevators f/3,760'V3,509'. Hole started swabbing again. Pump and Pull f/3,509'1/3,206'Pumping at 550 GPM w/1650 psi. Rotate slowly at 20 RPM.Attempt to pull on Elevators f/3,206'V3,112',Still Swabbing. Pump and Pull f/3,112'V2,750'. Pumping at 550 GPM w/1650 psi,rotate at 20 RPM.Attempt to pull on Elevators f/2,750'1/2,653',Still Swabbing. Pump and Pull f/2,653'1/600'. Pumping at 600 GPM w/1630 psi,Rotate at 10 RPM.Lay out Fishing BHA and Fish.Stabilizers and all related tools were clean, No Balled up pieces.MU Clean out assembly and RIH to 2,736'. 9/2/2008 9/3/2008 12,323.0 O.00j 9.40 RIH w/clean out assembly f/2,736'114,960'.CBU.Continue to Circulate until shakers clean. Troubleshoot Top Drive while staying at shoe and Circulate hole clean.RIH f/4,960'117,559'and CBU. Resume RIH f/7,559'118,995'changing out 7 damaged joints of 5"DP and replacing with new. 9/3/2008 9/4/2008 12,323.0 0.00 10.50 Stage in hole to 10,038',C&C,B/U,change out mud with new 10.5 PPG,TIH 1/11340',wash and ream f/11,340'1/12,217'. Performed BOPE function test per AOGCC, Nabors, PNR requirements. 94/2008 9/5/2008 12,323.0 0.00 11.50 Circ&condition mud at 12,217',Perform 2 Dynamic FIT test using 10.5 PPG Mud,observed 12.9 ECD and 12.77 ECD on test before losses seen. Raise MW to 11.5 PPG,Attempt to pull on elevators f/12,029'1111841',pulled into tight spot with 50K over,S/O,M/U TDS,wash and ream(/11,926'1/11,812'. � �3s � ��, .a `%�ld.� .,,L.�' Vis - ,,. �.�; Page 3/9 Report Printed: 12/8/2009 PIONEER Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date Er)d Data.,s.€: :,11003) (ft) Dens(lb/gal); Summary 9/5/2008 9/6/2008 12,323.0 0.00 11.50 Back ream to 10,700',CBU until ECD's lower and shaker clean,POOH V8465. Backream f/8465'117476', POOH f/7,476115,475', Backream f/5,485'115,405',pump out f15,405'115,231', back ream f/5,231'115,019, POOH f/5,019'114,923',CBU,POOH,LD BHA,Service TDS, RU to test BOPE. 9/6/2008 9/7/2008 12,323.0 0.00 11.50 Test BOPE per AOGCC requirements,(250psi Low/4500psi High),w/Lou Grimaldi present for State.Once completed,line up choke manifold&begin PU BHA#6, troubleshoot MWD.RIH to +/-334',filling pipe&test ing MWD as required.TIH 1/3,000',Down link to MWD,TIH V4;973', CBU.TIH 116,352'wash thru obstruction,TIH 1/7,578',CBU,Wash thru obstrucitiO t at 7588',TIH 118,531'. 9/7/2008 9/8/2008 12,323.0 284.00 11.50 Continued to RIH w/BHA#6 V10,049'&CBU.Continue to Wash/Ream f/10,049'1111,185'where CBU to reduce ECD's. RIH on elevators f/11,185'V11,944'w/o further porblems.Wash/Ream under gauged hole f/11,944'V12,214',&CBU,(begin 760 BBL dilution).Get parameters&start drilling,1/12,217'1112,607'. 9/8/2008 9/9/2008 12,607.0 261.00 11.50 Drill 9-7/8"Hole t/12,868',where experience tight hole while drilling,PU out same&unable to regain MWD detection(Tuffeous Interface).Able to rotate&circ.while CBU 3x,Rack back 1 std/.5hr while back reaming f/12,865'V11,646'.Pull on elevators w/o swabbing,(100-120K over) (/11,646'V10,025',where pump dry job.Continue to trioist on elevators 119,064'where had to screw into&pump/back ream out 8,984',but MWD � ed working.Continue to work ti @ 8,984-9,016'& MWD worked intermittently.Back, med V6,349'. 9/9/2008 9/10/2008 12,868.0 0.00 11.50 Continue to POOH(/6,349'1/5,300'. Back Ream tight section f/5,300'1/5,117'&then pump out 1/4,927'. Pump dry job.Continue to POOH to BHA#6 tools, (Rack/LD same). PU replacement MWD components&MU BHA#7. RIH 1/4,924'&CBU,Slip/Cut Drilling line&service TDS&rig. Continue to RIH w/problems f/4,924't/7,577'&stage up CBU,as close to 12.65ppg EMW ECD. Once BU achieved, RIH to+/-8,995'&Ream tight section V9,115'.Continue to RIH 1110,015', • where again,staged up circulation to 600gpm,while keeping ECD @ 12.37ppg EMW. 9/10/2008 9/11/2008° '12,868.0 386.00 11.50 Continued to RIH w/BHA#7,f/10,146'V12,544',where tight spot seen.Ream V12; "! 1112,868'.Drill ahead 9-7/8"Hole section f/12,868`1/13,100'w/o much issues Lost „ on i pump.Circulate&repair same.Resume drilling f/13,100'1113 292' P R$ :., 9/11/2008 9/12/2008 13,234.0 349.00 11.90 Repair Mud Pump#2. Drill 9-7/8"open hole section f/13,234'1/13,583 MWD Tool Failure. Circulate 3x's bottoms up. Rack back stand every 1/2 hour. RIH f/13,161'1113,583',hole in good condition.Circulate and weight up active mud system from 11.5 ppg to 12.0 ppg. 9/1,;4008 9/1 " r+ t" 42 Finished circulating12.Oppg MW around,while Backiait1 .' 4iandmg bac "f Continue to Back ream out of hole,w/over pull,pack WS;tighthole conditions 5";"; '4'V12,340'.Attempt to rack back stand @ 10,187',but unable to grip TF w/TDS grabber dies.RIH w/same stand V11,182'&C/O Grabber dies on TDS.POOH,backream V10,712'.POOH on £,••;;', elevators(/10,712'1/8,812'.Unable to work thru tight spot.POOH,backream f/8,818't/8,723'. 9/13/2008 9/14/2008 13,583.0 0.00 12.00 Continue to POOH w/BHA#7 f/8,723'1/4,929',having to back ream tight spots @ 6,260'& 5,452'. Pulled inside casing shoe @ 4,973'w/o pumping/rotating.CBU-Pump dry job,serviced rigTDS&performed BOPE function test as required by AOGCC. Flow check,(well bore static) &POOH w/BHA#7 to 659'w/o issues. Pull wear ring rack tools&pull Nuke sources. Download tools&LD MWD.PU&MU BHA#8&after initializing MWD RIH w/same. RIH to+1-4,783'& CBU.Continue to RIH V6,345'&see tight spot,screw into TDS&rotate slowly thru.Continue to RIH 117,740'.C&C mud.CBU. 9/14/2008''''' 9115/20118 13,583.0 283.00 12.00 Continue to RIH w/BHA#8,(17,740'V10,011'on elevators,(replaced 25 jts of 5"OR due to. . worn down Hard Banding).CBU.Continue to RIH w/BHA#8,f/10,011'1/12,569'on the elevators,and then used TDS w/40 rpm&100 gpm to continue RIH w/o much further problems 1113,518'.Wash/Ream 1113,583'.Rotary Drill 9-7/8"Open Hole Section f/13,583'V13,866'MD (6,165'TVD),'TD'. ' Page 4/9 Report Printed: 12/8/2009 PIONEER Jperations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last laid Start Date End Date ( (ftKB) (ft) w wd`tom(tblyei. Summary 9/15/2008 19/16/2008 13,866.01 0.00 12.00 C&C hole.CBU 3x's. Rack back one stand of drill pipe every1/2 hour.Backream out of hole at drilling rate f/13,866't/13,424'.Work tight hole and pack offs f/13,630 t13,476'. POOH with top drive f/13,424't/13,107'. Back ream as needed.Observed intermittent tight hole. POOH with top drive f/13,107'1/12,007'. Back ream as needed.Observed intermittent tight hole. POOH on elevators f/12,007'1/10,678'MD.C&C mud.CBU.Service Top Drive and Rig. RIH on elevators f/10,678'1/12,835'. 9/16/2008 9/17/2008 13,866.0 0.00 12.50 Continue wiper trip f/12,385 1/13,770',using 40 rpm's on TOS to aid getting down through Shales.Wash&Ream to bottom at 13,865.Work thru tight hole at 13,770'&13,820'.Displace mud system to 12.5 ppg. POOH with drill pipe to run casing f113,866'1/8,830'.Back ream V9 079'v8 830'.Service top drive&rig. Replace grabber dies. POOH f/8,830'1/6,415'on elevators.Work tight hole at 6,415.POOH on elevators f/6,415'1/5,903'.Occasionally back reaming V6,251'1/6,167'&f/5,982'1/5,903'. 9/17/2008 9/18/2008 13,866.0 0.00 12.50 Finish POOH w/BHA#8,f/5,903'1/4,955'.Once in side 10-3/4"casing,CBU,Serviced Rig& TDS&Slipped/Cut drilling line.A dry job was pumped&assembly POOH w/o further incidents. The HWDP were racked back and everything else LD.Set test plug&C/O Top Pipe rams to 7-5/8".Once completed,test same to 250psi low/4500psi high&chart same(Jeff Jones waived witness for State). RU floor to run 7-5/8"Casing&PJSM held.MU 7-5/8"shoe track accordingly &floats tested(held ok). Run Casing per program+/-1,000'&filled w/11.5ppg MW per program. RIH with 7-5/8"casing 1/2,854'. • 9/18/2008 9/19/2008 13,866.0 0.00 12.50 Float 7-5/8"casing f/2,854'1/8,047'. Fill casing with 90 bbls(2,000') 11.5 LSND mud.Push casing in hole f/5,306'1/7,880'.Rotate casing string into hole f/7,880'1/8,047'. 9/19/2008 9/20/2008 13,866.0 0.00 12.501 Rotate 7-5/8"casing string into hole f/8,047'1/10,000',w/various collars,torque rings&jt.#232 !C/O,due to galling of threads.. RU Halliburton Wireline and prepare to set bridge plug to allow ;top 4,000'of casing to be filled while running. 0/2008 9/21/2008 13,866.0 0.00 12.50 Ran Baker Bridge Plug on Halliburton Wireline and set at 204'below KC 3,(Set' }.Jt#239).RD wireline equipment.Ran 7-5/8"casing.Changed out collars as needed due to thread galling and Ktri4seal rings being displaced and able to reseat.After connection at 11,395'unable to move pipe 4.7114,16144.( 1 up or down.Work to free pipe with 585K over pull and squat to 25K.Worked torque into pipe up to 22K and worked f/25K t/225K with no movement. 9/21/2008 9/22/2008 13,866.0 0.00 11.50 RU to run 4"XT39 DP into 7-5/8"Casing to Retrieve Baker Bridge plug.RU Baker Fishing Slip bowl&get slips on barge. Finish making false floor table&MU Baker Retrieving assembly per Representative. RIH(7-5/8"casing), PU 51 joints of 4"DP.Latch onto Bridge plug C) 1,630'& allow Mud to balance out between annulus. Hoist&stand back 4"DP&recover fish(LD same). RU fill up line and fill 7-5/8"casing with 11.5ppg mud allowing air to swap out of interior at intervals to minimize blow back. RD short bails,change out saver sub, install long bails. MU TDS into drive sub&continued filling pipe with 11.5ppg mud until 1,000'of pipe left empty. 9/22/2008 9/23/2008 13,866.0 0.00 11.50 Finish RU casing elevators and slips,PU joint 7-5/8"casingwith drive sub,MU same to TDS, Fill pipe with 130 bbls 11.5ppg mud.Established good circulation with 11.5ppg mud in and 12.5 Mud out.Work string from 25K to 500K with no movement.Applied 22K torque to pipe and stalled TDS,worked pipe. Flow slowly fell off to zero with 13.2ppg mud returns from well. .Continue to work pipe from 25K-500K with 22K Torque,attempt to regain circulation with no —success.RU cement equipment and pump 45 bbls 15.8ppg cement and displace with rig pumps '" staged up to 6.5 BPM,bumped plug with 1500 psi over pump pressure and hold 5 min.Check floats-OK.RD cement equipment,ND BOP,Set emergency slips with 440K. h '9 9/23/2008 9/24/2008 13,866.0 0.00 12.50 Finish NU. RD casing equipment.RU 5"handling tools,LD drillpipe from derrick. Repair pipe • shed skate hydraulic motor. LD 5"drill pipe, repair draw works drill line tangle, LD 5"drill pipe. Page 5/9 Report Printed: 12/8/2009 PIONEER Jperations Summary Report NATURAL RESOURCES Depth Start Foot/Wtete% Lest Mud Start Date End pate `,' MKS) (ft) dens( gel) Summary 9/24/2008 9/25/2008 13,866.0 0.00 12.50 The rig transferred 17 std's of 4"DP onto the ODS,&continued to LD 5"DP single @ time from Mouse hole installed in rotary table.A 4,500psi.casing test performed(.5hr&charted). PU& MU singles of 4"DP,while RIH w/same.Sim-Op's:While performing the upgrade, Freeze protected the 7-5/8"x 10-3/4"Annulus w/85 BBL's of Diesel. PU&RIH,(1 x 1),the 4"XT39 once again,to 7373". 9/25/2008 9/26/2008 13,866.0 0.00' 12.50 Continue to PU&RIH w/4"XT39 DP t/11,012'.Est.circulation&stage up to 500gpnt,w/Fresh 12.5ggp MW.Circ. 1.5x DP volume&rotate DP @ 15Orpm's.Short circ.by+/L1,000'&POOH& rack back 114 std's.Test choke manifold 250/4500 psi while POOH.PU&Rli4 12 jts 4"XT39 HWDP&27 jts 4"XT39 DP.Circ.again @ 700gpm 1.5x DP volume.POOH 84'rack same,pull wear ring wNetco Gray Representative&set test plug.C/O pipe rams to 4"Type&pressure, •, test BOP stack per AOGCC regulations, (Mr.Lou Grimaldi waived 9 witness). • „ 9/26/2008 9/27/2008 13,866.0' 0.001 12.50iI Finish BOPE test,Set wear bushing,MU BHA with Rhino Reamer and MWD tools.TIH,Shallow test MWD tools,TIH on 4"drill pipe verify strap with SLM.Wash through several tight spots,tag Ifloat shoe at 11,289',drill out wiper plugs&float collars,wash t/11,320'with no hard cement. 9/27/2008 9/28/2008 13,866.0 0.00 N 12.50 Wash and ream shoe track to 11326',drill cement t/11374',drill out shoe V11377',wash acct ream f/11,377'V11,438',MAD pass f/11420 V10330'for CBL log.TIH V13,379,taggeded�` obstruction with 40K, B/C&stage pumps upto 270 m,ECD climbed to 15.08 pg partial A returnsslow pumps and G&C to condition mud and stage pumps upto 300 GPM while reciprocating pipe.Wash and ream f/13,379 V13,693',observe ECD to control losses,Ream down with 80 rpm and 300 gpm,Ream up with 140-150 gpm,then down with same to verify hole clear. li 9/28/2008 9/29/2008 13,866.0 0.001 12.501 Ream f/13,693't/13,866',working thru multiple tight spots and pack offs. Back ream f/13,866' t/13,142'working thru multiple tight spots and pack offs,having to stage pumps up to regain I returns,circulate and condtion to lower ECDs. 13,866.0 0. 12.50 Packed off and stalled with 22K torque at 13,142', 10,0%losses work to fre ; returns.Stage pumps up to 300 gpm,RPM-=-140. Wash and ream t/13,068',lost returns v dt,, to regain same.Back Ream f/13,068'V12,743',C&C,pull 2 stands V12,585'.Till bole't/13, ' �� &worked thru multiple tight spots and ledges,washed/reamed as needed.CBU,Dropactwat ball to open Rhino Reamer cutters. • 9/30/2008 10/1/2008 13,866.0 0.00 12.50 Back Ream f/13,866 t/12,729'with minimal losses and no hole trouble,attempt to pull pipe while pumping and lost 750 psi pressure at 12,729'. POOH V12,397',Test surface equipment to 2000 psi,no leaks.POOH and back ream as hole required to free pipe and pass obstructions f/12,397 V11,438'.Saw slight drag when Rhino Cutters pulled in shoe.May indicate internal seals blown causing pressure loss of 750 psi. 10/1/2008 10/2/2008 13,866.0 0.00 12.50 POOH f/11,438't/11,285'.Pump out of hole due to swabbing.Service Rig&Top Drive.Change out saver sub.Slip and cut drilling line.POOH,pump out of hole due to swabbing.Trip f/11,285' I V6,175'.Attempt several times to pull straight on elevators.No Go.Work on top drive due to electrical problem.CBU.POOH with 4"drill pipe on elevators.Hole taking proper fluid displacement.Trip f/6,175'V3,957'. 10/2/2008 10/3/2008 13,866.0 0.00 12.50 POOH f/3,957't/581'to BHA.Service BHA#9, LD 1-jt HWDP.Break out Rhino-Reamer,LD bat-sonic tool.Stand back BHA, LD over torqued1-IWDP.MU BHA#10, PU new Rhino-Reamer. Service top drive and rig,clear rig floor.MU Bit RR5&Ghost Reamer,service BHA#10.Wait on arrival of new TM collar from Halliburton Deadhorse shop.MU new TM collar with BHA#10. RIH with BHA#10, LD 2 over torqued flex collars, LD 2-jts of over torqued HWDP,Shallow test PWD tool. RIH t/11,377'filling drillpipe every 2,500'.Stop at 7-5/8"casing shoe.C&C mud. Page 6/9 Report Printed: 12/8/2009 PIONEER Operations Summary Report NATURAL RESOURCES Depth Start Foot/Metets Last Mud ; • Start Doti (ttKBj< (ft) Dens{lbtgai) ' • Summary • .,.a• 10/3/2008 10/4/2008 13,866.0 0.00 12.50 C&C mud at 7-5/8"casing shoe until 12.5 ppg mud all around.Take torque and drag readings prior to RIH. RIH f/11,377'at 7-5/8"casing shoe 1/11,514'.Nabors Rig Electrician and Canrig Service Hand trouble shoot top drive.Circulate,pull 2-stands of drillpipe back up into 7-5/8" casing at 11,321'.Monitor wellbore.Work on electrical problem with top drive.Change oil in drawworks.Weekly function of BOPE.Circulate mud at 200 gpm 2200 psi. New Canrig service loop delivered to OTP from NOC. 10/4/2008 10/5/2008 13,866.00.00 12.50 Trouble shooting TD electrical issue.Continue circulating at 200 gpm 2250 psi.General rig maintenance. Replace seal in drill pipe spinner on iron roughneck. Repair steam heater in pipe shed. • i�. LTi is 10/5/2008 10/6/2008 13,866.0 0.00 12.50 Finalize Top Drive Electrical Repairs.General rig maintenance.Grease choke and mud manifold. Plumb in water softener. POOH f/11,231'1/10,841'. PUW 155K,SOW 100K.General rig maintenance.Grease manual and HCR valves.Change out valves and seats in number#1 mud pump. RIH f/10,841'1/12,764'. Observed tight hole at 11,899', 12,760, 12,764. Wash and ream f/12,7641/13,389'.Observed tight spots at 12,860', 13,140', 13,195'.Wash and ream f/13,389'1/13,485'.Wash and ream f/13,485't/13,866',bottom.C&C mud,CBU 2x. Drop ball. Pump to Rhino Reamer,shear activation sleeve at 2800 psi. Bring pump rate up to 300 gpm. Back ream open hole section f/13,866't/13,830'with 7-1/2" Rhino Reamer. 10/6/2008 :10/7/2008 13,866.0 0.00 12.50 Pump out of hole f/13,830't/12,750'.Observed tight spot at 13,572,work thru same.Back ream '' open hole section with 7W'Rhino Reamer f/12,750't/12,670'at 75'to 80'fph.Observed tight spots at 12,735'and 12,700'.Work thru same.Circulate&condition gas cut mud 12,670'.Max gas units at 6,849 gas cut mud at 11.8 ppg.Circulate until gas units fall below 1,000.Back ream open hole section with 71/2"Rhino Reamer f/12,670'1111,850'at 75'to 80'fph.Observed intermittent tight spots.Work thru same. 10/7/2008 10/8/2008 13,866.0 0.00 12.50 Back ream open hole section with 71/2"Rhino Reamer f/11,850'1/11,560'at 75'to 80 fph. Observed tight spots and pack off's at 11,842', 11,700'&11,595'.Work thru same.C&C mud at 11,560'. Back ream open hole section with 71/2" Rhino Reamer f/11,560't/11,468'at 75'to 80 fph.Shut down pumps,pull up into 7-5/8"casing to close Rhino Reamer blades.Circulate and condition mud..Service top drive,crown,and rig. RIH on elevators(/11,321'1/12,469'.Work thru tight spots at 12,164', 12,313', 12,469'.Wash and ream open hole section f/12,469't/12,840'. POOH on elevators f/12,840'1/12,400'. RIH on elevators f/12,400'1/12,840'.Work thru tight spots at 12,745'and 12,771'.MU top drive RIH. Hole taking fluid, 150 bph static,300 bph with pumps on. RIH to bottom at 13,866'.Wash and ream thru tight spots.Work thru same. POOH on elevators f/13,866'1/11,314'inside 7-5/8"casing. Fluid loss rate at 150 bph.Circulate and condition mud. Monitor well. Fluid loss rate while pumping 300 bph, 150 bph with pumps off. RIH on elevators f/11,314'1/12,767'.Fluid loss rate at 150 bph while tripping. 10/8/2008 10/9/2008 ,.;,;.',f,103,866.0 0.00 12.50 RIH with drill pipe on elevators 1/12,767'1113,460'tight spot.MU top drive,Break circulation. t • Wash thru tight hole f/12,460'1/13,538'.Work same. RIH on elevators(/13,538'1/13,866'.Tag bottom,no fill. POOH with drill pipe on elevators f/13,866'1/11,350'.Monitor well for 15 min,` Static fluid loss rate at±50 bph.Mix and pump 60 bbl 12.5 ppg 60 ppb LCM pill.Spot pill in 'open hole section. Chase pill with 115 bbls of mud.Lost 93 bbls of mud to hole while displacing pill. Mix and pump dry job.Drop 2-3/8 drift thru drill pipe.POOH with drill pipe on elevators f/11,350't/427'.Break out and LD BHA#10.PU and MU Enventure BHA to run expandable liner.Rack back in derrick. PU Weatherford liner running equipment to rig floor.Held PJSM on running Enventure Expandable liner casing. RU Weatherford casing tools.Troubleshhot Weatherford Casing Tongs.RIH with 6"Enventure expandable casing liner. Run,1,572'casing. Weatherford casing tongs damaged jt#41. Fluid loss to formation last 24 hrs 350 bbls 143 bph avg loss rate. Note:Tom Maunder of AOGCC approved pipe,ram exemption for6"expandable casing. Page 7/9 Report Printed: 12/8/2009 PIONEER Jperations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Lest Mud, Start pate End Date., fftKB) (ft) !D/ J)'•',1' Summary', ,.: 10/9/2008 10/10/2008 13,866.0 0.00 12.50 RIH with 6"Enventure expandable liner f/1,572't/2,635'.RD Weatherford casing equipment. Clear rig floor. RU false bowl over casing in hole.RIH with Enventure BHA on 4"drill pipe t12,635'.MU Liner running assembly with debris catcher. RD false bowl.Clear rig floor. RIH with 6"Enventure Expandable liner f/2,625'V12,460'on 4"drill pipe.Drop ball at 10,882'. Pump ball in place and shear at 2300 psi.Convert to float assembly. RIH fill every 5 stands of drill pipe. 10/10/2008 "IOl 8 '`13,866.0 0.00 12.50 Work tight hole at 12,460'. RIH with 6"Enventure Expandable casing on 4"drill pipe f/12,460' 1/13,135',tight spot,work down thru tight spot.RIH 1/13,500'tight spot.Work down thru tight spot. RIH 1/13,862'.Tag bottom.Circulate one drill pipe volume.Hold PJSM on cementing job. z` Break out top drive from drill string.MU cement hose to drill string.Halliburton)pumps 5 bbls of water.Pressure test cement lines to 6000 psi-ok. Pump 5 bbls of water,mix of 13.Oppg0 bbls, spacer.Halliburton pumps 20 bbls spacer at 13.Oppg followed by 15 bbls(74 sx)of 15.8ppg • Class G cement.Break out cement line from drill string,drop dart,MU cement line back to drill string. Perform cement job,20 bbls 13.0ppg spacer+15 bbls 15.8ppg cement.CIP at 05:00 hrs.RD cement lines,pull and LD drill pipe pup joints from drill string.MU top drive,pressure up on drill string to 4200 psi. POOH with Enventure casing expander hold 4200 psi on drill string. Pull drill pipe f/13,862'V13,767'.Observed pressure drop from 4200 psi to 400 psi.Unable to maintain pressure on casing expanding tool.POOH with drill string while attempting to mechanical expand casing f/13,767'til 1,987'.Appears casing started moving up hole with drill string at 12,850'. RIH with drill string f/11,987'1/12,907.Tag Enventure casing expanding BHA to casing bottom.Attempt to push casing back to bottom,pipe movement stopped at 13,435'. MU top drive,Break circulation and attempt to move drill string downhole.No movement.POOH f/13,435'1/13,095 to PU storm packer for BOP test.Still pulling casing.RIH. RIH f/13,095 1/13,111'.Tag up solid down hole.Attempt to regain pipe movement,No go.Attempt to release from Enventure expanding tool.Work 14 turns of left hand torque into drill string.Back off shallow down hole. POOH until at back off joint. 10/11/2008 10/12/2008 13,866.0 0.00 12.50 RIH with 7-5/8'storm packer&set same @ 47',(test to 1,000psi-OK).Drain stack&remove wear ring-install Test plug.Fill stack w/H2O&initiate BOPE test,per AOGCC requirements, (Mr.Chuck Sheave waived witness for State).Once completed,blow down choke manifold,kill &HCR lines. Line up valves for RIH. Pull up out 7-5/8"storm packer w/op difficulties&recover same.LD 9 x 4-3/4"DC's. PU&RIH w/std's 4"XT-39 DP to 964'.Change out leaky Wash Pipe packing on TDS.RIH&screw into fish @ 13,486'.Able to push down to 13,522'before refusal. LD one joint of drill pipe. Depth at 13,513'. Prepare to RU Halliburton E-Line unit.Service top •drive&rig. Hold PJSM with Nabors&Halliburton on E-line Work. RU e-line thru top drive.Make dummy run with CCL to verify if operational. RIH with e-line to 1,000'no response from CCL. POOH with e-line to PU severing tool. 10/12/2008 10/13/20o8. 13,866.0 0.00 12.50 Continue to work on CCL of HES Wireline.PJSMfMUSever Charge for run.RIH w/HES Sever Charge to+/-3,700'where took weight.Begip own - ra e=400-6OOpsi(150 BPH loss rate).Pump tool 3,700'-10,810'(WL Depth)where pressure up to 4300psi�&able ,, move tool up/downward.Attempt to pull out Upper Debris catcher of Enventure w/o succeSal , Decision made to fire off Gun,as know depth&collar location(CCL not working).Unable to fire,' as igniter not showing proper voltage drop.Decision made to pull out of rope socket of HES Wt.:: , Pull 5,400#'s&came upwards,where saw another 4,500#pull section.Upon retrieval surface there was not running gear present&confirmed left down hole.LD lower WL sheave. Decision made to twist off at Upper-lower debris sub if able.Est.right hand torque set @ 30 rpm=11 K torque.Gradually work 75K down-200K up&increase from 11K-19.9K where able to est.constant 30-50rpm (indication seen when 0 130K Rot Wt came free w/160K PU Wt.Pull up V13,431'&attempt to pump on fish.Achieve 1200 psi w/48spm(leads us to believe have Upper Debris sub&unfired charge present w/fish). POOH w/4"Drillpipe f/10,824'1/9,816' where had to LD Bottom jt on std.TTop jt.of next std.due to where engagement at 1,086'(galled threads).Iron Roughneck hydraulic hoses damaged on stump while retracting from mousehole. Fix damaged Hydraulic hoses(2x's on Iron Roughneck).Service Rig&TDS also,while performing work.POOH w/4 Drill Pipe f/9,816't/surface.(No excessive drag seen when exiting liner).Twisted off drill pipe cross over sub from top of Enventure debris catcher.Service top drive&rig. Discuss options with Pioneer Sr Drilling Engineer.Decision made to run 7-5/8" cement retainer&proceed with suspending well operations. RD Halliburton E-line sheaves from derrick.Change out saver-sub on top drive.Prepare to run 7-5/8°cement retainer. i y Page 8/9 Report Printed: 12/8/2009 • PIONEER Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date End Date (ttK8 (ft) Dens(th/ga1) Summar' umma ' s 10/13/2008 10/14/2008 13,866.0 0.00 8.50 RIH and set Halliburton 7-5/8" EZSV cement retainer at 10,100'drill pipe measurement. • Establish injectivity rate below retainer. RU cement lines to drill pipe. Halliburton pumps 10 bbls of water,test cement lines to 4000 psi,mix and pump 82 bbls(394 sx)of 15.8 ppg Class G cement. Displace cement with 100 bbls 12.5 ppg mud to below cement retainer at 3.5 bpm 1280 a psi,CIP at 15:22 hrs. Pull stinger from cement retiner. Pump 2.5 bbls(12 sx)-82'of cement on top of retainer. RD cement lines, POOH with 4"drill pipe 1110,017'.CBU.Test 7-5/8"casing to 4500 psi. Displace well to 8.5 ppg inhibited seawater. POOH and LD 4"drill pipe. 10/14/2008 10/15/2008 13,866.0 -LD 4"drill pipe.Change out blower motor on drawworks Service rig and top drive:Slip and cut .drilling line. RIH with'13 stands of 4"drill pipe from derrick. POOH,LD 4"drill pipe.Pull wear ring. RU Nabors tubular handling equipment.RIH with 80 joints of 2-7/8"6.5 ppf L-80 BTC tubing 1/2,424'.Land tubing in Vetco/Grey Wellhead. RD Nabors tubular handling equipment. 10/15/2008 10/16/2008 13,866.0 0.00 8.50 Finish up w/BOP stack operation&ND same. NU Vetco Gray tree&Reversed circulated 86 1 BBLs of Diesel for Freeze protection to+/-2,000'TVD.Once completed&allowed to U-tube for 45 mins, RD lines&manifold. Blew down Sea Water/Potable/Cutting lines&disconnected lines in Hutz. Pull out Sea Water pump due to ice flow conditions. Prepare to&move over to b6) ODSK-41.Center over well Bore&Shim up rig. Rig Released f/ODSN-45i C� 23:59hrs, J- 10/15/08. 40/4/2009 10/5/2009 13,866.0 0.1 $55 Finish moving Nabors 19AC from ODSN4441 to ODSN-45a(Note:ODSN-45I t n tl milli window& is kick off)and RU on same.Reverse circulate out diesel freeze protect.Check well for flaw- static.Install TWC valve and ND tree.NU BOPE.Change out bottom pipe rams from 3.5"to 4". Test BOPE's.Annular to 250 psi low/2500 psi high.Blind Rams,Upper VBR's Lower 4"Rams,Kill and Choke HCR valves,Kill and Choke manual valves,Floor Safety and Dart valves,Upper&Lower IBOP valves to 250 psi low/3500 psi high. 14 Choke Manifold valves to 250 psi low/3500 psi high.All tests held 5 min each on chart.Accumulator test, System Pressure 3000 psi,After Closure 2100 psi, Initial 200 psi recovery 17 seconds,Full pressure recovery 1 min 32 seconds.No Failures.AOGCC rep Jeff Jones waived witness of BOP test at 20:15 hrs on 10/03/09.Change out top drive saver sub.RU 2-7/8"handling tools. Install landing joint and unseat tubing hanger.LD tubing hanger and landing joint. • • Page 9/9 Report Printed: 12/8/2009 PIONEER operations Summary Report NATURAL RESOURCES G) Well Name: OD 5A C— Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Spud Date: Rig Release Date: Depth Start F i lastMed,, ' Start Date End Date (ftKS) ' V.34;)0004401r, Summary 10/4/2009 10/5/2009 0.0 8.55 Move Nabors 19AC from ODSN-34i to ODSN-45A(Note:ODSN-45i until mill window&kickoff) and RU. Rig accepted on ODSN-45A @ 00:00 hrs, 10/04/09. Reverse circulate out diesel freeze protect.Check well for flow-static. Install TWC valve and ND tree.NU BOPE.Change out bottom pipe rams from 3.5"to 4".Test BOPE's.Annular to 250 psi low/2500 psi high.Blind Rams, Upper VBR's(2-7/8"X 5")Lower 4"Rams,Kill&Choke HCR valves,Kill&Choke manual valves, Floor Safety&Dart valves, Upper&Lower IBOP valves to 250 psi low/3500 psi high. 14 Choke Manifold valves to 250 psi low/3500 psi high.All tests held 5 min each on chart.Accumulator test,System Pressure 3000 psi,After Closure 2100 psi, Initial 200 psi recovery 17 seconds, Full pressure recovery 1 min 32 seconds. No Failures.AOGCC rep Jeff Jones waived witness of BOP test at 20:15 hrs on 10/3/09.Change out top drive saver sub. RU 2-7/8"handling tools. Install landing joint and unseat tubing hanger.LD tubing hanger and landing joint. 10/5/2009 10/6/2009 0.0 8.55 POOH&LD 2-7/8"workstring.PU clean out 6-3/4"BHA and TIH 113,104', 10/6/2009 10/7/2009 0.0 8.60 TIH f/3,104' 119,350'. LWD log f/9,350't/9,473'. Pump 20 bbl hi-vis sweep and circulate out same through gas buster.LWD log f/9,473't/10,104'.Tagged up on cement retainer at 10,104'. Pump 30 bbl hi-vis sweep and circulate out same. RU and test casing to 3500 psi held 30 min on chart-Good test. POOH f/10,104'to the BHA. Download LWD,remove nuclear sources,LD BHA. PU Fast Drill cement retainer with 4",2'shot interval,6 spf,60*phased Drill Guns and TIH t/2,616' 10/7/2009 10/8/2009 0.0 8.95 RIH with Drill Gun Assembly f/2,616' t/10,040".Set Fast Drill Packer and set down 20k to confirm. Pressure up annulus to 1000 psi and fire pert guns with 3400 psi DP pressure. Released from packer with 220k PUW.RU cement lines and test to 3200 psi.Perform injectivity test at.5-3 bpm with FCP of 2990 psi.Pump 20 bbls 8.6 ppg seawater ahead. Pump 33 bests (1.17 cu/sk)15.8 ppg Class'G'Cement, .2%CFR-3,.75%Halad-344, .3%SCR-100 and displaced with 13 bbls 8.6 ppg seawater.Sting into packer and squeeze cement away with 83 1 bblspg seawater at 2.5 bpm with n50 psi. Final injection rate at 2 bpm with 3000 psi,30 BBL's away Total).Unsting from Fas Drill and POOH t/9,990'.Circulate surface to surface, POOH t/9,853'.Pump 9.3 ppg Dry Job. POOH f/9,853' 115,319'.Secondary Crown Saver failed, removed from derrick.Primary Crown Saver still operational.;POOH f/5,319�4freiR N-4 AOGCC given 24 hr notice to witness 7-5/8"perforated casing cement squeeze.AOGCC representative Jeff Jones waived witness of cement squeeze on 10/7/09. 10/8/2009 10/9/2009 10,040.0 0.00 9.10 POOH with Fas Drill Running Tool and LD same. PU BHA#12,6-3/4"Smith XR+312 Bit- Watermelon Mill-Bit Sub-NM Float Sub-2x NM Flex DC's-Stab-NM Flex DC-Bumper Sub -3 x HWDP-Drilling Jar-21x HWDP 11871'. RIH f/871' t19,648'.Clean out cement stringers f/9,648' t/10,020'.Drill Cement f/10,020' 1110,040'.Drill Packer and Perf Gun tail assembly f/10,040' 1110,095'.Circulate 2ea 50 bbl high-vis sweeps surface to surface. POOH with BHA #12 f/10,095' 11871',installing Super Sliders on first 111 its out of hole. POOH laying down BHA f/871' t/42'. Notified AOGCC of early BOPE test to be performed on 10/9/09.Witness of test waived by AOGCC representative Chuck Scheve. 10/9/2009` 10/10/2009 10,040.0 0.00 8.90 POOH w/BHA#12.Tested Annular to 250 •si low/2500.si hi.h.Tested Upper VBR"s(2-7/8" x 5"),Lower 4"Rams(fixed bore),Blind Rams,Choke and Kill line 'CR valves,Manual Choke and Kill line valves,Floor safety,Dart,Upper IBOP and Lower IBOP valves to 250 psi low/3500 psi high.All low and high tests held 5 min each and charted.Kill line HCR failed.Accumulator - w - test,System Pressure 3000 psi,Pressure After Closer 2000 psi,Initial 200 psi attained; Full Pressure attained 1 min 36 secs. Replace Kill HCR valve and retested.PU BH ii Geo-Track Whipstock Assembly.RIH to 10,070'and set . st,Cck at 19 deg RHC. ++ i\ -4,:', psi.Sheared hanger with 235k over ull andpulled to 10 Rotated down z - and`6roke off bif jef nozzle'plugs.Established circulation with 250 gpm at 3800'ps . � L 57,9-t oDsN-415A Page 1/4 Report Printed: 12/8/2009 ,alliburton Company Survey Report _ Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 1 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN- 45i,True North Site: ` Oooguruk ODS Vertical(TVD)Reference: ODSN-45157.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.O0E,233.94Azi) Wellpath: ODSN-451 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska,Zone 4 Geo Datum: NAD27(Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSN-45i Slot Name: 50-703-20577-70 Well Position: +N/-S -144.91 ft Northing: 6031005.53 ft Latitude: 70 29 44.804 N +E/-W -98.46 ft Easting: 469821.86 ft Longitude: 150 14 48.349 W Position Uncertainty: 0.00 ft Wellpath: ODSN-45i Drilled From: Well Ref.Point 50-703-20577-00 Tie-on Depth: 43.62 ft Current Datum: ODSN-451 Height 57.12 ft Above System Datum: Mean Sea Level Magnetic Data: 7/28/2008 Declination: 22.43 deg Field Strength: 57630 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From(TVD) +N/-S +EI-W Direction ft ft ft deg 43.62 0.00 0.00 233.94 Survey Program for Definitive Wellpath Date: 11/3/2006 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 533.00 ODSN-45i Gyro(50.00-533.00) SRG-Gyro-SS Conventional SRG single shots 575.40 13833.63 ODSN-45i MWD(575.40-13833.63) MWD+Sag+CA+IIFR+MhilWD+Sag+CA+IIFR+MS Survey MD Incl Azim TVD Sys TVD N/S E/W MapN Maps T,, &,0 ft deg deg ft ft ft ft ft ft ,��� , 43.62 0.00 0.00 43.62 -13.50 0.00 0.00 6031005.53 469821.86 TIE LINE 50.00 0.30 141.13 50.00 -7.12 -0.01 0.01 6031005.52 469821.87 SRG-Gyro-SS 100.00 0.30 191.03 100.00 42.88 -0.24 0.07 6031005.29 469821.93 SRG-Gyro-SS 168.00 0.50 165.94 168.00 110.88 -0.71 0.11 6031004.82 469821.96 SRG-Gyro-SS 197.00 0.48 148.51 197.00 139.88 -0.93 0.20 6031004.60 469822.06 SRG-Gyro-SS 228.00 0.59 198.76 228.00 170.88 -1.19 0.22 6031004.34 469822.07 SRG-Gyro-SS 258.00 0.58 166.67 257.99 200.87 -1.49 0.20 6031004.04 469822.06 SRG-Gyro-SS 288.00 0.68 167.36 287.99 230.87 -1.81 0.28 6031003.72 469822.13 SRG-Gyro-SS 321.00 0.98 173.11 320.99 263.87 -2.28 0.35 6031003.25 469822.20 SRG-Gyro-SS 351.00 1.08 175.74 350.98 293.86 -2.82 0.40 6031002.71 469822.25 SRG-Gyro-SS 382.00 1.32 178.28 381.98 324.86 -3.47 0.44 6031002.06 469822.28 SRG-Gyro-SS 413.00 1.75 179.15 412.97 355.85 -4.30 0.45 6031001.23 469822.30 SRG-Gyro-SS 443.00 2.13 178.74 442.95 385.83 -5.31 0.47 6031000.22 469822.31 SRG-Gyro-SS 533.00 2.88 180.19 532.86 475.74 -9.24 0.50 6030996.28 469822.32 SRG-Gyro-SS 575.40 2.94 174.16 575.21 518.09 -11.39 0.61 6030994.14 469822.42 MWD+Sag+CA+IIFR+MS 670.40 3.91 162.96 670.04 612.92 -16.91 1.81 6030988.61 469823.60 MWD+Sag+CA+IIFR+MS 764.70 5.03 162.67 764.05 706.93 -23.93 3.98 6030981.58 469825.74 MWD+Sag+CA+IIFR+MS 859.30 5.77 161.44 858.23 801.11 -32.40 6.73 6030973.11 469828.46 MWD+Sag+CA+IIFR+MS 954.90 5.70 160.56 953.35 896.23 -41.43 9.84 6030964.06 469831.53 MWD+Sag+CA+IIFR+MS 1049.20 7.62 163.09 1047.01 989.89 -51.83 13.22 6030953.65 469834.86 MWD+Sag+CA+IIFR+MS 1143.50 8.56 164.80 1140.37 1083.25 -64.59 16.88 6030940.88 469838.47 MWD+Sag+CA+IIFR+MS 1238.70 9.80 165.71 1234.35 1177.23 -79.27 20.73 6030926.18 469842.27 MWD+Sag+CA+IIFR+MS 1334.70 11.30 167.74 1328.72 1271.60 -96.38 24.75 6030909.06 469846.21 MWD+Sag+CA+IIFR+MS 1428.60 13.21 170.21 1420.48 1363.36 -115.95 28.53 6030889.48 469849.91 MWD+Sag+CA+IIFR+MS 1523.55 12.76 171.01 1513.00 1455.88 -137.00 32.01 6030868.42 469853.31 MWD+Sag+CA+IIFR+MS 1618.50 13.98 172.54 1605.38 1548.26 -158.73 35.14 6030846.68 469856.35 MWD+Sag+CA+IIFR+MS 1712.90 14.83 172.59 1696.81 1639.69 -182.01 38.17 6030823.38 469859.29 MWD+Sag+CA+IIFR+MS 1808.20 16.36 172.06 1788.60 1731.48 -207.40 41.60 6030797.98 469862.62 MWD+Sag+CA+IIFR+MS 1902.60 18.07 178.03 1878.77 1821.65 -235.21 43.94 6030770.17 469864.84 MWD+Sag+CA+IIFR+MS _ialliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 2 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN-45i,True North Site: Oooguruk ODS Vertical(TVD)Reference: "ODSN-45i 57,1r /77, Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) Wellpath: ODSN-45i Survey Calculation Method: Minimum Curvature Db; Oracle Survey MI) Incl Azim TVD Sys TVD N/S E/W MapN MapE Tnor ft deg deg ft ft ft, ft ft ft `i 1999.40 21.10 181.35 1969.96 1912.84 -267.64 44.05 6030737.74 469864.82 MWD+Sag+CA+IIFR+MS 2093.80 24.37 188.46 2057.03 1999.91 -303.90 40.78 6030701.49 469861.40 MWD+Sag+CA+IIFR+MS 2187.50 25.30 191.15 2142.07 2084.95 -342.67 34.06 6030662.76 469854.53 MWD+Sag+CA+IIFR+MS 2282.30 28.06 195.13 2226.78 2169.66 -384.08 24.32 6030621.39 469844.62 MWD+Sag+CA+IIFR+MS 2326.00 29.70 195.74 2265.04 2207.92 -404.42 18.70 6030601.07 469838.92 MWD+Sag+CA+IIFR+MS 2377.20 32.48 198.82 2308.88 2251.76 -429.65 10.83 6030575.88 469830.94 MWD+Sag+CA+IIFR+MS 2424.00 34.60 199.84 2347.89 2290.77 -454.05 2.26 6030551.52 469822.28 MWD+Sag+CA+IIFR+MS 2472.50 36.16 200.43 2387.43 2330.31 -480.41 -7.41 6030525.20 469812.50 MWD+Sag+CA+IIFR+MS 2566.60 39.82 202.47 2461.59 2404.47 -534.29 -28.62 6030471.41 469791.07 MWD+Sag+CA+IIFR+MS 2659.40 43.52 202.62 2530.89 2473.77 -591.26 -52.27 6030414.55 469767.19 MWD+Sag+CA+IIFR+MS 2699.00 44.79 203.91 2559.30 2502.18 -616.60 -63.17 6030389.25 469756.19 MWD+Sag+CA+IIFR+MS 2752.30 48.34 205.85 2595.95 2538.83 -651.69 -79.47 6030354.23 469739.75 MWD+Sag+CA+IIFR+MS 2805.10 49.84 207.14 2630.52 2573.40 -687.40 -97.27 6030318.60 469721.81 MWD+Sag+CA+IIFR+MS 2849.00 51.64 207.46 2658.30 2601.18 -717.60 -112.86 6030288.46 469706.09 MWD+Sag+CA+IIFR+MS 2943.20 53.16 207.96 2715.78 2658.66 -783.67 -147.57 6030222.54 469671.12 MWD+Sag+CA+IIFR+MS 3040.20 55.15 209.57 2772.58 2715.46 -852.59 -185.42 6030153.79 469633.00 MWD+Sag+CA+IIFR+MS 3133.80 57.80 210.63 2824.27 2767.15 -920.08 -224.55 6030086.46 469593.60 MWD+Sag+CA+11FR+MS 3229.60 59.33 210.06 2874.23 2817.11 -990.62 -265.84 6030016.09 469552.02 MWD+Sag+CA+IIFR+MS 3323.40 61.07 209.65 2920.85 2863.73 -1061.21 -306.36 6029945.67 469511.22 MWD+Sag+CA+IIFR+MS 3417.40 64.24 210.67 2964.02 2906.90 -1133.39 -348.31 6029873.67 469468.98 MWD+Sag+CA+IIFR+MS , 3465.30 65.89 210.86 2984.22 2927.10 -1170.71 -370.53 6029836.45 469446.62 MWD+Sag+CA+IIFR+MS 3512.30 69.49 210.64 3002.05 2944.93 -1208.07 -392.76 6029799.18 469424.24 MWD+Sag+CA+IIFR+MS 3560.00 71.29 209.81 3018.06 2960.94 -1246.90 -415.37 6029760.45 469401.47 MWD+Sag+CA+IIFR+MS 3607.70 73.43 210.51 3032.52 2975.40 -1286.20 -438.21 6029721.25 469378.47 MWD+Sag+CA+IIFR+MS 3700.80 73.49 209.15 3059.02 3001.90 -1363.62 -482.61 6029644.02 469333.77 MWD+Sag+CA+IIFR+MS 3797.60 75.67 213.26 3084.77 3027.65 -1443.40 -530.95 6029564.44 469285.10 MWD+Sag+CA+IIFR+MS 3892.10 75.67 212.88 3108.16 3051.04 -1520.13 -580.91 6029487.92 469234.84 MWD+Sag+CA+IIFR+MS 3986.90 74.92 215.00 3132.23 3075.11 -1596.20 -632.10 6029412.07 469183.34 MWD+Sag+CA+IIFR+MS 4081.10 74.82 216.86 3156.81 3099.69 -1669.83 -685.46 6029338.67 469129.69 MWD+Sag+CA+IIFR+MS 4176.00 73.20 216.32 3182.96 3125.84 -1743.07 -739.84 6029265.65 469075.02 MWD+Sag+CA+IIFR+MS 4268.50 72.50 218.38 3210.23 3153.11 -1813.33 -793.46 6029195.61 469021.13 MWD+Sag+CA+IIFR+MS 4365.10 71.06 219.72 3240.44 3183.32 -1884.59 -851.26 6029124.60 468963.04 MWD+Sag+CA+IIFR+MS 4458.60 70.94 218.34 3270.88 3213.76 -1953.26 -906.93 6029056.16 468907.10 MWD+Sag+CA+IIFR+MS 4554.80 70.77 219.77 3302.43 3245.31 -2023.83 -964.18 6028985.83 468849.56 MWD+Sag+CA+IIFR+MS 4648.50 71.10 218.30 3333.04 3275.92 -2092.62 -1019.96 6028917.28 468793.52 MWD+Sag+CA+IIFR+MS 4744.60 71.00 217.70 3364.25 3307.13 -2164.24 -1075.91 6028845.89 468737.28 MWD+Sag+CA+IIFR+MS 4839.60 70.69 218.10 3395.42 3338.30 -2235.05 -1131.04 6028775.31 468681.87 MWD+Sag+CA+IIFR+MS 4931.40 71.44 218.07 3425.21 3368.09 -2303.40 -1184.60 6028707.19 468628.04 MWD+Sag+CA+IIFR+MS 5012.78 71.57 218.31 3451.02 3393.90 -2364.06 -1232.32 6028646.73 468580.08 MWD+Sag+CA+IIFR+MS 5105.28 70.97 217.33 3480.73 3423.61 -2433.26 -1286.03 6028577.76 468526.09 MWD+Sag+CA+IIFR+MS 5202.48 70.78 216.37 3512.57 3455.45 -2506.74 -1341.11 6028504.50 468470.72 MWD+Sag+CA+IIFR+MS 5292.27 71.43 216.16 3541.65 3484.53 -2575.24 -1391.36 6028436.22 468420.20 MWD+Sag+CA+IIFR+MS 5393.88 72.60 214.62 3573.02 3515.90 -2654.02 -1447.32 6028357.67 468363.92 MWD+Sag+CA+IIFR+MS 5489.92 72.80 213.99 3601.59 3544.47 -2729.77 -1499.00 6028282.14 468311.94 MWD+Sag+CA+1 IFR+MS 5577.53 72.79 214.00 3627.50 3570.38 -2799.15 -1545.79 6028212.95 468264.87 MWD+Sag+CA+IIFR+MS 5673.75 72.92 213.93 3655.86 3598.74 -2875.41 -1597.16 6028136.91 468213.20 MWD+Sag+CA+IIFR+MS 5773.17 72.72 211.84 3685.23 3628.11 -2955.17 -1648.73 6028057.37 468161.31 MWD+Sag+CA+IIFR+MS 5868.30 72.53 210.72 3713.64 3656.52 -3032.76 -1695.87 6027979.98 468113.86 MWD+Sag+CA+IIFR+MS 5962.55 72.20 211.00 3742.20 3685.08 -3109.86 -1741.94 6027903.07 468067.48 MWD+Sag+CA+IIFR+MS 6057.35 72.53 212.72 3770.92 3713.80 -3186.59 -1789.63 6027826.54 468019.49 MWD+Sag+CA+IIFR+MS 6151.54 72.92 211.27 3798.89 3741.77 -3262.87 -1837.28 6027750.47 467971.53 MWD+Sag+CA+IIFR+MS 6247.51 72.48 211.27 3827.43 3770.31 -3341.19 -1884.84 6027672.35 467923.66 MWD+Sag+CA+IIFR+MS _.alliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 3 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN-45i,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) Weilpath: ODSN-45i Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Ind Azim TVD Sys TVD N/S E/W MapN MapE Tool s, ft deg deg ft ft ft ft ft ft 6340.49 72.26 212.99 3855.59 3798.47 -3416.22 -1931.97 6027597.51 467876.23 MWD+Sag+CA+IIFR+MS 6434.79 72.46 211.57 3884.17 3827.05 -3492.20 -1979.96 6027521.74 467827.94 MWD+Sag+CA+IIFR+MS 6529.18 72.54 211.31 3912.55 3855.43 -3569.00 -2026.92 6027445.14 467780.67 MWD+Sag+CA+IIFR+MS 6623.99 72.35 212.08 3941.15 3884.03 -3645.92 -2074.41 6027368.43 467732.87 MWD+Sag+CA+IIFR+MS 6720.35 71.83 213.74 3970.78 3913.66 -3722.89 -2124.22 6027291.66 467682.75 MWD+Sag+CA+IIFR+MS 6814.40 71.76 214.87 4000.17 3943.05 -3796.69 -2174.57 6027218.07 467632.11 MWD+Sag+CA+IIFR+MS 6908.92 71.70 215.49 4029.80 3972.68 -3870.05 -2226.29 6027144.93 467580.10 MWD+Sag+CA+IIFR+MS 7004.57 71.68 215.84 4059.85 4002.73 -3943.83 -2279.23 6027071.38 467526.86 MWD+Sag+CA+IIFR+MS 7100.30 72.01 215.80 4089.68 4032.56 -4017.59 -2332.47 6026997.84 467473.33 MWD+Sag+CA+IIFR+MS 7193.35 72.53 215.54 4118.01 4060.89 -4089.59 -2384.15 6026926.06 467421.37 MWD+Sag+CA+IIFR+MS 7288.69 72.40 215.89 4146.74 4089.62 -4163.40 -2437.22 6026852.47 467368.00 MWD+Sag+CA+IIFR+MS 7382.89 72.80 215.45 4174.91 4117.79 -4236.43 -2489.63 6026779.67 467315.30 MWD+Sag+CA+IIFR+MS 7477.85 72.16 214.78 4203.49 4146.37 -4310.50 -2541.72 6026705.81 467262.91 MWD+Sag+CA+IIFR+MS 7572.92 71.77 214.65 4232.93 4175.81 -4384.80 -2593.20 6026631.72 467211.14 MWD+Sag+CA+IIFR+MS 7667.50 71.96 215.11 4262.37 4205.25 -4458.54 -2644.60 6026558.20 467159.44 MWD+Sag+CA+IIFR+MS 7758.40 72.02 214.91 4290.47 4233.35 -4529.34 -2694.20 6026487.61 467109.56 MWD+Sag+CA+IIFR+MS 7857.11 72.14 214.91 4320.84 4263.72 -4606.36 -2747.95 6026410.82 467055.51 MWD+Sag+CA+IIFR+MS 7951.54 72.13 214.87 4349.81 4292.69 -4680.08 -2799.36 6026337.31 467003.80 MWD+Sag+CA+IIFR+MS 8047.28 72.73 214.89 4378.71 4321.59 -4754.96 -2851.55 6026262.65 466951.31 MWD+Sag+CA+IIFR+MS 8142.04 72.86 213.92 4406.74 4349.62 -4829.64 -2902.70 6026188.19 466899.87 MWD+Sag+CA+IIFR+MS 8235.58 72.73 214.08 4434.41 4377.29 -4903.72 -2952.67 6026114.32 466849.60 MWD+Sag+CA+IIFR+MS 8330.92 72.86 213.75 4462.61 4405.49 -4979.30 -3003.48 6026038.95 466798.49 MWD+Sag+CA+IIFR+MS 8425.40 72.21 213.89 4490.97 4433.85 -5054.18 -3053.64 6025964.29 466748.03 MWD+Sag+CA+IIFR+MS 8520.59 71.03 214.65 4520.98 4463.86 -5128.83 -3104.51 6025889.86 466696.87 MWD+Sag+CA+IIFR+MS 8614.84 70.45 215.43 4552.07 4494.95 -5201.67 -3155.59 6025817.22 466645.49 MWD+Sag+CA+IIFR+MS 8707.25 70.97 215.11 4582.60 4525.48 -5272.89 -3205.95 6025746.22 466594.85 MWD+Sag+CA+IIFR+MS 8802.25 71.56 214.91 4613.11 4555.99 -5346.57 -3257.57 6025672.75 466542.94 MWD+Sag+CA+IIFR+MS 8897.29 71.76 215.01 4643.02 4585.90 -5420.51 -3309.26 6025599.04 466490.95 MWD+Sag+CA+IIFR+MS 8992.33 71.70 215.37 4672.81 4615.69 -5494.26 -3361.27 6025525.50 466438.65 MWD+Sag+CA+IIFR+MS 9087.72 72.40 214.07 4702.21 4645.09 -5568.85 -3412.95 6025451.13 466386.67 MWD+Sag+CA+IIFR+MS 9182.29 72.66 214.32 4730.60 4673.48 -5643.46 -3463.65 6025376.73 466335.67 MWD+Sag+CA+IIFR+MS 9276.97 72.27 212.54 4759.13 4702.01 -5718.80 -3513.39 6025301.60 466285.63 MWD+Sag+CA+IIFR+MS 9371.46 71.83 212.53 4788.25 4731.13 -5794.59 -3561.73 6025226.02 466236.99 MWD+Sag+CA+IIFR+MS 9466.41 71.88 213.38 4817.82 4760.70 -5870.30 -3610.81 6025150.52 466187.60 MWD+Sag+CA+IIFR+MS 9561.43 71.43 216.75 4847.73 4790.61 -5944.11 -3662.62 6025076.93 466135.51 MWD+Sag+CA+IIFR+MS 9656.16 70.96 220.58 4878.28 4821.16 -6014.11 -3718.63 6025007.16 466079.22 MWD+Sag+CA+IIFR+MS 9750.62 72.00 222.51 4908.29 4851.17 -6081.14 -3778.03 6024940.38 466019.55 MWD+Sag+CA+IIFR+MS 9845.50 72.39 225.50 4937.30 4880.18 -6146.11 -3840.78 6024875.67 465956.54 MWD+Sag+CA+IIFR+MS 9940.33 72.08 228.44 4966.24 4909.12 -6207.72 -3906.78 6024814.33 465890.30 MWD+Sag+CA+IIFR+MS 10035.42 70.98 231.76 4996.38 4939.26 -6265.57 -3975.96 6024756.77 465820.89 MWD+Sag+CA+IIFR+MS 10130.89 70.98 235.78 5027.50 4970.38 -6318.90 -4048.75 6024703.74 465747.90 MWD+Sag+CA+IIFR+MS 10225.27 70.91 238.53 5058.32 5001.20 -6367.28 -4123.68 6024655.67 465672.77 MWD+Sag+CA+IIFR+MS 10320.41 71.04 243.08 5089.35 5032.23 -6411.14 -4202.18 6024612.13 465594.11 MWD+Sag+CA+IIFR+MS 10415.41 71.75 246.21 5119.66 5062.54 -6449.69 -4283.53 6024573.92 465512.61 MWD+Sag+CA+IIFR+MS 10509.57 71.95 249.73 5149.00 5091.88 -6483.24 -4366.46 6024540.71 465429.55 MWD+Sag+CA+IIFR+MS 10605.50 72.46 253.32 5178.33 5121.21 -6512.17 -4453.07 6024512.13 465342.83 MWD+Sag+CA+IIFR+MS 10700.09 72.67 257.60 5206.68 5149.56 -6534.82 -4540.40 6024489.84 465255.42 MWD+Sag+CA+IIFR+MS 10794.90 72.27 260.44 5235.25 5178.13 -6552.04 -4629.14 6024472.98 465166.61 MWD+Sag+CA+IIFR+MS 10890.16 72.60 263.72 5264.00 5206.88 -6564.55 -4719.08 6024460.84 465076.64 MWD+Sag+CA+IIFR+MS 10984.46 72.46 267.15 5292.32 5235.20 -6571.71 -4808.73 6024454.04 464986.97 MWD+Sag+CA+IIFR+MS 11080.18 72.47 270.51 5321.16 5264.04 -6573.57 -4899.97 6024452.55 464895.73 MWD+Sag+CA+IIFR+MS 11173.49 72.67 274.68 5349.13 5292.01 -6569.54 -4988.88 6024456.94 464806.85 MWD+Sag+CA+IIFR+MS 11266.96 71.89 276.68 5377.58 5320.46 -6560.73 -5077.47 6024466.11 464718.30 MWD+Sag+CA+IIFR+MS _.alliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page:', 4 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN-451,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94A4) Wellpath ODSN-451 Survey Calculation Method: Minimum Curvature ;Din Oracle Survey MD Incl Azim TVD Sys TVDN/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 11356.00 71.72 279.39 5405.39 5348.27 -6548.91 -5161.22 6024478.27 464634.61 MWD+Sag+CA+IIFR+MS 11457.21 72.27 283.01 5436.68 5379.56 -6530.22 -5255.62 6024497.35 464540.29 MWD+Sag+CA+IIFR+MS 11552.12 72.21 286.60 5465.64 5408.52 -6507.13 -5342.99 6024520.79 464453.03 MWD+Sag+CA+IIFR+MS 11646.83 72.03 289.98 5494.72 5437.60 -6478.84 -5428.56 6024549.42 464367.58 MWD+Sag+CA+IIFR+MS 11742.09 72.21 292.85 5523.98 5466.86 -6445.75 -5512.95 6024582.85 464283.34 MWD+Sag+CA+IIFR+MS 11836.81 72.45 296.50 5552.74 5495.62 -6408.07 -5594.94 6024620.85 464201.51 MWD+Sag+CA+IIFR+MS 11930.91 72.29 300.23 5581.24 5524.12 -6365.48 -5673.84 6024663.77 464122.79 MWD+Sag+CA+IIFR+MS 12007.35 71.97 300.29 5604.70 5547.58 -6328.82 -5736.68 6024700.68 464060.11 MWD+Sag+CA+IIFR+MS 12101.64 70.85 300.90 5634.76 5577.64 -6283.33 -5813.61 6024746.47 463983.37 MWD+Sag+CA+IIFR+MS 12194.63 70.30 300.73 5665.69 5608.57 -6238.41 -5888.92 6024791.70 463908.25 MWD+Sag+CA+IIFR+MS 12289.23 70.71 303.97 5697.26 5640.14 -6190.70 -5964.24 6024839.71 463833.13 MWD+Sag+CA+IIFR+MS 12383.79 70.65 307.31 5728.56 5671.44 -6138.71 -6036.75 6024891.98 463760.84 MWD+Sag+CA+IIFR+MS 12479.00 70.96 309.49 5759.86 5702.74 -6082.86 -6107.21 6024948.11 463690.61 MWD+Sag+CA+IIFR+MS 12574.86 70.77 314.08 5791.30 5734.18 -6022.54 -6174.72 6025008.71 463623.35 MWD+Sag+CA+IIFR+MS 12669.13 71.83 317.98 5821.53 5764.41 -5958.28 -6236.69 6025073.21 463561.65 MWD+Sag+CA+IIFR+MS 12764.01 71.48 320.01 5851.40 5794.28 -5890.32 -6295.78 6025141.40 463502.84 MWD+Sag+CA+IIFR+MS 12864.80 72.46 323.82 5882.61 5825.49 -5814.90 -6354.88 6025217.05 463444.06 MWD+Sag+CA+IIFR+MS 12957.10 72.55 323.56 5910.35 5853.23 -5743.96 -6407.00 6025288.19 463392.23 MWD+Sag+CA+IIFR+MS 13052.14 72.99 324.36 5938.51 5881.39 -5670.56 -6460.41 6025361.80 463339.12 MWD+Sag+CA+IIFR+MS 13146.90 73.51 324.07 5965.81 5908.69 -5596.95 -6513.47 6025435.62 463286.37 MWD+Sag+CA+IIFR+MS 13242.77 73.77 324.33 5992.82 5935.70 -5522.34 -6567.28 6025510.44 463232.87 MWD+Sag+CA+1IFR+MS 13337.16 72.65 323.59 6020.08 5962.96 -5449.27 -6620.44 6025583.71 463180.01 MWD+Sag+CA+IIFR+MS 13432.69 73.56 321.31 6047.85 5990.73 -5376.81 -6676.15 6025656.39 463124.60 MWD+Sag+CA+IIFR+MS 13526.56 73.33 321.70 6074.60 6017.48 -5306.39 -6732.16 6025727.04 463068.88 MWD+Sag+CA+IIFR+MS 13580.48 73.55 321.45 6089.97 6032.85 -5265.90 -6764.28 6025767.65 463036.93 MWD+Sag+CA+IIFR+MS 13675.10 73.07 321.28 6117.14 6060.02 -5195.10 -6820.87 6025838.67 462980.64 MWD+Sag+CA+IIFR+MS 13770.61 75.01 320.96 6143.40 6086.28 -5123.62 -6878.50 6025910.38 462923.30 MWD+Sag+CA+IIFR+MS 13833.63 76.73 320.41 6158.78 6101.66 -5076.34 -6917.22 6025957.81 462884.77 MWD+Sag+CA+IIFR+MS 13866.00 76.73 320.41 6166.21 6109.09 -5052.07 -6937.30 6025982.17 462864.79 PROJECTED to TD PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: September 15, 2009 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Steve Davies 700 G Street, Suite 600 333 W. 7t'Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps • Report X Other— 1 CD, 4 Well Logs ❑ Agreement DETAIL QTY DESCRIPTION 1 CD ODSN-45i (API: 50-703-20577-00) 1 CD LWD Final Processed Data containing digital graphic logs (EMF, CGM, PDF, TIFF) and digital data (LAS, DLIS) 4 Well Logs 4 Well lops DGR, EWR-Phase 4, CTN, ALD (1:600, 1:240) MD logs, TVD logs We request that all data be treated as confidential information. Thank you. Received by: , Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax Pioneer Natural Resources ODSN-45i Well Abandonment and ODSN-45A Pre-Drill Plan Summary of Operations Present Well Condition: Diagram attached 1. ODSN-45i has 7-5/8" 29.7 ppf L-80 casing set across the Torok interval. 2. The primary cement job showed little lift during the job and it is assumed that cement is not covering the Torok Interval. It is assumed that the 7-5/8" casing shoe is isolated with cement. 3. It is assumed that due to the high stress in the shale above the Kuparuk, that in the time the well has been static, the shale has collapsed, isolating the Kuparuk formation. 4. It is assumed that due to the high stress in the shale above and below the Torok, that in the time the well has been static, the shale has collapsed, isolating the Torok sands from above and below. 5. An EZSV bridge plug was run in the 7-5/8" casing and set at-10100' MD. -80 bbls of 15.8 ppg cement was placed via injection through the plug and then -3 bbls of cement was left on top of the plug to abandon the inside of the 7-5/8" casing. 6. -2000' of 2-7/8"tubing was run in the well as a kill string. Riq Activity: Verify Abandonment plug from Sundry Number 308-366 and Prep the Wellbore for Sidetrack operations Note: MPD will not be utilized while drilling this well 1. MIRU Nabors 19AC over ODSN-45i. 2. RU circulation lines and circulate out the freeze protection diesel from the well with seawater. 3. Flow check the well. Set two way check. ND Tree. NU BOPE and test to 250 psi low/ 3500 psi (2500 psi Annular) high. Pull two way check. Note: A 7 day BOPE test is required during the workover phase of this well plan. 4. Pull the 2-7/8" kill string. 5. Test the casing to 3500 psi-chart and hold for 30 minutes 6. MU 6-3/4" bit and full gauge mill picking up 4" DP as necessary and RIH to the top of the cement(-10050' MD) above the EZSV. Cleanout cement as needed to provide enough room for the squeeze perforation guns. Notes: • Do not drill up the Abandonment EZSV at-10100'. Contact the ODE should reu u4 this be of concern. 11 F_/S-e • Notify the AOGCC North Slope inspector 24 hours prior to tagging up on the current cement plug, estimated to be at 10050' MD,for possible witnesss 7. POH standing back the 4" DP. 8. MU HES DrillGun (3-3/8" aluminum, drillable perforation guns -4' in length -6 spf-60 deg phase) and RIH on 4" DP from the derrick. Set the DrillGun packer(a Drillable EZSV) at the top of the Torok(-10042' MD). Fire the DrillGun perf guns hanging below the packer. 9. Unsting from the EZSV. Extend the DrillGun stinger and sting into the EZSV. 10. Perform injectivity test with seawater and then pump the cement squeeze, currently estimated at 15 bbls of total cement, through the EZSV. 11. Unsting from the EZSV and leave -50' of cement on top of the EZSV. Pull up above the cement plug and circulate the drill pipe and casing clean with seawater. 12. POH standing back the 4" DP. 13. MU 6-3/4" bit and full gauge mill picking up 4" DP, as necessary to TD the well, and RIH to the top of the cement(-9990' MD) above the DrillGun EZSV. Drill up the cement, EZSV and aluminum pert guns to a depth to allow for the setting of the Whipstock. Utilize seawater and viscous sweeps until finished drilling the EZSV and perf guns. Notes: • Do not drill up the Abandonment EZSV at-10100'. Contact the ODE should this be of concern. • Notify the AOGCC North Slope inspector 24 hours prior to tagging up on the cement plug for possible witness 14. Circulate the well clean with seawater and viscous sweeps. 15. POH standing back the 4" DP. 16. Pressure test the casing to a 12.5 ppg EMW at the perforation TVD for 10 minutes to test the squeeze perfs-note results of the pressure test on the morning report. Note: With seawater in the hole,this is -1014 psi at the surface 17. MU 6-3/4" Smith GeoTrack one trip whipstock and window milling/drilling system with a 1.5 deg motor and Dir/GR. 18. Set the Whipstock RHS so that the top of the window is below the top of the Torok at -10042' MD according to the Smith Rep on location. 19. Displace the well over to -9.3 ppg milling/drilling fluid. Please continue to the Permit to Drill request for ODSN-45A for the sidetrack summary of operations C p I1-1 /1\k `� Y r � `' SEAN PARNELL, GOVERNOR ITO ALASKA OIL AND GABS 1 333 W 7th AVENUE,SUITE 100 CONSERVATION CO1'II►IISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Mr. Vance Hazzard Drilling Manager Pioneer Natural Resources Alaska Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk, Nuiqsut Oil Pool, ODSN-45i Sundry Number: 309-274 Dear Mr. Hazzard: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cath P. Forester Commissioner DATED this /v d y of August, 2009 Encl. REc , , . E: ) 440 STATE OF ALASKA -!f 41111.J‘ lU "4 ALASKA oIL AND GAS CONSERVATION COMMISbIUN AUG 0 6 - ° APPLICATION FOR SUNDRY APPROVALS i tiR Oil & Gas Cons. . 20 AAC 25.280 rAi1.Type of Request: Abandon n Suspend ❑ Operational shutdown ❑ Perforate 1:1 Waiver i_j age Other❑ Alter casing❑ Repair well D Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program❑ Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development- Exploratory ❑ 208-100 3.Address: Stratigraphic ❑ Service d 6.API Number: 700 G Street, Suite 600 Anchorage,AK 995011 1.-ei 50-703-20577-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name an Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E ODSN-45i 9. Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 355037/ADL 355036 56.2' Ooogurk-Nuiqsut Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13,866' 6166' 10,100' 5017' N/A 10,806' ; 10,825' Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 4934' 10-3/4" 4973' 3438' 5210 2470 Intermediate 11,337' 7-5/8" 11,377' 5447' 6890 4790 Expandable Liner 2638' 6"x 7-5/8" 13,513' 6106' 6150 2750 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8",6.5# L-80 BTC 2424' Packers and SSSV Type: Packers and SSSV MD(ft): 7-5/8" EZSV 10100' 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development 2 Service ❑ 15. Estimated Date for 16.Well Status after proposed work: Commencing Operations: 9/8/2009 Oil ❑ Gas ❑ Plugged Q Abandoned 2 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name Vance Hazzard Title Drilling Manager Signature '' Mt1i6 1 (k �f Phone 343-2116 Date 8/5/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .J6/"c2 Plug Integrity RV BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: .3 5 QO p Sc, a o'� / L 2 Sao IJ s,.... Ah...•,.A-t 4-re 5 1' Subsequent Form Required: MI— 4/0 ZRVED BYApproved by: / 2Z4')/11. t COMMISSIONER COMMISSION Date:8-l .©� Form 10-403 evised 06/2006 R I G I N A L `yy ��}} Submit in Duplicate R Jlos IBI' - ) : 1 241)7-0 RECEIVE. PIONEER AUG 06200 3 aska Oji & Gas Cons.Corr NATURAL RESOURCES Anchorage Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage,Alaska 99501 Tel: (907)277-2700 Fax: (907) 343-2190 August 5, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry Notice to abandon ODSN-45i, (PTD 208-100), (Sundry Number 308-366) Surface Location: 2889' FSL, 1176' FEL, Sec. 11, T13N, R7E, UM X = 469821.86, Y = 6031005.53, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to abandon ODSN-45i. Due to `junk' left in the hole and in accordance to Sundry Number 308-366, the well was placed in an operational shutdown condition by setting an EZSV, injecting -80 bbls of cement through the EZSV and leaving -3 bbls of cement on top of the EZSV. A schematic is attached In a separate Permit To Drill Request, PNRA is proposing to use the 7-5/8" casing just above the abandonment plug to drill a sidetrack into the Torok formation as an in-field exploration well. It is planned to perforate and squeeze cement to anchor the casing at the window depth, and provide additional isolation prior to the sidetrack. Information on the abandonment and the pre- sidetrack work scope is attached. Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) Documentation on the current well conditions 3) Current condition wellbore schematic 4) Summary of planned abandonment and pre-drill operations 5) A proposed abandonment and pre-drill wellbore schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson@pxd.com 2) Geologic Data and Logs Tim Reed, Senior Operations Geologist (20 AAC 25.071) 907.343.2144 tim.reed@pxd.com Alaska Oil & Gas Conservation Commission August 5, 2009 ODSN-45i Page 2of2 The anticipated start date for this well is September 8, 2008. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincerely, f . 4 =, 1 4 ance Hazz.r• Drilling Manager Attachments: Form 10-403 Supporting information cc: ODSN-45i Well File ODSN-45A Well File Pioneer Natural Resources ODSN-45i Well Abandonment and ODSN-45A Pre-Drill Plan Summary of Operations Present Well Condition: Diagram attached 1. ODSN-45i has 7-5/8" 29.7 ppf L-80 casing set across the Torok interval. 2. The primary cement job showed little lift during the job and it is assumed that cement is not covering the Torok Interval. It is assumed that the 7-5/8" casing shoe is isolated with cement. 3. It is assumed that due to the high stress in the shale above the Kuparuk, that in the time the well has been static, the shale has collapsed, isolating the Kuparuk formation. 4. It is assumed that due to the high stress in the shale above and below the Torok, that in the time the well has been static, the shale has collapsed, isolating the Torok sands from above and below. 5. An EZSV bridge plug was run in the 7-5/8" casing and set at -10100' MD. -80 bbls of 15.8 ppg cement was placed via injection through the plug and then -3 bbls of cement was left on top of the plug to abandon the inside of the 7-5/8" casing. 6. -2000' of 2-7/8"tubing was run in the well as a kill string. Rig Activity: Verify Abandonment plug from Sundry Number 308-366 and Prep the Wellbore for Sidetrack operations Note: MPD will not be utilized while drilling this well SUPERCEDED 1. MIRU Nabors 19AC over ODSN-45i. l-�S o ti 2. RU circulation lines and circulate out the freeze protection diesel from the well with seawater. 3. Flow check the well. Set two way check. ND Tree. NU BOPE and test to 250 psi low/ ✓3500 psi (2500 psi Annular) high. Pull two way check. Note: A 7 day BOPE test is required during the workover phase of this well plan. 4. Pull the 2-7/8" kill string. 5. Test the casing to 3500 psi-chart and hold for 30 minutes 6. MU 6-3/4" bit and full gauge mill picking up 4" DP as necessary and RIH to the top of the cement (-10050' MD) above the EZSV. Cleanout cement as needed to provide enough room for the squeeze perforation guns. Note: Do not drill up the Abandonment EZSV at -10100'. Contact the ODE should this be of concern. 7. POH standing back the 4" DP. 8. MU HES DrillGun (3-3/8"aluminum, drillable perforation guns -4' in length-6 spf-60 deg phase) and RIH on 4" DP from the derrick. Set the DrillGun packer(a Drillable EZSV) at the top of the Torok (-10042' MD). Fire the DrillGun pert guns hanging below the packer. 9. Unsting from the EZSV. Extend the DrillGun stinger and sting into the EZSV. 10. Perform injectivity test with seawater and then pump the cement squeeze through the EZSV. 11. Unsting from the EZSV and leave -50' of cement on top of the EZSV. Pull up above the cement plug and circulate the drill pipe and casing clean with seawater. 12. POH standing back the 4" DP. 13. MU 6-3/4" bit and full gauge mill picking up 4" DP, as necessary to TD the well, and RIH to the top of the cement (-9990' MD) above the DrillGun EZSV. Drill up the cement, EZSV and aluminum perf guns to a depth to allow for the setting of the Whipstock. Utilize seawater and viscous sweeps until finished drilling the EZSV and perf guns. Note: Do not drill up the Abandonment EZSV at -10100'. Contact the ODE should this be of concern. 14. Circulate the well clean with seawater and viscous sweeps. 15. POH standing back the 4" DP. 16. MU 6-3/4" Smith GeoTrack one trip whipstock and window milling/drilling system with a 1.5 deg motor and Dir/GR. 17. Set the Whipstock RHS so that the top of the window is below the top of the Torok at -10042' MD according to the Smith Rep on location. 18. Displace the well over to -9.3 ppg milling/drilling fluid. ( . PTD ..?Off-o7 I1 . <5.-+ c4.z: l. .4. g sat?) p .c L • Y.-7.° i Pr. ccsQrt.ti Please continue to the Permit to Drill request for ODSN-45A for the sidetrack summary of operations SUPERCEDED q-6---01 - ODSN-45i Nuiqsut Injector, P&A/Operation Shutdown Schematic Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor A L 153'MDrkb/153'TVDrkb 2-7/8"6.5#L-80 IBT-M,2100'TVDrkb ' ► r Diesel to—2100'TVDrkb Seawater from—2100'TVDrkb IF 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3438'TVDrkb EZSV 10100'MDrkb/5017TVDrkb Top of @ Cement above packer:2.5bbI/50' Estimated M / of Cement7'TVDrkb Cement below packer:79.5bbl/1277'to 7-5/8"shoe+ 10100100'w/30%excess bullhead below shoe Top of 6"liner,10,806'MDrkb/5239'TVDrkb Top of Inner String fish,10,825MDrkb II Live Severing Charge w/2.0"OD 7-5/8",29.7#L-80 BTC-M,6.875"ID 11377'MDrkb/5412'TVDrkb ` Debris Catcher,2.0"ID 1 12413'MDrkb,Top of Expanded Section, / 6",18.6#L-80 Expanded to 6.767"OD,6.19"ID,6.131"Drift The highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section 1 below the liner from 13513' and I Connection unable to hold pressure,13,433 MDrkb to the top of the Nuiqsut a✓ y Expansion Cone formation at 13812' and will collapse and effectively seal 4 Expandable csg shoe 13,513'MDrkb/6071'TVDrkb above the Nuiqsut—qualifying as `�r2 20AAC25.112(a)(3) L'-')11\r..—ii- . ( 13866'MDrkb/6166'TVDrkb Hole Fill and Un-consolidated Cement Date: Revision By: Comments PlO 1 CE E C �I 9/22/2008 JDF Proposed Completion v2 10/13/2008 Alex Vaughan P&A/Operation Shutdown Condition ODSNATUHALRESOURCES AIASKA Well Schematic S he-45i mor atic • Proposed ODSN-45A Torok Exp. Well Pre-Sidetrack Schematic Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor ` 153'MDrkb/153'TVDrkb KW Drilling/milling fluid from surface to PBTD Diesel to—2100'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3438'TVDrkb 1 X` —4'of 3-3/8"charges @ 60 degree phasing and 6spf—squeezed EZSV 10100'MDrkb/5017'TVDrkb Cement above packer:2.5bbI/50' Cement below packer:79.5bbI Top of 6"liner,10,806'MDrkb/5239'TVDrkb 7-5/8",29.7#L-80 BTC-M,6.875"ID i Top of Inner String fish,10,825MDrkb Live Severing Charge w/2.0"OD 11377'MDrkb/5412'TVDrkb Debris Catcher,2.0"ID The highly stressed and unstable 12413'MDrkb,Top of Expanded Section, HRZ, Kalubik and Miluveach6",18.6#L-80 Expanded to 6.767"OD,6.19"ID,6.131"Drift shales in the openhole section below the liner from 13513' and to the top of the Nuiqsut formation at 13812' and will collapse and effectively seal 1 Connection unable to hold pressure,13,433 MDrkb above the Nuiqsut—qualifying 00 q q fY g as Expansion Cone 20AAC25.112(a)(3) Expandable csg shoe 13,513'MDrkb/6071'TVDrkb r 13866'MDrkb/6166'TVDrkb Hole Fill and Un-consolidated Cement PIONEER Date: Revision By: Comments 7/27/2009 JDF Proposed Pre-sidetrack Condition ODSN-45A Torok JATURAL RESOURCES ALASKA Exploration Well Schematic— pre- sidetrack DSN-45i Nuiqsut Injector, Proposed P&A Schematic 20$-lpb Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor I AI { 153'MDrkb/153'TVDrkb 2-7/8"6.5#L-80 IBT-M,2100'TVDrkb Diesel to—2100'TVDrkb I I Seawater from—2100'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3442'TVDrkb EZSV 10100'MDrkb Estimated Top of Cement @ 10100' =.41 _ Cement above packer:2.5bbl/50' MD/—5241'TVDrkb Cement below packer:79.5bbl/1277'to 7-5/8" shoe+100'w/30%excess bullhead below shoe Top of 6"liner,10,806"'MDrkb 1 Top of Inner String fish,10,825MDrkb Live Severing Charge w/2.0"OD ill 7-5/8",29.7#L-80 BTC-M,6.875"ID LII .IF4 Debris Catcher,2.0"ID 11377'MDrkb/5412'TVDrkb 12413'MDrkb,Top of Expanded Section, / 6",18.6#L-80 Expanded to 1 6.767"OD,6.19"ID,6.131"Drift The highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section \ o �\ A Connection unable to hold pressure,13,433 MDrkb below the liner from 13513' and 1 to the top of the Nuiqsut � Expansion Cone formation at 13812' and will C� ( 1 collapse and effectively seal \� \ Expandable csg shoe 13,513'MDrkb above the Nuiqsut—qualifying as ���j 20AAC25.112(a)(3) \A l 13866'MDrkb/6204'MDrkb Hole Fill and Un-consolidated Cement Date: Revision By: Comments ( 1j" ) 9/22/2008 JDF Proposed Completion v2 10/13/2008 Alex Vaughan P&A Condition \ 441 ODSN-45i Injector Well Schematic PIONEER RECEIVED STATE OF ALASKA ALASF\m OIL AND GAS CONSERVATION COMMI,..,ION JUL 2 7 2009 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil &Gas Cons. Commission 1.Operations Abandon U Repair Well U Plug Perforations U Stimulate Li Other LiAnLIiOiage Performed: Alter Casing ❑ jt(Pull Tubing❑ Perforate New Pool ❑ Waiver Time Extension❑ r3t1 Change Approved Program [�' OpehutdownQ • Perforate ❑ Re-enter Suspended Well 2.Operator 4.Well Class Before Work: A 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development a/�ly�t�7✓ Exploratory 208-100 • 3.Address: 700 G Street,Suite 600 Stratigraphic❑ " Service 6.API Number: Anchorage,AK 99501 f '' 50-703-20577-00 • 7.KB Elevation(ft): 9.Well Name and Number: 56.2' ODSN-45i • 8.Property Designation: 10.Field/Pool(s): ADL 355036/ADL 355037 Oooguruk Nuiqsut Oil Pool . 11.Present Well Condition Summary: Total Depth measured 13866 • feet Plugs(measured) N/A true vertical 6166 . feet Junk(measured) 10825' Effective Depth measured 10100 feet true vertical 5017 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 4934' 10-3/4" 4973' 3438' 5210 2470 Intermediate 7-5/8" 11377' 5412' 6890 4790 Production Liner 2638' 6 x 7-5/8" 10806'-13513' 5239'-6071' N/A N/A Perforation depth: Measured depth: N/A True Vertical depth: Tubing:(size,grade,and measured depth) 2-7/8", 6.5# L-80 2424' Packers and SSSV(type and measured depth) 7-5/8"EZSV 10100' 12.Stimulation or cement squeeze summary: 1/43e_s 3r%_ S �o� 3��•-a cS,, >t y ��� o -6) Intervals treated(measured): 1.4 Treatment descriptions including volumes used and final pressure: ��0\� 4(C_Wc3075-313(3:obs � 30 L`' p0.A` o 13. Representative Daily Average Production or Injection Data N V-3 k Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: ff�� ' Copies of Logs and Surveys Run X Exploratory Development-g.Y�.?r. Service [� Daily Report of Well Operations X 16.Well Status per work: f � „e, Oil Vh A•?P'Gas ❑ WAG EI GINJ INJ _ h1 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.Exe • Contact James Franks,343-2179 Prepard By:Kathy Campoamor,343-2183 Printed Name Vance Hazzard Title Drilling Superintendent ' JJ , 1 I -� Signature j ki—ili� ,f))/(,,.t)i)_ct"t j ,l`/ �%61tI)f,-� If '. ' Phone 343-2116 Date 12/15/2008 Form 10-404 Revised 04/2006 1 Submit Original q fy ROOMS WI_ � 3 i 7009 k l'31 � % 7 X50 -73e.ek i P 1 O N E E R Operations Summary Report NATURA,_ RESOURCES Well Name: ODSN-45i Contractor: NABORS DRILLING Rig Number: 19AC Job Category: DEVELOPMENT DRILL Spud Date: 8/4/2008 Rig Release Date: Depth Start Foot/Meters Last Mud Start Date End Date (fKB) (f?) Dens(Ib/gal) Summary 8/2/2008 8/3/2008 44.0- 0.00 8.80 Rig down lines. Move rig F/ODSN-40 T/ODSN-45i. RU lines in HUTZ and cuttings transfer lines from CCU to RSC. PU&spot head on ODSN-45i, install 16"riser and test starling head to 500 psi for 10 min.-OK. Install 4"annular valve and insure environmental seal on conductor • inflated. Replace TDS service loop due to damage.Transfer spud mud to rig pit system. 8/3/2008 18/4/2008 44.0 0.00 8.80;Replace Top Drive Umbilical.Spot E-line for Gyro survey.PU 5"drill pipe and rack in derrick, move pipe in derrick to off drillers side. 1 8/4/2008 18/5/2008 44.0 312.00 8.901 PU 5"drill pipe and rack in off drillers side of derrick. Adjust Top Drive brakes,slip and cut drill line, PU and MU BHA, PJSM for spud,Clean out conductor to 153'. Drill 13-1/2"surface hole F/153'T/356'. 8/5/2008 8/6/2008 356.0 1,697.00 9.30 Drill 13-1/2"Surface Hole per HES DD&Well Plan#14a, drilling&surveying 630'-722'. I Continue drilling ahead,722'-2053'. 8/6/2008 8/7/2008 2,053.0 1,419.00 9.40 Drill 13-1/2"open hole section per HES DD&Well Plan#14a.CBU Hi-vis sweep. Continue drilling ahead from 2,053'to 3,472'MD. � I 8/7/2008 8/8/2008 3,472.0 1,513.001 9.50r Drill 13-1/2"open hole section per HES DD&Well Plan#14.a,drilling&surveying 3,472'-4,985' (4985'TD for Surface Hole).Pump 60 BBL's Hi-Vis sweep&CBU 3.5x,prior to wiper trip to bit. 8/8/2008 8/9/2008 4,985.0 0.001 9.701Wiper trip BHA#1,4,985'-180'(pump out 1,477-180'). RIH w/ledge seen @ 1,500'&tight spot @ 2,241'.Continue to RIH 2,241'-4,609',where slightly tight.Wash/Clean 4,609'-4,985'. RSC pumps down, repair RSC. Wash/Ream 4,605'-4,985'&CBU until MUD in shape. 8/9/2008 8/10/2008 4,985.0 0.00' 9.90I1Finish POOH w/BHA#1,racking back as much in Derrick. PJSM&RU to&Run 10-314"Casing Iger program (Ledge @ 1,500',tight @ 3,510').Land casing per Vetco Gray Hep. 47) 3' 4,9/ . +++Break circulation&stage up per schedule(PJSM held). 8/10/2008 18/11/2008 4,985.01 0.00 9.70 Continue to stage up to 10-12BPM&condition mud(PJSM).Once completed,test Cement lines to 3,500psi&Cement 10-3/4"Casing into place per program, 168 sx Thermal& 105 sxE� !Class'G'. Recieved 90 BBLs contaminated mud&90 BBLs good cement back to surface: Bump plugs-w/500psi over 3 mins-ok,w/CIP @ 07:21hrs 08/10/08. RD Cement&casing ;running equipment& LD landing Jt& PU Johnny Wacker(flush Riser).LD tool&ND 16" Riser system, Install Vetco Gray M233 Well Head,tests al element to 5,000psi-ok. NU 11."-5K rated BOP stack& Risers. s`e. /pro 8/11/2008 f 8/12/2008 4,985.0 0.00 9.70 NU BOPE,LD BHA#1,Set wear ring,PU 150 jts 5"drillpipe from pipe shed. RIH with same. POOH,Stand back 5"drillpipe in derrick. PU 5"drillpipe from pipe shed. RIH with same. 8/12/2008 18/13/2008 4,985.0,• 0.00 9.70 Finish PU total of 120 jts of 5"DP f/1,297't/3,897'&circ DP volume.Slip&Cut drilling line per NAD procedures. POOH racking back 40 Stands of 5"drillpipe. Finish racking pipe&PU BHA #2& rack back.Set test plug& attempt to test BOPE,but AP high test failed due to test plug leak. Unable to retrieve test plug.Separate wellhead sections A&B of M233 Well head(find faulty VG Seal Ring). Dummy run test plug-ok.NU sections on Well Head.Unsuccessful dummy run with two different test plugs. Unable to set in wellhead profile. ND and seperate wellhead sections A&B for inspection. JI 8/13/2008 8/14/2008 ! 4,985.0 0.00' 9.70 Installed VG test plug& NU Vetco Gray Well Head section A&B.Install 16"Riser&fill stack. Test BOPE per AOGCC requirements(Chuck Sheve waived witness).Attempt to pull test plug (failed).Break apart Well head sections A&B&retrieve test plug.NU Well Head fill BOP stack&perform casing test to 3,500psi for.5hr(ok).PU& RIH w/BHA#2(9-7/8"Bit RTTS type).Break in Geo Pilot seals&get past Tam Port collar @ 1,020'w/o issue.RIH to 4,906'& displace to seawater-based LSND mud type system. 1 • — — — I._ Page 1/9 PIONEER Operations Summary Report NATURAL RESOURCES Depth Start ! Foot/Meters { Last Mud Start Date End Dale (ttKB) (It) Dens(lb/gal) Summary 18/14/2008 ;8/15/2008 4.985.01 1.420.00 8.901,Finish circulating fresh 8.eppg LSND mud&condition same.Clean out suction screens on pumps. Finish drilling cement, F/C&shoe @ 4,973'.Clean out rathole to 4,985'&drill 9-7/8" (hole to 5.005'. CBU&pull back into casing. Rig to& perform LOT/FIT to 14.81ppg EMW. Rig Idown test equipment. Drill 9-7/8" Intermediate Hole Section to 5,005'-6,562'MD. 8/15/2008 8/16/2008 6.405.01 1,579.00 9.10IDrill 9-7/8"open hole section to 6.562'.Circulate and condition hole.Make wiper trip from 6,562' to 4,950'.Service rig.RIH to bottom at 6,562'.Drill 9-7/8"open hole section from 6,562'to 1 7,985'.Circulate and condition hole for wiper trip. 18/16/2008 8/17/2008 7.984.0 791.00 9.101 Circulate and condition hole for wiper trip.Perform 13.0 ppg MWE FIT. Make wiper trip from 7.985'to 6.500'. Service Rig. RIH to bottom at 7.985'. Drill 0-7/8"open hole section from 7,985' 1 to 8,775'. 8/17/2008 18/18/2008 8,775.0 795.00 9.20'Drill 9-7/8' open hole section from 8,775'to 9,570'MD. ;8/18/2008 8/19/2008 9.570.0. 612.00 9.20IDrill 9-7/8"open hole section to 9,973'MD.Circulate and condition mud.Make wiper trip from 19,973'to 7.995'.Hole in good condition.Service rig. Drill 9-7/8'open hole section from 9,973'to 110,182'MD. 8/19/2008 8/20/2008 10,182.01 1,468.001 9.20'Drilled 9-7/8"open hole section to 11,650'MD(5,496'TVD). 8/20/2008 18/21/2008 11.650.0' 673.00 9.30 Drill 9-7/8" Hole to 12323'. Begin circ. bottoms up.well packed off,work to free pipe jarring up to 1360K (200K over string wl),jarring down to 40k(120K below string weight at 160K neutral). 1 18/21/2008 18/22/2008 12.323.0 0.00 9.101 Work stuck pipe,jar up with 200K over neutral and 110K below neutral,work up to 485K and got; pipe movement from 11299'up to 10408. Pipe became stuck with no,movement up or down. Unable to re-establish circulation.Continue to work pipe while mobilizing Free point and fishing tools. 1 I I 8/22/2008 8/23/2008 12.323.0 0.00 9.201 Work stuck pipe,attempt to run dummy run with wire line to determine stuck point,max depth 4768'due to thick mud. Made blind back off,Circ and condition mud. 18/23/2008 18/24/2008 12.323.0 0.00 9.201 Circ&condition after blind back off,SLM POOH, MU screw in sub and TIH to 1140'. 18/24/2008 18/25/2008 12.323.0 0.00 9.201TIH to casing shoe,change out encoder,TIH, B/C,tag fish at 9449'.Circ&condition while waiting on HES wire line tools. 18/25/2008 18/26/2008 12,323.01 0.00, 9.20'Change TDS dies, POOH, LD backed out joints,TIH,tag and MU to fish,transfer torque,back out high,re-engage fish,Transfer torque, back out at screw in sub.Ciro&Condition, RU HES 7/32"wireline,GIH to 6700',pump tools down,MU to screw in sub. 1 1 i 8/26/2008 18/27/2008 12.323.0 0.00 9.201LD String shot#2. RIH with string shot#3 to 4000',pump down, re-gained returns with no 'losses.Observe on trip tank,pump down to depth,tool string lodged in jar mandrell.Work free Ian attempt to shoot 1 joint above jars,miss fire, POOH, primer cord pulled out of firing head. B/C and work up to 600 GPM with no losses,work pipe F/40-480K and move up hole Iapproximately 70'. Packed off and stuck.MU string shot Run#4,GIH to 4000',pump down to :9968', log up to screw in sub at 9371'WLM, had 140 lb over pull with string shot at sub. Log down to space out and log up to put string shot at 9964.5',attempt to shoot connection,no loss I in torque or vibration. POOH with wire line miss fire. RD wireline. Page 2/9 PIONEER Operations Summary Report ; NATURAL RESOURCES • start Date End Date Depth Start Foot/Meters 1 Last Mud (f1KB) (ft) I Dens(Ib/gal) t Summary 8/27/2008 18/28/2008 12.323.0 0.00 9.20'Finish RD wire line, Make blind back off at 635'. POOH, RU pull wear bushing, PU 9 jts,6.5" DC,MU RTTS with storm valve. RIH to 350'and set RTTS @ 61'. POOH w/2 singles and SSCV stinger.Test RTTS to 1000 psi. Blow down lines,drain stack and ND BOP.Change out !Multi bowl wellhead and test to 5000 si.Install wellhead valves and RU riser.NU BOP,set test p ug an es to ow igh.Witness waived by Jeff Jones of AOGCC.Pull test plug and RD test equipment. RIH and engage RTTS and release same and POOH.UO 3ea. 6-1/2"DC and rack back 6ea.DC.Install wear Bushing and prepare to PU Fishing assembly. 8/28/2008 8/29/2008 i 12,323.0 0.00 9.20'MU screw in sub and RIH to top of 5"at 635',engage 5"and attempt to circulate, pressure i climbed to 1000psi and slowly bleeding off,got rate up to 2 BB1/min with 900psi and minimal returns,shut down.While rigging up wireline it was noted on the BOP chart that the 4500 high ltests had not been achieved. Conduct Blind back off in order to rig up and test.Contact Chuck Sheave w/AOGCC for waiver on 3500 test until fishing operations are concluded. MU HES { wireline,CCL and String shot. RIH to 3,500 line hit refusal. Pump line down to 9,964'. Log with 'CCL,Spot String shot and fire same.Back string out of box, PU,Circulate and condition mud. POOH f/9,955'1/6,155'. 1 • • 18//29/2008 8/30/2008 12,323.0', 0.00 9.20 POOH f/6,155'to Surface. LD 1 Stand of 5"with damaged threads.LD Screw in sub, 9 Joints of I 5"DP,and 10 Joints of HWDP. MU Fishing BHA and RIH to 9966'and engage fish.Jar on fish land slowly stage pumps up to 525 GPM w/Full returns.Continue to work on establishing rotation. i 8/30/2008 18/31/2008 12,323.0! 0.00 9.70'Continue Jarring down on pipe while holding torque. @ 01:30 Pipe became free, Full Circulation', and Stage rotary to 130 RPM.Circulate and work pipe cautiously 1 complete B/U before • attempting to rack a stand back.Continue Back Reaming 1/10,272'1/9,988'.POOH on Elevators 11 1 f/9,988'1/9,296'PU Wt=250K S/O Wt=100K.Pump out f/9,296'3/8.000'Dumping @ 625 I ,GPM.Hole packed off,Lost 30 BBL mud and High ECD's and lost Circulation.Re-establish 1 Circulation and stage pumps up to 250 GPM and Pull1/8,000 1/7,621.Start Back Reaming f/7,621'1/7,526'using 40 RPM and pumping @ 450 GPM.Gas rose to 3,838 units and losing mud over shakers,Slop Backreaming and Circulate and work pipe until gas dropped out. Resume Back reaming(/7,526'1/7.246'working thru tight spots @ 7,508'and loss of returns at I .17,410'. 8/31/2008 19/1/2008 ( 12.323.0 0.00 9.40,Back Reaming F/7.246'to 6.542'. Using 550 Gpm @ 2.075 Psi,rotate @ 130 Rpm. Hole acting !better. ECD 10.3 to 10.5.Gas 65 to 300 units and is associated with the cuttings load coming • • (back over the shaker.Continue Backreaming F/6,542'to Shoe @ 4973'.Using 550 GPM w/ 12,050 PSI, 140 RPM.Stop Bacreaming @ 5,089 Pull into shoe and Circulate 2 BU.Conduct a I FIT w/9.4 Mud weight,Pressure up to 610 PSI,shut down and observe pressure and after 6 min.pressure stabilized @ 585 PSI. Pumped 20 bbls and returned 19 BBIs,ora 11.45 down 1Hole EMW. Conduct Post Jarring inspection of Derrick,Slip and Cut Drill Line and POOH with Fish. POOH f/4,973'1/3,992'. I ' 9/1/2008 9/2/2008 12,323.0 0.00; 9.40 Back Ream 1/3,992'1/3,898'. Pump and POOH(/3,898'1/3,760'.Pumping at 550 GPM w/1650 Psi.Rotate slowly at 20 RPM.Attempt to pull on elevators 1/3,760'1/3,509'.Hole started 1 :swabbing again.Pump and Pull f/3,509'1/3,206'Pumping at 550 GPM w/1650 psi. Rotate slowly at 20 RPM.Attempt to pull on Elevators f/3,206'1/3,112',Still Swabbing. Pump and Pull 11/3,112'1/2,750'.Pumping at 550 GPM w/1650 PSI rotate at 20 RPM.Attempt to pull on 'Elevators f/2,750'1/2.653',Still Swabbing.Pump and Pull f/2,653'1/600'.Pumping at 600 GPM w/1630 PSI Rotate at 10 RPM.Lay out Fishing BHA and Fish.Stabilizers and all related tools were clean,No Balled up pieces. MU Clean out assembly and RIH to 2,736'. i 9/2/2008 9/3/2008 12,323.0! 0.00 9.40 RIH w/clean out assembly F/2,736'to 4.960'.Circulate B/U.Continue to Circulate until shakers Iclean. I rouolesnoor Top Drive while staying at shoe and Circulate hole clean. RIH F/4.960'to 17.559'and Circulate B/U. Resume RIH F/7.559'to 8.995'changing out 7 damaged joints of 5" IDP and replacing with new. I ' • I I 1 1 1 Ii Page 3/9 PIONEER Operations Summary Report 1NATURAL RESOURCES Foot/Meters .Last Mud Start Date 1 End Date Depth Start ! (ft) i Dens(Ib/gal)1 Summary 19/3/2008 19/4/2008 I 12,323.0 0.00 10.50Stage in hole to 10038.C&C. B/U.chance out mud with new 10.5 PPG,TIH to 11340',wash ;and ream F/11340'To/12217'. Performed BOPE function test per AOGCC,NABORS,PNR • I requirements. 9/4/2008 9/5/2008 12,323.01 0.00 11.50!Circ&condition mud at 12217', Perform 2 Dynamic FIT test using 10.5 PPG Mud,observed 1 ;12.9 ECD and 12.77 ECD on test before losses seen. Raise MW to 11.5 PPG, Attempt to pull on elevators F/12029'to 11841',pulled into tight spot with 50 K over,S/O, M/U TDS,wash and ream F/11926'to 11812'. 1 1 9/5/2008 9/6/2008 12,323.0 0.00 11.50:Back ream to 10700'.CBU until ECD's lower and shaker clean, POOH to 8465, Back ream F/ 18465'to/7476', POOH F/7476 to/5475', Back ream F/5485'to/5405', pump out F/5405'to/ 15231', back ream 5231'to/5019, POOH F/5019'To/4923',CBU, POOH, L/D BHA,Service TDS, R/U to test BOPE. 9/6/2008 9/7/2008 12.323.0' 0.00 11.50:Test BOPE per AOGCC requirements,(250psi low/4,500psi High),w/Lou Grimaldi present for State. Once completed, line up choke manifold& begin PU BHA 46, troubleshoot MWD. RIH to +/-334'.filling pipe&test ing MWD as required.TIH to 3000', Down link to MWD,TIH to 4973', CBU.TIH to 6352'wash thru obstruction,TIH to 7578',CBU,Wash thru obstruction at 7588', TIH to 8531'. '9/7/2008 9/8/2008 12.323.01 284.00 11.50IContinued to RIH w/BHA#6 to 10,049',& CBU.Continue to Wash/Ream 10,049'-11,185'where CBU to reduce ECD's. RIH on elevators 11,185'-11.944'w/o further porblems.Wash/Ream • under gauged hole,11.944'-12,214',&CBU,(begin 760 BBL dilution).Get parameters&start drillin ,12,217'-12.607' I ' 9/8/2008 9/9/2008 12,607.0; 261.00. 11.50 Drill 9-7/8"Hole to 12,868',where experience tight hole while drilling. PU out same,&unable to regain MWD detection,(Tuffeous Interface).Able to rotate&circ.while CBU 3x,Rack back 1 ,std/.5hr while back reaming to 12,865'-11,646'.Pull on elevators w/o swabbing, (100-120K over),11,646'-10.025',where pump dry job.Continue to hoist on elevators to 9,064'where had ito screw into&pump/back ream out 8.984',but MWD started working.Continue to work tight thole 8,984-9,016',& MWD worked intermittently.Back reamed to 6349'. 9/9/2006 9/10/2008 12.868.0 0.0C 11.50 Continue to POOH,6.349'-5.300'. Back Ream tight section,5,300'-5,117',&then pump out to 14.927'. Pump dry job.Continue to POOH to BHA#6 tools, (Rack/LD same). PU replacement • MWD components& MU BHA 47. RIH to 4,924'&CBU,Slip/Cut Drilling line,&service TDS& rig.Continue to RIH w/problems,4,924'-7,577'&stage up CBU,as close to 12.65ppg EMW I ECD.Once BU achieved, RIH to+/-8,995'& Ream tight section to 9,115'.Continue to RIH to 110.015',where again.staged up circulation to 600gpm.while keeping ECD @ 12.37ppg EMW. 9/10/2008 9/11/2008 1 12,868.01 366.00' 11.50IContinued to RIH w/BHA#7, 10,146'-12,544',where tight spot seen. Ream 12,544'-12,868'. Drill 'ahead 9-7/8"Hole section, 12,868'-13,100'w/o much issues. Lost swab on pump.Circulate& repair same.Resume drilling 13,100'-13,292'. ii 1 it 9/11/2008 19/12/2008 13,234.01 349.00 11.901 Repair Mud Pump 4 2.Drill 9-7/8'open hole section from 13,234'MD to 13,583'MD. MWD Tool Failure.Circulate 3x's bottoms up.Rack back stand every 1/2 hour.RIH from 13,161'to 13,583', hole in good condition.Circulate and weight up active mud system from 11.5 ppg to 12.0 ppg. 9/12/2008 9/13/2008 I 13,583.0' 0.00 12.00 Finished circulating 12.0ppg MW around,while Back reaming&standing back 1 std.per.5hr. j 1 Continue to Back ream out of hole,w/over pull,pack off's,tight hole conditions, 13,084'-12,340'. Attempt to rack back stand @ 10,187',but unable to grip TF w/TDS grabber dies. RIH w/same stand to 11,182'&C/O Grabber dies on TDS.POOH,Back ream to 10,712'MD. POOH on elevators from 10,712'to 8,812'.Unable to work thru tight spot. POOH, Back ream from 8,818' :to 8,723'MD. it Page 4/9 PIONEER Operations Summary Report NATURAL RESOURCES Depth Stan Foot/Meters I Last Mud I Start Date End Date (11KB) (h) Dens(lb/gal) j Summary 9/13/2008 19/14/2008 I 13,583.0 0.00 12.00'Continue to POOH w/BHA 447,8,723'-4,929',having to back ream tight spots @ 6,260'&5.452'. j Pulled inside casino shoe @ 4.973'w/o pumping/rotating.CBU-Pump dry job,serviced rig/TDS & performed BOPE function test as required by AOGCC. Flow check,(well bore static),& POOH w/BHA 417 to 659'w/o issues. Pull wear ring rack tools&Pull Nuke sources. Down load tools&LD MWD.PU& MU BHA 418&atter initializing MWD RIH w/same.RIH to+/-4,783'& •CBU.Continue to RIH to 6.345'&see tight spot,Screw into TDS& Rotate slowly thru.Continue • 'to RIH to 7,740'MD.Circulate and condition mud.CBU. 9/14/2008 '9/15/2008 13,583.0 283.00 12.00'Continue to RIH w/BHA 41 8,7,740'-10,011'MD on elevators,(replaced 25 jts of 5"DP due to worn down Hard Banding).CBU.Continue to RIH w/BHA 44 8, 10,011'-12,569'MD on the elevators,and then used TDS w/40 rpm,& 100 gpm to continue RIH w/o much further ,problems,to 13.518'MD.Wash/Ream to 13.583'. Rotary Drill 9-7/8"Open Hole Section from 13,583'to 13.866'MD(6,165'TVD),"TD". 9/15/2008 19/16/2008 13.866.0 0.00 12.00'Circulate and condition hole.CBU 3x's. Rack back one stand of drill pipe every 1/2 hour. Back team out of hole at drilling rate from 13.866'to 13.424'.Work tight hole and pack off's from !13,630 to 13,476'. POOH with top drive from 13,424'to 13,107'. Back ream as needed. Observed intermittent tight hole. POOH with top drive from 13,107'to 12,007'. Back ream as needed.Observed intermittent tight hole. POOH on elevators from 12,007'to 10,678'MD. !I 'Circulate and condition mud. CBU.Service Top Drive and Rig. RIH on elevators from 10,678'to 12.835'MD. i I 9/16/2008 9/17/2008 13.866.01 0.00 12.50 Continue wiper trip from 12.385'to 13,770',using 40 rpm's on IDS to aid getting down through ; Shales.Wash&Ream to bottom at 13,866'.Work thru tight hole at 13,770'& 13,820'. Displace mud system to 12.5 ppg.POOH with drill pipe to run casing,from 13,866'to 8,830'. Back ream (from 9,079'to 8;830'. Service top drive& rig. Replace grabber dies. POH from 8,830'to 6,415' on elevators.Work tight hole at 6,415'. POOH on elevators from 6,415'to 5,903'.Occasionally I 'back reaming from 6,251'to 6,167'and 5,982'to 5,903'. IiI I , 9/17/2008 9/18/2008 13.866.0 0.00 12.50!Finish POOH w/BHA 448,5.903'-4.955'.Once in side 10-3/4"casing,CBU,Serviced Rig&TDS 18 Slipped/Cut drilling line.A dry job was pumped&assembly POOH w/o further incidents.The • i HWDP were racked back and everything else LD.Set test plug&C/O Top Pipe rams to 7-5/8". • IOnce completed,lest same to 250psi/4,500psi high&chart same(Jeff Jones waived witness lfor State).The floor was then rigoed up for running the 7-5/8"Casing& PJSM held.The 7-5/8" !shoe track was made up accordingly&floats tested(held ok).Casing was then ran per program j+/-1.000'&filled w/11.5ppg MW per program. RIH with 7-5/8"casing to 2.854'. I i 9/18/2008 19/19/2008 I 13,866.0' 0.00' 12.50 i Float 7-5/8'casing from 2,854'to 8,047'.Fill casing with 90 bbls:(2,000') 11.5 LSND mud. !Push casing in hole from 5.306'to 7,880'.Rotate casing string into hole from 7,880'to 8,047'. 1 I 19/19/2008 19/20/2008 I 13,866.0 0.00 12.501 Rotate 7-5/8"casing string into hole from 8,047'-10,000',w/various collars,torque rings&jt. 41232 C-O,due to galling of threads.. R/U Halliburton Wire Line and prepare to set bridge plug to .allow top 4000'of casino to be filled while running. 19/20/2008 19/21/2008 13,866.0 0.00 12.50'Ran Baker Bridge Plug on Halliburton Wire Line and set at 204'below RKB,(Set in Jt 41 239) R/D wire line equipment. Ran 7 5/8"Casing.Changed out collars as needed due to thread galling and sea!rings being displaced and able to reseal.After connection at 11,395'unable to move pipe up or down.Work to free pipe with 585 K over pull and squat to 25 K.Worked torque into pipe up to 22 K and worked from 25 K to 225 K with no movement. • 11:1(r--\ &91:L..\ Page 5/9 • PIONEER Operations Summary Report NATURAL RESOURCES I i Depth Start i Foot/Meters i Last Mud Start Date I End Date MKS) ff1) Dens(Ib/oai) Summary 9/21/2008 19/22/2008 13,866.0 0.00 11.501 Rig up to run 4"X739 DP into 7-5/8"Casing to Retrieve Baker Bridge plug. RU Baker Fishing i Slip bowl&get slips on barge. Finish making false floor table& MU Baker Retrieving assembly ;per Representative.RIH(7-5/8"casing). PU 51 joints of 4"DP.Latch onto Bridge plug @ 1.630' la allow Mud to balance out between annulus. Hoist&stand back 4"DP&recover fish(LD !same). R/U fill up line and till 7 5/8"casing with 11.5 PPG mud allowing air to swap out of interior at intervals to minimize blow back. R/D short bails,change out saver sub, install long bails. M/U TDS into drive sub&continued filling pipe with 11.5 PPG mud until 1000'of pipe left empty. i ! I I i I 9/22/2008 ,9/23/2008 l 13,866.01 11.50'Finish R/U casing elevators and slips,P/U joint 7 5/8"casing with drive sub, M/U same to TDS, ' 0.00' 'Fill pipe with 130 BBLs 11.5 PPG mud.Established good circulation with 11.5 PPG mud in and 112.5 Mud out.Work string from 25 K to 500 K with no movement.Applied 22 K torque to pipe and stalled TDS,worked pipe. Flow slowly fell oft to zero with 13.2 PPG mud returns from well. !Continue to worki e from 25 K-500 K with 22 K TO, attempt to regain circulation with no PP 4 success. R/U cement equipment and pump 45 BBLs 15.8 PPG cement and displace with rig pumps stagedd up to 6.5 BPM,bumped plug with 1500 psi over pumppressure and hold 5 min. 'Check floats.OK, R/D cement equipment. N/D BOP,Set emergency slips with 440 K, 9/23/2008 19/24/2008 13.866.0 0.00 12.50..Finish nipple up. R/D csg equipment. R/U 5"handling tools, UD drill pipe from derrick. Repair pipe shed skate hydraulic motor. UD 5"drill pipe, repair draw works drill line tangle,UD 5"drill I pipe. 9/24/2008 19/25/2008 13.866.01 0.00: 12.50 The rig transferred 17 std's of 4"DP onto the ODS,&continued to LD 5"DP single @ time from Mouse hole installed in rotary table.A 4,500psi.casing test performed(.5hr&charted).PU& MU singles of 4"DP,while RIH w/same.Sim-Op's:While performing the upgrade,Freeze protected the 7-5/8"x 10-3/4"Annulus w/85 BBL's of Diesel. PU& RIH,(1 x 1),the 4"XT39 ` ! once again,to 7373". 9/25/2008 !9/26/2008 13.866.0 0.00 12.50'Continue to PU& RIH w/4"XT39 Dp to 11,012'. Est.circulation& stage up to 500gpm,w/Fresh I 112.5ggp MW.Circ. 1.5x DP volume& rotate Dp @ 15Orpm's.Short circ.by+/-1,000'& POOH& ;rack back 114 std's.Test choke manifold 250/4,500 psi while pulling out of hole. PU& RIH 12 jts 4"XT39 HWDP&27 jts 4"XT39 DP.Circ.again @ 700gpm 1.5x Dp volume. POOH&rack same,pull wear ring w/Vetco Gray Representative,&set test plug.C-O pipe rams to 4"Type& pressure test BOP stack per AOGCC regulations,(Mr. Lou Grimaldi waived witness). 9/26/2008 9/27/2008 13,866.0 0.001 12.50 Finish BOPE test,Set wear bushing,M/U BHA with Rhino Reamer and MWD tools.TIH, 'Shallow test MWD tools,TIH on 4"drill pipe verify strap with SLM.Wash through several tight spots,tag float shoe at 11289',drill out wiper plugs&float collars,wash to 11320'with no hard cement. 1 , 9/27/2008 19/28/2008 13,866.0' 0.00 12.501 Wash and ream shoe track to 11326'.drill cement to 11374',drill out shoe to 11377',wash and ream F/11377'to 11438'.MAD pass From 11420 to 10330'for CBL log.TIH to 13379,tagged !obstruction with 40 K, B/C&stage pumps up to 270 GPM,ECD climbed to 15.08 PPG,lost partial returns,slow pumps and C&C to condition mud and stage pumps up to 300 GPM while !reciprocating pipe.Wash and ream F/13379 To/13693',observe ECD to control losses, Ream !down with 80 RPM and 300 GPM,Ream up with 140-150 GPM,then down with same to verify !hole clear. ii 1 9/28/2008 9/29/2008' 13,866.0 0.00 12.501 Ream Fl 13693'To/13866',working thru multiple tight spots and pack offs.Back ream from 113866'To/13142'working thru multiple tight spots and pack offs,having to stage pumps up to regain returns,circulate and condtion to lower ECDs. 9/29/2008 19/30/2008 I 13,866.0 0.00 12.501Packed oft and stalled with 22 K TQ,at 13142', 100%losses work to free pipe and regain 'returns. Stage pumps up to 300 GPM. RPM=140. Wash and ream t/13068', lost returns,work Ito regain same.Back Ream f/13068't/12743',Circ.& Condition,pull 2 stands to 12585'.TIH I j lhole to 13866'.worked thru multiple tight spots and ledges,washed and reamed as needed. ICBU,Drop activation ball to open Rhino Reamer cutters. — —! —�— • — ---- — j Page 6/9 r r 1_ I Q N L E R Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Muc Start Date ! End Date I (SKS) fit) ;Dens pb/pap Summary 9/30/2008 110/1/2008 I 13.866.0 0.00 12.50'Back Ream F/13866 To/12729'with minimal losses and no hole trouble,attempt to pull pipe !while pumping and lost 750 psi pressure at 12729'. POOH to 12397',Test surface equipment ;2000 PSI,no leaks. POOH and back ream as hole required to tree pipe and pass obstructions F/12397 To/11438'.Saw slight drag when Rhino Cutters pulled in shoe.May indicate internal ! !seals blown causing pressure loss of 750 psi. l ! I i i 10/1/2008 .10/2/2008 13,866.0 0.00' 12.50 POOH from 11.438'to 11.285'.Pump out of hole due to swabbing.Service Rig&Top Drive. Change out saver sub.Slip and cut drilling line.POOH,pump out of hole due to swabbing.Trip 'from 11,285'to 6,175'.Attempt several times to pull straight on elevators. No Go.Work on top drive due to electrical problem.Circulate bottoms up. POOH with 4*drill pipe on elevators. Hole taking proper fluid displacement.Trip from 6,175'to 3,957'. 10/2/2008 10/3/2008 13.866.0 0.00 12.50i�POOH from 3.957'to 581'to BHA.Service BHA 49, lay down 1-jt HWDP. Break out I Rhino-Reamer.Lay down bat-sonic tool.Stand back BHA,lay down over torqued HWDP. MU 1 BHA 410, PU new Rhino-Reamer.Service top drive and rig,clear rig floor.MU Bit RR5&Ghost 'Reamer,service BHA 410.Wait on arrival of new TM collar from Halliburton Deadhorse shop. I MU new TM collar with BHA# 10. RIH with BHA 44 10, lay down 2 over torqued flex collars,lay (down 2-jts of over torqued HWDP,Shallow test PWD tool, RIH to 11,377'filling drill pipe every 2.500'.Stop at 7-5/8"casing shoe.Circulate and condition mud. 10/3/2008 :10/4/2008 { 13.866.01 0.00' 12.50'Circulate and condition mud at 7-5/8"casing shoe until 12.5 ppq mud all around.Take torque and drag readings prior to running in the hole. RIH from 7-5/8"casing shoe at 11,377'to 11,514'.Nabors Rig Electrician and Canrig Service Hand trouble shoot top drive.Circulate,pull '2-stands of drill pipe back up into 7-5/8"casing at 11,321'.Monitor wellbore.Work on electrical problem with top drive.Change oil in drawworks.Weekly function of BOPE.Circulate mud at 200 GPM 2.200 psi. New Canrig service loop delivered to OTP from NOC. i I 10/4/2008 110/5/2008 13.866.0 0.00 12.50:7 rouble shooting TD electrical issue.Continue circulating at 200 GPM 2,250 psi.General rig maintenance. Replace seal in drill pipe spinner on iron roughneck. Repair steam heater in pipe I , shed. 10/5/2008 10/6/2008 13,866.01 0.00 12.50 Finalize Top Drive Electrical Repairs.General rig maintenance.Grease choke and mud manifold.Plumb in water softener.POOH from 11,231'to 10,841'. PUW 155K,SOW 1OOK. 1 General rig maintenance.Grease manual and HCR valves.Change out valves and seats in number 411 mud pump.RIH from 10,841'to 12,764'.Observed tight hole at 11,899', 12,760, 12,764. Wash and ream from 12.764 to 13,389'.Observed tight spots at 12,860', 13,140', 13,195'.Wash and ream from 13,389'to 13,485'.Wash and ream from 13,485'to 13,866', bottom.Circulate and condition mud,2X bottoms up.Drop ball.Pump to Rhino Reamer,shear 'activation sleeve at 2,800 psi.Bring pump rate up to 300 GPM.Back ream open hole section from 13.866'10 13,830'with 7-1/2"Rhino Reamer. 1 ' 1 10/6/2008 10/7/2008 13.866.0' 0.00 12.50'Pump out of hole from 13.830'to 12,750'. Observed tight spot at 13,572,work thru same. Back ream open hole section with 71/2" Rhino Reamer from 12,750'to 12,670'at 75'to 80'fph. Observed tight spots at 12,735'and 12,700'.Work thru same.Circulate&con•i i•• •- a • 1112,670'.Max gas units at 6.849 qas cut mud at 11.8 pp9.Circulate until gas units fall below 11,000. Back ream open hole section with 71/2" Rhino Reamer from 12,670'to 11,850'at 75'to i180'fph.Observed intermittent tight spots.Work thru same. II Page 7/9 • PIONEER Operations Summary Report i NATURAL RESOURCES 'I jl Depth Start Foot/Meters ! Last Mud Start Date End Date (11K8) 1 (h) Dens(lb/gal);' Summary 10/7/2008 110/8/2008 1 13.866.0, 0.00 12.50:Back ream open hole section with 71/2" Rhino Reamer from 11.850'to 11,560'at 75'to 80 fph. !Observed tight spots and pack off's at 11842', 11700'& 11595'.Work thru same.Circulate and 'condition mud at 11.560'. Back ream open hole section with 71/2" Rhino Reamer from 11,560'to 111.468'at 75'to 80 fph.Shut down pumps,pull up into 7-5/8'casing to close Rhino Reamer 'blades.Circulate and condition mud..Service top drive,crown,and rig. RIH on elevators from 111.321'to 12.469'.Work thru tight spots at 12164', 12313', 12469'.Wash and ream open hole 'section from 12.469'to 12.840'. POOH on elevators from 12,840'to 12,400'. RIH on elevators 'from 12,400'to 12.840'.Work thru tight spots at 12,745'and 12,771'. MU top drive RIH. Hole (taking fluid, 150 bph static.300 bph with pumps on. RIH to bottom at 13,866'.Wash and ream lthru tight spots.Work thru same. POOH on elevators from 13.866'to 11,314'inside 7-5/8" .casing. Fluid loss rate at 150 bph.Circulate and condition mud. Monitor well.Fluid loss rate 'while pumping 300 bph. 150 bph with pumps off. RIH on elevators from 11,314'to 12,767'. Fluid loss rate at 150 bph while tripping. i1 10/8/2008 10/9/2008 13,866.01 0.00 12.50 RIH with drill pipe on elevators from 12,767'to 13,460'tight spot.MU top drive,Break circulation.Wash thru tight hole from 12.460'to 13,538'.Work same. RIH on elevators from 13.538'to 13.866'.Tag bottom,no fill. POOH with drill pipe on elevators from 13,866'to 11,350'. Monitor well for 15 min.Static fluid loss rate at±50 b h. Mix and pump 60 bbl 12.5 ppq 60 ppb LCM pill. Spot pill in open hole section. Chase pill wit15 bbls of mud. Lost 93 bbls of mud to hole while displacing pill.Mix and pump dry job.Drop 2-3/8 drift thru drill pipe.POOH with drill pipe on elevators from 11.350'to 427'.Break out and lay down BHA 41 10. PU and MU Enventure BHA to run expandable liner.Rack back in derrick.PU Weatherford liner running equipment to rig floor.Held PJSM on running Enventure Expandable liner casing.RU Weatherford casing tools.Troubleshhot Weatherford Casing Tongs. RIH with 6" Enventure expandable casing liner. Run 1,572'casing.Weatherford casing tongs damaged jt 4(41. Fluid loss to formation last 24 hrs 350 bbls, 14.5 bph avg loss rate. Note:Tom Maunder of AOGCC approved pipe ram exemption for 6"expandable casing11 - I , 10/9/2008 110/10/2008 13.866.0 0.00 12.50!RIH with 6' Enventure expandable liner from 1,572'to 2,635'. RD Weatherford casing equipment.Clear rig floor. Rig up false bowl over casing in hole. RIH with Enventure BHA on 4" III drill pipe to 2.635'. MU Liner running assembly with debris catcher.Rig down false bowl.Clear 1 1 rig floor. RIH with 6"Enventure Expandable liner from 2,625'to 12,460'on 4"drill pipe.Drop ball rat 10.882'. Pump ball in place and shear at 2.300 psi.Convert to float assembly. RIH fill every 5 stands of drill pipe. • I I ' 10/10/2008 110/11/2008 13.866.0 0.00 12.501 Work tight hole at 12,460'. RIH with 6"Enventure Expandable casing on 4"drill pipe from 12,460'to 13,135',tight spot,work down thru tight spot. RIH to 13,500'tight spot.Work down thru tight spot.RIH to 13.862'.Tag bottom.Circulate one drill pipe volume. Hold PJSM on 'cementing job.Break out top drive from drill string.MU cement hose to drill string. ppg cement. Break out cement line from drill string,drop dart, MU cement line back to drill string.Perform cement job,20 bbls 13.Oppg spacer+15 bbls 15.8ppg cement.CIP at 05:00 hrs. RD cement lines,pull and LD drill pipe pup joints from drill string.MU top drive,pressure up on drill string to 4,200 psi.POOH with Enventure casing expander hold 4,200 psi on drill string. Pull drill pipe !from 13,862'to 13,767'.Observed .ressure dro•from 4,200 .si to 400 •si.Unable to maintain !pressure on casing expanding tool.P••H with drill string while attempting to mechanical expand casing from 13,767'to 11,987'. Appears casing started moving up hole with drill string at 12.850'. RIH with drill string from 11.987'10 12,907'.Tag Enventure casing expanding BHA to casing bottom.Attempt to push casing back to bottom,pipe movement stopped at 13,435'. MU !top drive,Break circulation and attempt to move drill string downhole. No movement.POOH 'from 13,435'to 13,095'to pick up storm packer for BOP test. Still pulling casing. Flit-l. RIH from 113,095 to 13,111'.Tag up solid down hole.Attempt to regain pipe movement, No go.Attempt to ;release from Enventure expanding tool.Work 14 turns of left hand torque into drill string. Back off shallow down hole. POOH until at back off joint. 1 Page 8/9 PIONEER Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud - - -- Start Date End Date (f1K8) (f1) ( Dens(Ib/gal) , Summary 10/11/2008 110/12/2008 1 13,866.0 0.00 12.50;RIH with 7-5/8'storm packer& set same @ 47', (test to 1,000psi-OK).Drain stack& remove wear ring- install Test plug. Fill stack w/H20& initiate BOPE test,per AOGCC requirements. I(Mr.Chuck Sheave waived witness for State).Once completed.blow down choke manifold, kill I&HCR lines.Line up valves for RIH. Pull up out 7-5/8"storm packer w/op difficulties&recover !same.LD 9 x 4-3/4"DC's. PU& RIH w/std's 4"XT-39 DP to 964'.Change out leaky Wash Pipe ;pawing on TDS. RIH&screw into fish @ 13.486'.Able to push down to 13,522',before refusal. ILD one joint of drill pipe.Depth at 13.513'. Prepare to rig up Halliburton E-Line unit.Service top !drive&rig. Hold PJSM with Nabors&Halliburton on E-line Work. RU e-line thru top drive. Make dummy run with CCL to verify if operational. RIH with e-line to 1.000'no response from CCL. ;POOH with e-line to PU severing tool. 10/12/2008 10/13/2008 13,866.0 0.00 12.501 Continue to work on CCL of HES Wireline. PJSM/MU Sever Charge for run. RIH wIHES Sever Charge to+1-3,700'where took weight.Begin to pump down @ 2-3BPM rate=400-600psi(150, ;BPH loss rate.Pump tool 3,700'-10,810'(WL Depth)where pressure up to 4,300psi&unable tQ move tool up ownward.Attempt to pull out Upper Debris catcher of Enventure w/o success. Decision made to fire off Gun.as know depth&collar location(CCL not working) Unable to fire as igniter not showing proper voltage drop.Decision made to pull out of rope socket of HES WL. Pull 5,4004's&came upwards,where saw another 4,500#1 pull section.Upon retrieval @ surface there was not running gear present&confirmed left down hole.LD lower WL sheave. Decision made to twist off at Upper-lower debris sub if able. Est. right hand torque set @ 30 rpm= 11K torque.Gradually work 75K down-200K up& increase from 11K-19.9K where able 1 to est.constant 30-50rpm (indication seen when @ 130K Rot Wt came free w/16QK PU Wt. Pull up to 13,431'&attempt to pump on fish.Achieve 1,200psi w/48spm, (leads us to believe have Upper Debris sub&unfired charge present w/fish).POOH w/4"Drill Pipe from 10,824'-9,816' where had to LD Bottom jt on std./Top jt.of next std.due to where engagement at 1,086'(galled threads).Iron Roughneck hydraulic hoses damaged on stump while retracting from mousehole. Fix damaged Hydraulic hoses(2x's on Iron Roughneck).Service Rig&TDS also,while performing work.POOH w/4"Drill Pipe from 9,816-surface.(No excessive drag seen when exiting liner).Twisted off drill pipe cross over sub from top of Enventure debris catcher. Service I I top drive& rig.Discuss options with Pioneer Sr Drilling Engineer.Decision made to run 7-5/8" jcement retainer&proceed with suspending well operations.Rig down Halliburton E-line [sheaves from derrick.Change out saver-sub on top drive. Prepare to run 7-5/8"cement retainer. 10/13/2008 110/14/2008 I 13.866.0 0.00 8.50 RIH and set Halliburton 7-5/8"EZSV cement retainer at 10.100'drill pipe measurement. 'Establish infectivity rate below retainer. Rig up cement lines to drill pipe. Halliburton pumps 10 bbls of water,test cement lines to 4.000 psi, mix and pump 82 bbls of 15.8 ppg class G cement. I Displace cement with 100 bbls 12 ppg mud to below cement retainer at 3.5 bpm 1,280 psi, ICIP at 15:22 hrs. Pull stinger from cement retainer.Pump 2.5 bbls(82')of cement on ton of I retainer. RD cement lines, POOH with 4"drill pipe to 10,017'.Circulate bottoms up.Test 7-5/8" ;casing to 4.500 psi. Displace well to 8.5 ppg inhibited seawater. POOH and lay down 4"drill pipe ;10/14/2008 10/15/2008 a 13,866.0 0.00 8.50 Lay down 4"drill pipe.Change out blower motor on drawworks.Service rig and top drive. Slip and cut drilling line. RIH with 13 stands of 4"drill pipe from derrick. POOH lay down 4"drill pipe. f I !Pull wear ring. RU Nabors tubular handling equipment.RIH with 80 joints of 2-7/8"6.5 ppf L-80 'BTC tubing U 42' . an• using in y. • -... •• ... ... - . . 'equipment. t ' 10/15/2008 10/16/2008 13.866.0 0.00 8.501 Finish up w/BOP stack operation& ND same. NU Vetco Gray tree& Reversed circulated 86 I BBLs of Diesel for Freeze protection to+/-2,000'TVD.Once completed&allowed to U-tube for 45 mins, RD lines& manifold. Blew down Sea Water/Potable/Cutting lines&disconnected lines I in Hutz. Pull out Sea Water pump due to ice flow conditions. Prepared to& moved over to I ODSK-41. Center over well Bore&Shim up rig. Rig Released @ 23:59hrs, 10/15/08. i I II Page 9/9 ODSN-45i Nuiqsut Injector, P&A/Operation Shutdown Schematic Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal _. 16"Conductor ' A ` 153'MDrkb/153'TVDrkb 2-7/8"6.5#L-80 IBT-M,2100'TVDrkb ► Diesel to—2100'TVDrkb Seawater from—2100'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3438'TVDrkb ►� EZSV 10100'MDrkb/501 TTVDrkb ' Estimated Top of Cement @ Cement above packer:2.5bbI/50' 10100'MD/5017'TVDrkb Cement below packer:79.5bbI/1277'to 7-5/8"shoe+ 100'w/30%excess bullhead below shoe Top of 6"liner,10,806'MDrkb/5239'TVDrkb 1111 Top of Inner String fish, 10,825MDrkb L! Live Severing Charge w/2.0"OD 7-5/8",29.7#L-80 BTC-M,6.875"ID Debris Catcher,2.0"ID 11377'MDrkb/5412'TVDrkb I ► , 12413'MDrkb,Top of Expanded Section, / 6",18.6#L-80 Expanded to 6.767"OD,6.19"ID,6.131"Drift The highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section below the liner from 13513' and Connection unable to hold pressure,13,433 MDrkb . to the top of the Nuiqsut s'VlioN.11/461/".4 Expansion Cone 1 formation at 13812' and will 1 ( ' collapse and effectively seal 1 k Expandable csg shoe 13,513'MDrkb/6071'TVDrkb above Nuiqsut the —qualifying as `� 2 .112(a)(3) 1\ r 13866'MDrkb/6166'TVDrkb Hole Fill and Un-consolidated Cement Date: Revision By: Comments /22/2008 JDF PIONEER 190 13 2008Alex Vaughan P&A/Operationn Shutdown Condition ODSN-45i Injector NATURAL RESOURCES ALASKA • • Well Schematic Halliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 1 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN-45i,True North ,Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 • '€ ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) ' 1 ith OaSN-45i Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska,Zone 4 Geo Datum: NAD27(Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSN-45i Slot Name: 50-703-20577-70 Well Position: +N/-S -144.91 ft Northing: 6031005.53 ft Latitude: 70 29 44.804 N +E/-W -98.46 ft Easting: 469821.86 ft Longitude: 150 14 48.349 W Position Uncertainty: 0.00 ft Wellpath: ODSN-45i Drilled From: Well Ref.Point 50-703-20577-00 Tie-on Depth: 43.62 ft Current Datum: ODSN-45i Height 57.12 ft • Above System Datum: Mean Sea Level Magnetic Data: 7/28/2008 Declination: 22.43 deg Field Strength: 57630 nT Mag Dip Angle: 80.88 deg 1 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction ft ft ft deg 43.62 0.00 0.00 233.94 Survey Program for Definitive Wellpath Date: 11/3/2006 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 533.00 ODSN-45i Gyro(50.00-533.00) SRG-Gyro-SS Conventional SRG single shots 575.40 13833.63 ODSN-45i MWD(575.40-13833.63) MWD+Sag+CA+IIFR+MMWD+Sag+CA+IIFR+MS Survey MI) Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 43.62 0.00 0.00 43.62 -13.50 0.00 0.00 6031005.53 469821.86 TIE LINE 50.00 0.30 141.13 50.00 -7.12 -0.01 0.01 6031005.52 469821.87 SRG-Gyro-SS 100.00 0.30 191.03 100.00 42.88 -0.24 0.07 6031005.29 469821.93 SRG-Gyro-SS 168.00 0.50 165.94 168.00 110.88 -0.71 0.11 6031004.82 469821.96 SRG-Gyro-SS 197.00 0.48 148.51 197.00 139.88 -0.93 0.20 6031004.60 469822.06 SRG-Gyro-SS 228.00 0.59 198.76 228.00 170.88 -1.19 0.22 6031004.34 469822.07 SRG-Gyro-SS 258.00 0.58 166.67 257.99 200.87 -1.49 0.20 6031004.04 469822.06 SRG-Gyro-SS 288.00 0.68 167.36 287.99 230.87 -1.81 0.28 6031003.72 469822.13 SRG-Gyro-SS 321.00 0.98 173.11 320.99 263.87 -2.28 0.35 6031003.25 469822.20 SRG-Gyro-SS 351.00 1.08 175.74 350.98 293.86 -2.82 0.40 6031002.71 469822.25 SRG-Gyro-SS 382.00 1.32 178.28 381.98 324.86 -3.47 0.44 6031002.06 469822.28 SRG-Gyro-SS I 413.00 1.75 179.15 412.97 355.85 -4.30 0.45 6031001.23 469822.30 SRG-Gyro-SS 443.00 2.13 178.74 442.95 385.83 -5.31 0.47 6031000.22 469822.31 SRG-Gyro-SS 1 533.00 2.88 180.19 532.86 475.74 -9.24 0.50 6030996.28 469822.32 SRG-Gyro-SS 575.40 2.94 174.16 575.21 518.09 -11.39 0.61 6030994.14 469822.42 MWD+Sag+CA+IIFR+MS 670.40 3.91 162.96 670.04 612.92 -16.91 1.81 6030988.61 469823.60 MWD+Sag+CA+IIFR+MS 764.70 5.03 162.67 764.05 706.93 -23.93 3.98 6030981.58 469825.74 MWD+Sag+CA+IIFR+MS 859.30 5.77 161.44 858.23 801.11 -32.40 6.73 6030973.11 469828.46 MWD+Sag+CA+IIFR+MS 954.90 5.70 160.56 953.35 896.23 -41.43 9.84 6030964.06 469831.53 MWD+Sag+CA+IIFR+MS 1049.20 7.62 163.09 1047.01 989.89 -51.83 13.22 6030953.65 469834.86 MWD+Sag+CA+IIFR+MS 1143.50 8.56 164.80 1140.37 1083.25 -64.59 16.88 6030940.88 469838.47 MWD+Sag+CA+IIFR+MS 1238.70 9.80 165.71 1234.35 1177.23 -79.27 20.73 6030926.18 469842.27 MWD+Sag+CA+IIFR+MS 1334.70 11.30 167.74 1328.72 1271.60 -96.38 24.75 6030909.06 469846.21 MWD+Sag+CA+IIFR+MS 1428.60 13.21 170.21 1420.48 1363.36 -115.95 28.53 6030889.48 469849.91 MWD+Sag+CA+IIFR+MS 1523.55 12.76 171.01 1513.00 1455.88 -137.00 32.01 6030868.42 469853.31 MWD+Sag+CA+IIFR+MS 1618.50 13.98 172.54 1605.38 1548.26 -158.73 35.14 6030846.68 469856.35 MWD+Sag+CA+IIFR+MS 1712.90 14.83 172.59 1696.81 1639.69 -182.01 38.17 6030823.38 469859.29 MWD+Sag+CA+IIFR+MS 1808.20 16.36 172.06 1788.60 1731.48 -207.40 41.60 6030797.98 469862.62 MWD+Sag+CA+IIFR+MS 1902.60 18.07 178.03 1878.77 1821.65 -235.21 43.94 6030770.17 469864.84 MWD+Sag+CA+IIFR+MS Halliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 2 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Reference: Well:ODSN-45i,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) Wellpath: ODSN-45i Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft'. 1999.40 21.10 181.35 1969.96 1912.84 -267.64 44.05 6030737.74 469864.82 MWD+Sag+CA+IIFR+MS 2093.80 24.37 188.46 2057.03 1999.91 -303.90 40.78 6030701.49 469861.40 MWD+Sag+CA+IIFR+MS 2187.50 25.30 191.15 2142.07 2084.95 -342.67 34.06 6030662.76 469854.53 MWD+Sag+CA+IIFR+MS 2282.30 28.06 195.13 2226.78 2169.66 -384.08 24.32 6030621.39 469844.62 MWD+Sag+CA+IIFR+MS 2326.00 29.70 195.74 2265.04 2207.92 -404.42 18.70 6030601.07 469838.92 MWD+Sag+CA+IIFR+MS 2377.20 32.48 198.82 2308.88 2251.76 -429.65 10.83 6030575.88 469830.94 MWD+Sag+CA+IIFR+MS 2424.00 34.60 199.84 2347.89 2290.77 -454.05 2.26 6030551.52 469822.28 MWD+Sag+CA+IIFR+MS 2472.50 36.16 200.43 2387.43 2330.31 -480.41 -7.41 6030525.20 469812.50 MWD+Sag+CA+IIFR+MS 2566.60 39.82 202.47 2461.59 2404.47 -534.29 -28.62 6030471.41 469791.07 MWD+Sag+CA+IIFR+MS 2659.40 43.52 202.62 2530.89 2473.77 -591.26 -52.27 6030414.55 469767.19 MWD+Sag+CA+IIFR+MS 2699.00 44.79 203.91 2559.30 2502.18 -616.60 -63.17 6030389.25 469756.19 MWD+Sag+CA+IIFR+MS 2752.30 48.34 205.85 2595.95 2538.83 -651.69 -79.47 6030354.23 469739.75 MWD+Sag+CA+IIFR+MS 2805.10 49.84 207.14 2630.52 2573.40 -687.40 -97.27 6030318.60 469721.81 MWD+Sag+CA+IIFR+MS 2849.00 51.64 207.46 2658.30 2601.18 -717.60 -112.86 6030288.46 469706.09 MWD+Sag+CA+IIFR+MS 2943.20 53.16 207.96 2715.78 2658.66 -783.67 -147.57 6030222.54 469671.12 MWD+Sag+CA+IIFR+MS 3040.20 55.15 209.57 2772.58 2715.46 -852.59 -185.42 6030153.79 469633.00 MWD+Sag+CA+IIFR+MS 3133.80 57.80 210.63 2824.27 2767.15 -920.08 -224.55 6030086.46 469593.60 MWD+Sag+CA+IIFR+MS 3229.60 59.33 210.06 2874.23 2817.11 -990.62 -265.84 6030016.09 469552.02 MWD+Sag+CA+IIFR+MS 3323.40 61.07 209.65 2920.85 2863.73 -1061.21 -306.36 6029945.67 469511.22 MWD+Sag+CA+IIFR+MS 3417.40 64.24 210.67 2964.02 2906.90 -1133.39 -348.31 6029873.67 469468.98 MWD+Sag+CA+IIFR+MS 3465.30 65.89 210.86 2984.22 2927.10 -1170.71 -370.53 6029836.45 469446.62 MWD+Sag+CA+IIFR+MS 3512.30 69.49 210.64 3002.05 2944.93 -1208.07 -392.76 6029799.18 469424.24 MWD+Sag+CA+IIFR+MS 3560.00 71.29 209.81 3018.06 2960.94 -1246.90 -415.37 6029760.45 469401.47 MWD+Sag+CA+IIFR+MS 3607.70 73.43 210.51 3032.52 2975.40 -1286.20 -438.21 6029721.25 469378.47 MWD+Sag+CA+IIFR+MS 3700.80 73.49 209.15 3059.02 3001.90 -1363.62 -482.61 6029644.02 469333.77 MWD+Sag+CA+IIFR+MS 3797.60 75.67 213.26 3084.77 3027.65 -1443.40 -530.95 6029564.44 469285.10 MWD+Sag+CA+IIFR+MS 3892.10 75.67 212.88 3108.16 3051.04 -1520.13 -580.91 6029487.92 469234.84 MWD+Sag+CA+IIFR+MS 3986.90 74.92 215.00 3132.23 3075.11 -1596.20 -632.10 6029412.07 469183.34 MWD+Sag+CA+IIFR+MS 4081.10 74.82 216.86 3156.81 3099.69 -1669.83 -685.46 6029338.67 469129.69 MWD+Sag+CA+IIFR+MS 4176.00 73.20 216.32 3182.96 3125.84 -1743.07 -739.84 6029265.65 469075.02 MWD+Sag+CA+IIFR+MS 4268.50 72.50 218.38 3210.23 3153.11 -1813.33 -793.46 6029195.61 469021.13 MWD+Sag+CA+IIFR+MS 4365.10 71.06 219.72 3240.44 3183.32 -1884.59 -851.26 6029124.60 468963.04 MWD+Sag+CA+IIFR+MS 4458.60 70.94 218.34 3270.88 3213.76 -1953.26 -906.93 6029056.16 468907.10 MWD+Sag+CA+IIFR+MS 4554.80 70.77 219.77 3302.43 3245.31 -2023.83 -964.18 6028985.83 468849.56 MWD+Sag+CA+IIFR+MS 4648.50 71.10 218.30 3333.04 3275.92 -2092.62 -1019.96 6028917.28 468793.52 MWD+Sag+CA+IIFR+MS 4744.60 71.00 217.70 3364.25 3307.13 -2164.24 -1075.91 6028845.89 468737.28 MWD+Sag+CA+IIFR+MS 4839.60 70.69 218.10 3395.42 3338.30 -2235.05 -1131.04 6028775.31 468681.87 MWD+Sag+CA+IIFR+MS 4931.40 71.44 218.07 3425.21 3368.09 -2303.40 -1184.60 6028707.19 468628.04 MWD+Sag+CA+IIFR+MS 5012.78 71.57 218.31 3451.02 3393.90 -2364.06 -1232.32 6028646.73 468580.08 MWD+Sag+CA+IIFR+MS 5105.28 70.97 217.33 3480.73 3423.61 -2433.26 -1286.03 6028577.76 468526.09 MWD+Sag+CA+IIFR+MS 5202.48 70.78 216.37 3512.57 3455.45 -2506.74 -1341.11 6028504.50 468470.72 MWD+Sag+CA+IIFR+MS 5292.27 71.43 216.16 3541.65 3484.53 -2575.24 -1391.36 6028436.22 468420.20 MWD+Sag+CA+IIFR+MS 5393.88 72.60 214.62 3573.02 3515.90 -2654.02 -1447.32 6028357.67 468363.92 MWD+Sag+CA+IIFR+MS 5489.92 72.80 213.99 3601.59 3544.47 -2729.77 -1499.00 6028282.14 468311.94 MWD+Sag+CA+IIFR+MS 5577.53 72.79 214.00 3627.50 3570.38 -2799.15 -1545.79 6028212.95 468264.87 MWD+Sag+CA+IIFR+MS 5673.75 72.92 213.93 3655.86 3598.74 -2875.41 -1597.16 6028136.91 468213.20 MWD+Sag+CA+IIFR+MS 5773.17 72.72 211.84 3685.23 3628.11 -2955.17 -1648.73 6028057.37 468161.31 MWD+Sag+CA+IIFR+MS 5868.30 72.53 210.72 3713.64 3656.52 -3032.76 -1695.87 6027979.98 468113.86 MWD+Sag+CA+IIFR+MS 5962.55 72.20 211.00 3742.20 3685.08 -3109.86 -1741.94 6027903.07 468067.48 MWD+Sag+CA+IIFR+MS 6057.35 72.53 212.72 3770.92 3713.80 -3186.59 -1789.63 6027826.54 468019.49 MWD+Sag+CA+IIFR+MS 6151.54 72.92 211.27 3798.89 3741.77 -3262.87 -1837.28 6027750.47 467971.53 MWD+Sag+CA+IIFR+MS 6247.51 72.48 211.27 3827.43 3770.31 -3341.19 -1884.84 6027672.35 467923.66 MWD+Sag+CA+IIFR+MS Halliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 3 Field: Pioneer ASP Zone 4 Cu-ordinate(NE)Reference: Well:ODSN-45i,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) Wellpath: ODSN-45i Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lnel Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 6340.49 72.26 212.99 3855.59 3798.47 -3416.22 -1931.97 6027597.51 467876.23 MWD+Sag+CA+IIFR+MS 6434.79 72.46 211.57 3884.17 3827.05 -3492.20 -1979.96 6027521.74 467827.94 MWD+Sag+CA+IIFR+MS 6529.18 72.54 211.31 3912.55 3855.43 -3569.00 -2026.92 6027445.14 467780.67 MWD+Sag+CA+IIFR+MS 6623.99 72.35 212.08 3941.15 3884.03 -3645.92 -2074.41 6027368.43 467732.87 MWD+Sag+CA+IIFR+MS 6720.35 71.83 213.74 3970.78 3913.66 -3722.89 -2124.22 6027291.66 467682.75 MWD+Sag+CA+IIFR+MS 6814.40 71.76 214.87 4000.17 3943.05 -3796.69 -2174.57 6027218.07 467632.11 MWD+Sag+CA+IIFR+MS 6908.92 71.70 215.49 4029.80 3972.68 -3870.05 -2226.29 6027144.93 467580.10 MWD+Sag+CA+IIFR+MS 7004.57 71.68 215.84 4059.85 4002.73 -3943.83 -2279.23 6027071.38 467526.86 MWD+Sag+CA+IIFR+MS 7100.30 72.01 215.80 4089.68 4032.56 -4017.59 -2332.47 6026997.84 467473.33 MWD+Sag+CA+IIFR+MS 7193.35 72.53 215.54 4118.01 4060.89 -4089.59 -2384.15 6026926.06 467421.37 MWD+Sag+CA+IIFR+MS 7288.69 72.40 215.89 4146.74 4089.62 -4163.40 -2437.22 6026852.47 467368.00 MWD+Sag+CA+IIFR+MS 7382.89 72.80 215.45 4174.91 4117.79 -4236.43 -2489.63 6026779.67 467315.30 MWD+Sag+CA+IIFR+MS 7477.85 72.16 214.78 4203.49 4146.37 -4310.50 -2541.72 6026705.81 467262.91 MWD+Sag+CA+IIFR+MS 7572.92 71.77 214.65 4232.93 4175.81 -4384.80 -2593.20 6026631.72 467211.14 MWD+Sag+CA+IIFR+MS 7667.50 71.96 215.11 4262.37 4205.25 -4458.54 -2644.60 6026558.20 467159.44 MWD+Sag+CA+IIFR+MS 7758.40 72.02 214.91 4290.47 4233.35 -4529.34 -2694.20 6026487.61 467109.56 MWD+Sag+CA+IIFR+MS 7857.11 72.14 214.91 4320.84 4263.72 -4606.36 -2747.95 6026410.82 467055.51 MWD+Sag+CA+IIFR+MS 7951.54 72.13 214.87 4349.81 4292.69 -4680.08 -2799.36 6026337.31 467003.80 MWD+Sag+CA+IIFR+MS 8047.28 72.73 214.89 4378.71 4321.59 -4754.96 -2851.55 6026262.65 466951.31 MWD+Sag+CA+IIFR+MS 8142.04 72.86 213.92 4406.74 4349.62 -4829.64 -2902.70 6026188.19 466899.87 MWD+Sag+CA+IIFR+MS 8235.58 72.73 214.08 4434.41 4377.29 -4903.72 -2952.67 6026114.32 466849.60 MWD+Sag+CA+IIFR+MS 8330.92 72.86 213.75 4462.61 4405.49 -4979.30 -3003.48 6026038.95 466798.49 MWD+Sag+CA+IIFR+MS 8425.40 72.21 213.89 4490.97 4433.85 -5054.18 -3053.64 6025964.29 466748.03 MWD+Sag+CA+IIFR+MS 8520.59 71.03 214.65 4520.98 4463.86 -5128.83 -3104.51 6025889.86 466696.87 MWD+Sag+CA+IIFR+MS 8614.84 70.45 215.43 4552.07 4494.95 -5201.67 -3155.59 6025817.22 466645.49 MWD+Sag+CA+IIFR+MS 8707.25 70.97 215.11 4582.60 4525.48 -5272.89 -3205.95 6025746.22 466594.85 MWD+Sag+CA+IIFR+MS 8802.25 71.56 214.91 4613.11 4555.99 -5346.57 -3257.57 6025672.75 466542.94 MWD+Sag+CA+IIFR+MS 8897.29 71.76 215.01 4643.02 4585.90 -5420.51 -3309.26 6025599.04 466490.95 MWD+Sag+CA+IIFR+MS 8992.33 71.70 215.37 4672.81 4615.69 -5494.26 -3361.27 6025525.50 466438.65 MWD+Sag+CA+IIFR+MS 9087.72 72.40 214.07 4702.21 4645.09 -5568.85 -3412.95 6025451.13 466386.67 MWD+Sag+CA+IIFR+MS 9182.29 72.66 214.32 4730.60 4673.48 -5643.46 -3463.65 6025376.73 466335.67 MWD+Sag+CA+IIFR+MS 9276.97 72.27 212.54 4759.13 4702.01 -5718.80 -3513.39 6025301.60 466285.63 MWD+Sag+CA+IIFR+MS 9371.46 71.83 212.53 4788.25 4731.13 -5794.59 -3561.73 6025226.02 466236.99 MWD+Sag+CA+IIFR+MS 9466.41 71.88 213.38 4817.82 4760.70 -5870.30 -3610.81 6025150.52 466187.60 MWD+Sag+CA+IIFR+MS 9561.43 71.43 216.75 4847.73 4790.61 -5944.11 -3662.62 6025076.93 466135.51 MWD+Sag+CA+IIFR+MS 9656.16 70.96 220.58 4878.28 4821.16 -6014.11 -3718.63 6025007.16 466079.22 MWD+Sag+CA+IIFR+MS 9750.62 72.00 222.51 4908.29 4851.17 -6081.14 -3778.03 6024940.38 466019.55 MWD+Sag+CA+IIFR+MS 9845.50 72.39 225.50 4937.30 4880.18 -6146.11 -3840.78 6024875.67 465956.54 MWD+Sag+CA+IIFR+MS 9940.33 72.08 228.44 4966.24 4909.12 -6207.72 -3906.78 6024814.33 465890.30 MWD+Sag+CA+IIFR+MS 10035.42 70.98 231.76 4996.38 4939.26 -6265.57 -3975.96 6024756.77 465820.89 MWD+Sag+CA+IIFR+MS 10130.89 70.98 235.78 5027.50 4970.38 -6318.90 -4048.75 6024703.74 465747.90 MWD+Sag+CA+IIFR+MS 10225.27 70.91 238.53 5058.32 5001.20 -6367.28 -4123.68 6024655.67 465672.77 MWD+Sag+CA+IIFR+MS 10320.41 71.04 243.08 5089.35 5032.23 -6411.14 -4202.18 6024612.13 465594.11 MWD+Sag+CA+IIFR+MS 10415.41 71.75 246.21 5119.66 5062.54 -6449.69 -4283.53 6024573.92 465512.61 MWD+Sag+CA+IIFR+MS 10509.57 71.95 249.73 5149.00 5091.88 -6483.24 -4366.46 6024540.71 465429.55 MWD+Sag+CA+IIFR+MS 10605.50 72.46 253.32 5178.33 5121.21 -6512.17 -4453.07 6024512.13 465342.83 MWD+Sag+CA+IIFR+MS 10700.09 72.67 257.60 5206.68 5149.56 -6534.82 -4540.40 6024489.84 465255.42 MWD+Sag+CA+IIFR+MS 10794.90 72.27 260.44 5235.25 5178.13 -6552.04 -4629.14 6024472.98 465166.61 MWD+Sag+CA+IIFR+MS 10890.16 72.60 263.72 5264.00 5206.88 -6564.55 -4719.08 6024460.84 465076.64 MWD+Sag+CA+IIFR+MS 10984.46 72.46 267.15 5292.32 5235.20 -6571.71 -4808.73 6024454.04 464986.97 MWD+Sag+CA+IIFR+MS 11080.18 72.47 270.51 5321.16 5264.04 -6573.57 -4899.97 6024452.55 464895.73 MWD+Sag+CA+IIFR+MS 11173.49 72.67 274.68 5349.13 5292.01 -6569.54 -4988.88 6024456.94 464806.85 MWD+Sag+CA+IIFR+MS 11266.96 71.89 276.68 5377.58 5320.46 -6560.73 -5077.47 6024466.11 464718.30 MWD+Sag+CA+IIFR+MS Halliburton Company Survey Report Company: Pioneer Date: 11/14/2008 Time: 14:41:27 Page: 4 Field: Pioneer ASP Zone 4 Co-ordinate(NE)Refeence: Well:ODSN-45i,True North Site: Oooguruk ODS Vertical(TVD)Reference: ODSN-45i 57.1 Well: ODSN-45i Section(VS)Reference: Well(0.00N,0.00E,233.94Azi) Wellpath: ODSN-45i Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Aiim TVD Sys TVD N/S E/W MapN MapE Tool • ft deg deg ft ft ft ft ft ft 11356.00 71.72 279.39 5405.39 5348.27 -6548.91 -5161.22 6024478.27 464634.61 MWD+Sag+CA+IIFR+MS 11457.21 72.27 283.01 5436.68 5379.56 -6530.22 -5255.62 6024497.35 464540.29 MWD+Sag+CA+IIFR+MS 11552.12 72.21 286.60 5465.64 5408.52 -6507.13 -5342.99 6024520.79 464453.03 MWD+Sag+CA+IIFR+MS 11646.83 72.03 289.98 5494.72 5437.60 -6478.84 -5428.56 6024549.42 464367.58 MWD+Sag+CA+IIFR+MS 11742.09 72.21 292.85 5523.98 5466.86 -6445.75 -5512.95 6024582.85 464283.34 MWD+Sag+CA+IIFR+MS 11836.81 72.45 296.50 5552.74 5495.62 -6408.07 -5594.94 6024620.85 464201.51 MWD+Sag+CA+IIFR+MS 11930.91 72.29 300.23 5581.24 5524.12 -6365.48 -5673.84 6024663.77 464122.79 MWD+Sag+CA+IIFR+MS 12007.35 71.97 300.29 5604.70 5547.58 -6328.82 -5736.68 6024700.68 464060.11 MWD+Sag+CA+IIFR+MS 12101.64 70.85 300.90 5634.76 5577.64 -6283.33 -5813.61 6024746.47 463983.37 MWD+Sag+CA+IIFR+MS 12194.63 70.30 300.73 5665.69 5608.57 -6238.41 -5888.92 6024791.70 463908.25 MWD+Sag+CA+IIFR+MS 12289.23 70.71 303.97 5697.26 5640.14 -6190.70 -5964.24 6024839.71 463833.13 MWD+Sag+CA+IIFR+MS 12383.79 70.65 307.31 5728.56 5671.44 -6138.71 -6036.75 6024891.98 463760.84 MWD+Sag+CA+IIFR+MS 12479.00 70.96 309.49 5759.86 5702.74 -6082.86 -6107.21 6024948.11 463690.61 MWD+Sag+CA+IIFR+MS 12574.86 70.77 314.08 5791.30 5734.18 -6022.54 -6174.72 6025008.71 463623.35 MWD+Sag+CA+IIFR+MS 12669.13 71.83 317.98 5821.53 5764.41 -5958.28 -6236.69 6025073.21 463561.65 MWD+Sag+CA+IIFR+MS 12764.01 71.48 320.01 5851.40 5794.28 -5890.32 -6295.78 6025141.40 463502.84 MWD+Sag+CA+IIFR+MS 12864.80 72.46 323.82 5882.61 5825.49 -5814.90 -6354.88 6025217.05 463444.06 MWD+Sag+CA+IIFR+MS 12957.10 72.55 323.56 5910.35 5853.23 -5743.96 -6407.00 6025288.19 463392.23 MWD+Sag+CA+IIFR+MS 13052.14 72.99 324.36 5938.51 5881.39 -5670.56 -6460.41 6025361.80 463339.12 MWD+Sag+CA+IIFR+MS 13146.90 73.51 324.07 5965.81 5908.69 -5596.95 -6513.47 6025435.62 463286.37 MWD+Sag+CA+IIFR+MS 13242.77 73.77 324.33 5992.82 5935.70 -5522.34 -6567.28 6025510.44 463232.87 MWD+Sag+CA+IIFR+MS 13337.16 72.65 323.59 6020.08 5962.96 -5449.27 -6620.44 6025583.71 463180.01 MWD+Sag+CA+IIFR+MS 13432.69 73.56 321.31 6047.85 5990.73 -5376.81 -6676.15 6025656.39 463124.60 MWD+Sag+CA+IIFR+MS 13526.56 73.33 321.70 6074.60 6017.48 -5306.39 -6732.16 6025727.04 463068.88 MWD+Sag+CA+IIFR+MS 1 13580.48 73.55 321.45 6089.97 6032.85 -5265.90 -6764.28 6025767.65 463036.93 MWD+Sag+CA+IIFR+MS 13675.10 73.07 321.28 6117.14 6060.02 -5195.10 -6820.87 6025838.67 462980.64 MWD+Sag+CA+IIFR+MS 13770.61 75.01 320.96 6143.40 6086.28 -5123.62 -6878.50 6025910.38 462923.30 MWD+Sag+CA+IIFR+MS 13833.63 76.73 320.41 6158.78 6101.66 -5076.34 -6917.22 6025957.81 462884.77 MWD+Sag+CA+IIFR+MS • 13866.00 76.73 320.41 . 6166.21 6109.09 -5052.07 -6937.30 6025982.17 462864.79 PROJECTED to TD a i' l� RECEIVED STATE OF ALASKA , X, ' Iu ,a ALASKA OIL AND GAS CONSERVATION COMMISSION 0r,T , 4 \61 I APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil &Gas cul i.:• �- $.,,,..)�1 1.Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑✓ Perforate ❑ AhreV►age Other❑ Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program Q ' Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Developmentb;. Exploratory 208-100/308-329/308-340 3.Address: Stratigraphic ❑ fp't Service i 6.API Number: 700 G Street,Suite 600 Anchorage,AK 99501 ,:p 4• 50-703-20577-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ElNo 2 ODSN-45i 9.Property Designation: 10.KB Elevation(ft): 11. Field/Pool(s): ADL 355037/ADL 355036 57.12' MSL ' Ooogurk- Nuiqsut Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13866 6100 10825' 5280' N/A 10806'; 10825' Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 4931' 10-3/4" 4973' 3438' 5210 2470 Intermediate 11337' 7-5/8" 11377' 5447' 6890 4790 Expandable Liner 2638' 6'x 7-5/8" 13513' 6106' 6150 2750 ' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open Hole 13513'-13866' 6106'-6202' N/A Packers and SSSV Type: Packers and SSSV MD(ft): N/A N/A 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: fCr� / Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ) j i! Service ' f� 15. Estimated Date for 16.Well Status after proposed work: 10/14/2008 Commencing Operations: Oil ❑ Gas ❑ Plugged ❑Q • Abandoned ❑ 17.Verbal Approval: - Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL El Commission Representative:��'j+tz /11/2008 p '-�X-Corr.A & TM Wit 6;- 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Printed Name Joe Polya Title Sr.Staff Drilling Engineer Signature 26cp) Phone Date 343-2111 10/14/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a)g- a W Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required:q gyp c,._\ ..‘,'1����L.,.,vccr \_...2. ear dO Qti N C a s. o -\� C,\z:, , APPROVED BY Approved by:/1 COMMI N THE COMMISSION Date: /D/ Zo 8 811 OCT 1 1 1008 4..., i O. s'.da Form 10-403 Revised 06/2006 L ia p c �rc PIONEER NATURAL RESOURCES October 13, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry Notice for Proposed Operational Shutdown of ODSN-45i Surface Location: 2,889' FSL, 1176' FEL, Sec. 11, T13N, R7E, UM X = 469,821.86; Y = 6,031,005.53, ASP 4 NAD27 Pioneer Natural Resources, Alaska is submitting an operational shutdown proposal for AOGCC's review and approval for the ODSN-45i well. Verbal approval was received on Saturday, October 11, 2008. This is the follow up Form 10-403 Sundry Application as requested. As you are aware, Pioneer was planning to suspend this well after installing the 6" x 7-5/8" expandable liner into the top of the Nuiqsut Reservoir. Unfortunately, the 6" expandable liner stuck off bottom and therefore dictates that entire 9-7/8" hole section below the 7-5/8" casing shoe be plugged and abandoned. Pioneer's intent is to still suspend operations on this well with plans to re-enter the well at a later date to sidetrack and redrill to the Nuiqsut reservoir and install another 6" x 7-5/8" expandable liner. This will provide the 6-1/8" hole size required for geo-steer placement of the horizontal lateral in the Nuiqsut reservoir. This specific request is focused on abandonment of the 9-7/8" hole interval below the 7-5/8" casing shoe. 1. The 9-7/8" hole was drilled from the 10-3/4" casing shoe 4973' and to the intermediate TD @ 13866' and in the Nuiqsut formation. 2. A 7-5/8" casing string was stuck off bottom at 11377' and leaving 2489' and exposed. 3. Two 7-1/2" under reamer runs were performed and a 6" expandable liner was RIH to 13822' to cover the shales above the Nuiqsut formation. 4. The liner was cemented and the expansion process was initiated. After approximately 1100' of the liner were expanded, the liner inadvertently was pulled up the hole approximately 1000' md. Attempts were made to run the liner back to TD; however, the liner could not be RIH below 13435' md. 5. The drill pipe was backed off and an RTTS was RIH. A BOPE Test was performed. 6. RIH with drill pipe and tag at 964'. Screw into fish and push down 13,513 before refusal. 11/ Alaska Oil & Gas Conservation Commission October 13, 2008 Page 2 of 3 7. RIH with Halliburton e-line to 1000', no response from CCL, POOH with e-line 8. RIH with severing tool, Pump tool down at 2-3 bbl/min to 10,810. Pressured up to 4500 psi. Unable to move tool up or down. Attempt was made to pull out debris catcher with out success. Note; Severing tool OD of 2.0" was driven (press fit) into debris catcher ID of 2.0" 9. Decision made to fire severing charge, known depth and collar location, (CCL inoperable). Unable to fire gun as igniter was not showing correct voltage drop. 10. Decision made to pull out of rope socket. Pulled with 5,400 lb. Note: At surface no running gear present, confirmed down hole. 11. Decision made to twist off at upper-lower debris sub. Note: At surface twist off confirmed to have occurred at drill pipe cross over sub to debris catcher. The forward plan is to RIH with EZSV retainer, Set at 10,100' MD in 7-5/8" casing, Set cement plug, Suspend operations The proposed operational shutdown plan is as follows 1. RIH with 7-5/8" EZSV and set at 10100' and (1277' MD inside 7-5/8" casing shoe, 706' MD above 6" x 7-5/8" Expandable Liner). Bullhead 79.5 bbl of 15.8 ppg cement below retainer then unsting and lay 2.5 bbl of 15.8 ppg cement on top of the retainer as per 20AAC25.112(b)(2). 2. PU and pressure test the 7-5/8" casing to 4500 psi for 30 minutes -- chart. 3. Displace the 12.5 ppg drilling fluid to 8.5 ppg sea water with corrosion inhibitor. Shut down and observe well for 30 minutes to qualify negative pressure test. 4. POOH with cement stinger. 5. RIH with 2500 feet of 2-7/8" 6.5# L-80 IBT-M tubing and land tubing hanger. 6. Install TWC, ND BOPE and NU and Test Tree. 7. Remove TWC and install surface circulation manifold. 8. Circulate diesel freeze protection into the top 2100' tvd of well 9. RDMO to ODSK-41 well Currently with the expandable liner stuck off bottom, it is not possible to execute the placement of a cement plug to address the P&A requirements for the Nuiqsut hydrocarbon reservoir as per 20AAC25.112(a)(1 or 2). However, Pioneer proposes that the highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section below the liner from 13435' and to the top of the Nuiqsut formation at 13812' and will collapse and effectively seal above the Nuiqsut—qualifying as 20AAC25.112(a)(3). I Alaska Oil & Gas Conservation Commission October 13, 2008 Page 3of3 Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) Documentation on the current well conditions and justification for suspension. 3) A revised operational shutdown wellbore schematic 4) A revised as planned wellbore schematic showing the changes due to the expandable liner and severing charge fish. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joe Polya, Senior Staff Drilling Engineer (20 AAC 25.070) (907) 343-2111 loe.polyana pxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) (907) 343-2133 doug.waters@pxd.com Sincerely, ----911r------ - Joe Polya Senior Staff Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-45i Well File PIONEER NATURAL RESOURCES Pioneer Natural Resources Well Plan ODSN-45i Plug and Abandon Intermediate Section Plan Forward Currently 6"x 6.767" Expandable Casing liner top stuck at—10,806' MD/5239'TVDrkb Live Severing Charge Fish stuck at—10825' MD/5244'TVDrkb Rig Activity: Set EZSV at 10,100' MD in 7-5/8" casing, Set cement plug, suspend operations 1. RIH with 7-5/8"EZSV and set at 10100' and (1277' MD inside 7-5/8" casing shoe, 706' MD above 6"x 7-5/8"Expandable Liner). Bullhead 79.5 bbl of 15.8 ppg cement below retainer then unsting and lay 2.5 bbl of 15.8 ppg cement on top of the retainer as per 20AAC25.112(b)(2). 2. PU and pressure test the 7-5/8" casing to 4500 psi for 30 minutes -- chart. 3. Displace the 12.5 ppg drilling fluid to 8.5 ppg sea water with corrosion inhibitor. Shut down and observe well for 30 minutes to qualify negative pressure test. 4. POOH with cement stinger. 5. RIH with 2500 feet of 2-7/8" 6.5# L-80 IBT-M tubing and land tubing hanger. 6. Install TWC,ND BOPE and NU and Test Tree. 7. Remove TWC and install surface circulation manifold. 8. Circulate diesel freeze protection into the top 2100' tvd of well. 9. RDMO to ODSK-41 well. Currently with the expandable liner stuck off bottom, it is not possible to execute the placement of a cement plug to address the P&A requirements for the Nuiqsut hydrocarbon reservoir as per 20AAC25.112(a)(1 or 2). However, Pioneer proposes that the highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section below the liner from 13435' and to the top of the Nuiqsut formation at 13812' and will collapse and effectively seal above the Nuiqsut—qualifying as 20AAC25.112(a)(3). Rig Activity: Plan forward The plan forward for the ODSN-45i well is to return to the well in the April 2009 timeframe to re- drill the intermediate and drill the lateral. Following the successful drilling of the lateral, a 4-1/2" liner and will be run with injection conformance devices installed to aid in the placement of the injection water. The completion of the well will be in accordance with the approved PTD, with the well construction adjustments included in this document, following the installation of the liner. ODSN-45i Nuiqsut Injector, Junk Left in Hole Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor ` 153'MDrkb/153'TVDrkb 1 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3442'TVDrkb Estimated Top of Cement @ 10100' MD/—5241'TVDrkb Top of 6"liner,10,806"'MDrkb 111 Top of Inner String fish,10,825MDrkb Live Severing Charge W/2.0"OD 7-5/8",29.7#L-80 BTC M,6.875"ID t Debris Catcher,2.0"ID 11377'MDrkb/5412'TVDrkb 12413'MDrkb,Top of Expanded Section, 6",18.6#L-80 Expanded to 6.767"OD,6.19"ID,6.131"Drift Connection unable to hold pressure,13,433 MDrkb _ t"koloi.."61te* Expansion Cone Expandable csg shoe 13,513'MDrkb r 13866'MDrkb/6204'TVDrkb Hole Fill and Un-consolidated Cement Date: Revision By: Comments r,j . 9/22/2008 JDF Proposed Completion v2 10/13/2008 Alex Vaughan P&A Condition ODSN-45i Injector Well Schematic PIONEER NATURAL RESOURCES ODSN-45i Nuiqsut Injector, Proposed P&A Schematic Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor - ` 153'MDrkb/153'TVDrkb 2-7/8"6.5#L-80 IBT-M,2100'TVDrkb ► Diesel to-2100'TVDrkb T Seawater from-2100'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3442'TVDrkb EZSV 10100'MDrkb Estimated Top of Cement @ 10100' _ Cement above packer:2.5bbl/50' MD/-5241'TVDrkb r Cement below packer:79.5bbI/1277'to 7-5/8" shoe+100'w/30%excess bullhead below shoe Top of 6"liner,10,806"'MDrkb It 1 Top of Inner String fish, 10,825MDrkb Live Severing Charge w/2.0"OD 7-5/8",29.7#L-80 BTC-M,6.875"ID Debris Catcher,2.0"ID 11377'MDrkb/5412'TVDrkb , 12413'MDrkb,Top of Expanded Section, / \4 6",18.6#L-80 Expanded to 6.767"OD,6.19"ID,6.131"Drift The highly stressed and unstable HRZ,Kalubik and Miluveach shales in the openhole section \ — below the liner from 13513' and Connection unable to hold pressure,13,433 MDrkb to the top of the Nuiqsut ! Expansion Cone formation at 13812' and will collapse and effectively seal k Expandable csg shoe 13,513'MDrkb above the Nuiqsut—qualifying as `� 20AAC25.112(a)(3) \/ ���lll r 13866'MDrkb/6204'TVDrkb Hole Fill and Un-consolidated Cement 0'C` Date: Revision By: Comments 9/22/2008 JDF Proposed Completion v2 10/13/2008Alex Vaughan P&A Condition ODSN-45i Injector Well Schematic PIONEER - NATURALRESOURCES SARAH PALIN, GOVERNOR ALASKA OIL AND GAS333 W 7th AVENUE SUITE 100 CONSERVATIONCOM1►IISSIOT ANCHORAGE ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G Street, Ste 600 Anchorage AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-45i Sundry Number: 308-366 Dear Mr. Polya: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this2 0day of October, 2008 End. Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 16, 2008 3:04 PM To: 'Vaughan, Alex' Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: RE: Current Oooguruk Well Status as of 10/16/2008 Alex, et al, Thanks much for the updated information. Looking at the information and cross checking our files, I only found one well that may need some paperwork filed; ODSN-39. If no activity is likely on this well until springtime, it is appropriate for Pioneer to file a 404 with attachments for the operational SD as was done with K-35, K-36 and N- 34. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan©pxd.com] Sent: Thursday, October 16, 2008 2:09 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: Current Oooguruk Well Status as of 10/16/2008 Tom, Well Name PTD Completion Date- Comment Status ODSDW 01-44 207-140 1/27/2008 Active Disposal Well ODSK-35 207-181 2/12/2008 Surface Casing Set ODSK-36i 207-182 2/4/2008 Surface Casing Set ODSK-33 207-183 4/29/2008 Active Kuparuk Producer ✓ ODSN-34i 207-184 2/17/2008 Surface Casing Set ODSN-31 208-003 n/a Not Spudded ODSN-32 208-004 n/a Not Spudded J ODSN-40 208-039 8/1/2008 Active Nuiqsut Producer ODSN-39i 208-040 5/7/2008 Surface Casing Set ODSN-45i 208-100 10/15/2008 Intermediate Casing Set, temporarily abandoned, likely to be side tracked ODSN-43 208-139 n/a Not Spudded ODSK-41 208-147 n/a Not Spudded, Spud 10/16/2008 ODSK-38 208-148 n/a Not Spudded ODSN-37 n/a n/a Not Spudded The following is the current schedule as of 10/16/2008. We will be submitting the ODSN-37 Surface Casing Depth Change Sundry middle of next week. Drill Start Das Drill End Date y Date 10/20/2008 Page 2 of 3 ODSN-45i - 1N13 - S,l -AOGCC approved �/ � 3i 74.0 ,-101512008 ODSK-41 A Kup F (Horiz) -S 10/15x0 6.4 10/21/2008 ODSK-38i Kup D (Slant) -S 10/21/2008 5.8 10/27/2008 ODSN-37- PN8 -S 'L10/27,.i r ;' 5.7 11/2/2008 ODSK-381 - Kup D (Slant) - P,C 11/2/2008 15.1 11/17/2008 ODSN-37- PN8 - I 11/17/2008 13.0 11/30/2008 ODSK-41 - Kup F ( oriz) - I,P,C 11/30/2008 32.9 1/2/2009 Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Polya, Joe Sent: Wednesday, October 15, 2008 4:38 PM To: Vaughan, Alex Subject: FW: Current Oooguruk Well Status - Again Alex, Please review the attached and lets make ourselves a duplicate spreadsheet whereby we can track and ensure that we have all the applicable permits submitted and approved for our various wells in their array of stages toward completion. 744444, P-Oe PO-e6/4 Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polyaApxd.com Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Tuesday, October 14, 2008 10:01 AM To: Maunder, Thomas E (DOA); Polya, Joe Subject: RE: Current Oooguruk Well Status - Again Joe, I know you have been busy with ODSN-45, but I would appreciate if you or one of your staff could fill out the table below. Thanks in advance. Tom Maunder, PE AOGCC 10/20/2008 Page 3 of 3 From: Maunder, Thomas E (DOA) Sent: Friday, October 03, 2008 12:00 PM To: Polya, Joe Subject: Current Oooguruk Well Status Joe, As you know, I am reviewing the permit applications for ODSK-41 and -38. In the course of that review, I have prepared a list of the permits issued to date for the Oooguruk project. I realize that Pioneer has encountered drilling difficulties that have resulted in halting operations on some of the wells. Also, halting operations was planned due to the seasonal drilling restriction for some of the Kuparuk wells. Would you or one of the engineers complete the following table for the ODS wells? I have included the information I have available. It is possible that I have not seen all the paperwork that has been filed. I am particularly interested in wells that have been spudded and then operations halted. I expect that we will exchange a few messages to get things all filled out. Call or message with any questions. Tom Maunder, PE AOGCC Well Name PTD Completion Date- Comment Status ODSDW 01-44 207-140 1/27/08 WDSP1 ODSK-35 207-181 ODSK-36 207-182 ODSK-33 207-183 4/29/08 1-oil Initial production well. ODSN-34 207-184 ODSN-31 208-003 ODSN-32 208-004 ODSN-40 208-039 8/1/08 1-oil ODSN-39 208-040 ODSN-45 208-100 ODSN-43 208-139 ODSK-41 208-147 Permit under review ODSK-38 208-148 Permit under review Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 10/20/2008 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 13, 2008 8:08 AM To: 'Polya, Joe' Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: Request for Verbal Approval to MODIFY the Procedure for P&A Intermediate Hole Below 7-5/8" Casing on ODSN-45i -- Re: 20AAC25.112(a&b) 30 - \COC) Joe, I confirm our conversation of last evening. Sorry this reply is delayed. The basic plan submitted by Pioneer to plug the exexpanded liner and 7-5/8" shoe interval is still intended. The retainer has moved shallower, but the cement placement objectives will still be met with the increased volume. 20 AAC 25.112 (A) (1) (C) and 25.112 (c) (1) (C)allow plugging above junk if the objectives of that section are met. We look forward to your filing the sundry. Call or message with any questions. Tom Maunder, PE AOGCC Original Message From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Sunday, October 12, 2008 9:32 PM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; aogcc_prudhoe_bay@admin.state.ak.us Subject: Request for Verbal Approval to MODIFY the Procedure for P&A Intermeidate Hole Below 7-5/8" Casing on ODSN-45i -- Re: 20AAC25.112 (a&b) Mr.Maunder, As per our telephone conversation @ -8:30 pm on Sunday, October 12, Pioneer is requesting approval to modify the Plug and Abandonment Plan that was verbally approved as per attached. We are requesting verbal approval to set the 7-5/8" EZSV just above the 6" unexpanded liner top located at 10805' md. This is approximately 572' and above the 7-5/8" casing shoe @ 11377' md. 51 bbls of cement will be squeezed below the retainer to satisfy the requirements of 20AAC25.112 (b) (3) . A 10-403 will be submitted Monday outlining the specifics regarding the P&A of the 7-5/8" intermediate hole and the operational shutdown for the well. Details: Attempts to retrieve the expandable inner string failed leaving the inner string top of junk 20 feet below the top of the 6" unexpanded liner -- a severing charge was stuck and left in the top of the running tool fish. This inner string fish blocked access to the 6" expanded liner with fishing tools required to cut and retrieve the liner to the 7-5/8" casing shoe depth. Since the liner running and expanding bha was free to rotate, the operations necessary to mill this fish would be difficult at best and probably impossible. As a result, Pioneer is requesting to set the EZSV at the top of the current liner top. Thank you for your time and consideration of this matter. Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources, Alaska 907-244-0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 1 ..._..._. . . Sent: Sat 10/11/2008 2:21 Pr, To: Polya, Joe Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: Request for Verbal Approval to P&A Intermeidate Hole Below 7-5/8" Casing on ODSN-45i -- Re: 20AAC25.112 (a&b) Joe, I acknowledge your call. I have spoken with Commissioner Seamount and he has given his oral approval for you to proceed as proposed. I will look forward to your filing the sundry on Monday. This action should be considered an Operational SD. Call or message with any questions. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Sat 10/11/2008 1:24 PM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; aogcc_prudhoe_bay@admin.state.ak.us Subject: Request for Verbal Approval to P&A Intermeidate Hole Below 7-5/8" Casing on ODSN-45i -- Re: 20AAC25.112 (a&b) Mr. Maunder, To follow up our dicussion regarding the need to P&A the 9-7/8" intermediate hole section below the 7-5/8" casing shoe in the ODSN-45i well -- Pioneer is submitting the attached proposal for your review. Thanks in advance for you consideration and time regarding this matter. I will call to confirm your receipt of this request and attachment. Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources, Alaska 907-244-0668 ********************************************************************** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. ********************************************************************** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 2 October 11, 2008 Re: P&A 20ACC25.112 Mr. Maunder, Pioneer Natural Resources, Alaska is submitting the attached P&A proposal for AOGCC's review and verbal approval for the ODSN-45i well. This will be followed up with the 10-403 Sundry Application on Monday, October 13, 2008. As you are aware, Pioneer was planning to suspend this well after installing the 6"x 7- 5/8" expandable liner into the top of the Nuiqsut Reservoir. Unfortunately, the 6" expandable liner stuck off bottom and therefore dictates that entire 9-7/8"hole section below the 7-5/8"casing shoe be plugged and abandoned. Pioneer's intent is to still suspend operations on this well with plans to re-enter the well at a later date to sidetrack out of the 7-5/8" casing, redrill to the Nuiqsut reservoir and install another 6" x 7-5/8" expandable liner. This will provide the 6-1/8"hole size required for geo-steer placement of the horizontal lateral in the Nuiqsut reservoir. This specific request is focused on abandonment of the 9-7/8"hole interval below the 7- 5/8" casing shoe. I will summarize our discussions over the last couple weeks and provide information regarding the current well conditions as illustrated in Diagram#1 (attached): 1. The 9-7/8"hole was drilled from the 10-3/4" casing shoe 4973' and to the intermediate TD @ 13866' and in the Nuiqsut formation. 2. A 7-5/8" casing string was stuck off bottom at 11377' and leaving 2489' and exposed. 3. Two 7-1/2"under reamer runs were performed and a 6" expandable liner was RIH to 13822'to cover the shales above the Nuiqsut formation. 4. The liner was cemented and the expansion process was initiated. After approximately 1100' of the liner were expanded, the liner inadvertently was pulled up the hole approximately 1000' md. Attempts were made to run the liner back to TD; however,the liner could not be RIH below 13435' md. 5. The drill pipe was backed off at 600' and an RTTS was RIH and a BOPE Test was performed. Currently the rig has completed the BOP Test and has pulled the RTTS and layed down the drill collars. The forward plan is to RIH and screw back into the 4" drill pipe. We are RU wireline with plans to RIH and severe the drill pipe just below the expandable liner running tools. The proposed P&A plan is as follows (refer to P&A Diagram#2—attached): 1. POOH after severing the 4" drill string just above the expandable liner running tools. 2. PU a mechanical cutter and RIH inside the 6"non-expanded liner and perform an internal cut @ 11385' and(8' below the 7-5/8" casing shoe). 3. POOH and PU spear, RIH latch spear and POOH and Lay Down approximately 706' of 6" unexpanded liner. 4. RIB with 7-5/8"EZSV and set at 11325' and(52' and inside 7-5/8"casing shoe). Bullhead 18.5 bbls of 15.8 ppg cement then unsting and lay 3 bbls of 15.8 ppg cement on top of the retainer as per 20AAC25.112(b)(2). 5. PU and pressure test the 7-5/8" casing to 4500 psi for 30 minutes -- chart. 6. Displace the 12.5 ppg drilling fluid to 8.5 ppg sea water with corrosion inhibitor. Shut down and observe well for 30 minutes to qualify negative pressure test. 7. POOH with cement stinger. 8. RIB with 2500 feet of 2-7/8"tubing and land tubing hanger. 9. Install TWC,ND BOPE and NU and Test Tree. 10. Remove TWC and install surface circulation manifold. 11. Circulate diesel freeze protection into the top 2000' tvd of well. 12. RDMO to ODSK-41 well. Currently with the expandable liner stuck off bottom, it is not possible to execute the placement of a cement plug to address the P&A requirements for the Nuiqsut hydrocarbon reservoir as per 20AAC25.112(a)(1 or 2). However, Pioneer proposes that the highly stressed and unstable HRZ, Kalubik and Miluveach shales in the openhole section below the liner from 13435' and to the top of the Nuiqsut formation at 13812' and will collapse and effectively seal above the Nuiqsut—qualifying as 20AAC25.112(a)(3). Thank you for your time and consideration of this matter. I will call you to discuss specifics of this proposed P&A. Please call with any questions or concerns. Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources, Alaska 907-244-0668 joe.polya(apxd.com v in co 0 n N 0, i Z 05 71 - C 'er- n) o. V m c� M y Q.o n 3 ye.. m a • a CD 0) Q Cl) - a. 1 rn X Q • .a I 3 m , f$ a a_ . 03 2. CO m 3 1 ,..41 ka = -93 1 ,1 0 0z m o0 73 ti bis ti 0 ~a n w 1 = c co -, o lfl 3 C \ N tat 1 a t rt c„ Nc P co= a t,i g al f Q., 10 Hs P1.6 :1-1 '-a 0 . g ' t 4)ii 5 1 4 CD o o b -1 N r (�" . tv 1-h O = .°a CD �, Q o N b m .a 1 n o* N1 u2 O al o Q b 0 0 ' t rn c ti hr' Q 1) 01 3 0. / 0 " HI ,in z 1 P.-'o • a I § � ^ : . �� � doi FA 1.-' � � ƒ g % s 0 / Q � © � � ® < z + m \�» ■ .,' O. 14 R z w o I 0 tr co _O % y n _r _. m o a 0 • ' K M 0_ < % o § 7 g - cn a c ■ ■ / 0 7 1 ] _. 7 I \ /§ rn cm tav q q g / \ B. = ] 2 ± F @ ] ƒ Di = & 0- / 0 _ a 0. ) / a b.2 2 co E m % I-, / 2 / / 3 k \ •s § / 0 = Q. g o Iv Et' ~ / a e O R o k / § ■ 0 o - ® a 7 \ f a / a 0.1 ,,,, g.: - ] ■ al III 1a.o co $ k ƒ ra R 02 U 3 � / Page 1 of 7 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 08, 2008 3:54 PM To: 'Polya, Joe' Cc: Regg, James B (DOA) Subject: RE: Updated Request for Waiver to 20 AAC 25.035(e)(1)(C) (ii) -ODSN-45 (208-100) Importance: High Tracking: Recipient Read DO - V00 'Polya,Joe' Regg,James B(DOA) Read: 10/8/2008 3:59 PM Joe, Jim Regg and I have discussed your request and it is acceptable to proceed as you plan. It is encouraging that additional ram sizes especially VBRs will soon be available to use at Oooguruk. Regarding the BOP test, you are correct that midnight Friday is the "witching hour". I would hope that your liner is on depth long before then, however Mother Earth has not looked favorably on Pioneer's attempts to run casing. It may be to your advantage to "hedge your bets" and test. Call or message with any comments. When will you be making up the shoe? Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Wednesday, October 08, 2008 11:37 AM To: Polya, Joe; Maunder, Thomas E (DOA) Subject: RE: Updated Request for Waiver to 20 MC 25.035(e)(1)(C) (ii) Mr. Maunder, One additional item We would not plan to test BOPE prior to running this liner since we expect this operation to be complete prior NLT Friday, 10/10/08 which is when the next BOPE Test is due. 74#t , oPo4a Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya c pxd.com Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Polya, Joe Sent: Wednesday, October 08, 2008 11:33 AM To: 'Maunder, Thomas E (DOA)' Subject: Updated Request for Waiver to 20 MC 25.035(e)(1)(C) (ii) Mr. Maunder, 10/13/2008 Page 2 of 7 As per our telephone conversation, the ODSN-45i well update is as follows: 1. The rig successfully underreamed the hole from TD @ 13866' and to the 7-5/8"casing shoe @10377' md. a. A packoff occurred while reaming right below the shoe and losses were initiated into the Violet 3 fault @ 11405' md. These losses were 300 bbls per hour while circulating with 14.2 ppg EMW and reduced to 150 bph static. 2. The underreamer BHA was run back to TD and experienced some ledging which required additional reaming through a half dozen spots. 3. The trip back to the shoe was uneventful-no issues. Loss rate was -150 bph. 4. An additional trip was performed from the shoe to the TD which went well. 5. The undereamer bha was pooh to shoe with not incident-losses had reduced to-50 bph. a. A 50 bbl 60 ppb Icm pill with 20#each of barafiber, CaCO3 and Steel Seal was spotted at the shoe. 6. The BHA was pulled out of hole with the hole requiring 8 bbls excess fluid over the entire trip (10 hour trip out of hole from shoe). Plan forward is to 1. LD Underreamer BHA#2. 2. RU to Run 6" 2800 feet of expandable liner on 4" drill pipe. 3. See Waiver Request below Waiver Request: JUSTIFICATION: 1. As you are aware, ODSN-45i 9-7/8" hole was drilled from the 10-3/4" surface casing shoe at 4973' and (3482' tvd)to a total depth of 13866' and (6210' tvd). A 7-5/8" casing was then run into the well and stuck off bottom at 11392' and (-2500'off bottom)and cemented in place. • The Torok Disposal Zone is currently behind the 7-5/8"casing (10042' and to 10700' md). • The Kuparuk Formation was absent in this well --eroded at the Lower Cretaceous Unconformity. • The Nuiqsut is exposed 40' at the total depth of the well from 13826' and to 13866' and -data has been provided that demonstrates that the Nuiqsut is tight sand with low permeability and viscous oil which is not capable of flow to surface unassisted. • The pore pressure of the Nuiqsut is 9.6 ppg EMW and the current MW in the hole is 12.6 ppg. ■ A wiper trip was made and the drilling bha was pulled from the total depth after TD and there was no signs of swabbing and hole fill was correct. 2. The Nabors 19AC rig is currently RIH with a clean out assembly to drill out the float track and clean the hole out to TD. 3. Approximately 2850'of 6"expandable liner will be made up and RIH. This liner will then be run to total depth @ 13866 on 4"drill pipe. 4. In the unlikely event the well were to start flowing: A crossover made up to an open floor safety valve will be readily available on the floor--this will be made up. ncRin The annular preventer will be closed around the pipe. 0cqn A stand of 4"drill pipe will be made up. 1143 The closure pressure on the annular will be reduced and the liner run into the hole to place the 4"drill pipe adjacent to the pipe rams-this will allow the well to be shut in on the pipe rams 1. If it were necessary to POOH with the liner and the well showed tendency to swab due to the plunger effect, the liner could be pumped out of the hole to replace fluid for metal and fluid displacment. 10/13/2008 Page 3 of 7 In conclusion, Pioneer has an extremely high confidence level that this operation can be safely executed without harm to personnel or the environment and without damage to facilities or equipment. As stated above, Pioneer will order the 6" ram blocks, rubber elements and top seals to ensure that future 6" expandable liners can be run in compliance with 20 AAC 25.035(e)(1)(C)(ii). Thanks in advance for your consideration in this matter. Pe P(44 Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya@pxd.com Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Polya, Joe Sent: Friday, October 03, 2008 4:18 PM To: Maunder, Thomas E (DOA) Subject: RE: Request for Waiver to 20 AAC 25.035(e)(1)(C) (ii) Bank to Bank: • 0430 on 9/26 MU underreamer bha#1 • 0600 on 10/2 LD underreamer bha#2 • 6 days 1-1/2 hrs. Note: Hole had been open with not trips for 12+ days. A good portion of this time was spent fighting tight hole. Actual Back Ream: • 08:30 on 9/28 Start Underreaming @ 13866' and TD. • 14:30 on 9/29 Back Ream to 11750' and • 1 day 6 hrs. We are still trouble shooting electrical we are at the shoe ready to RIH as outlined below. 74vied, Poe Po Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya(ci)pxd.com Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 10/13/2008 Page 4 of 7 Mobile: (907) 244-0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, October 03, 2008 3:21 PM To: Polya, Joe Subject: RE: Request for Waiver to 20 AAC 25.035(e)(1)(C) (ii) Joe, I know we have discussed timing. I am curious, how long did the first underreaming run take, bank-to-bank? Tom From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Friday, October 03, 2008 10:32 AM To: Maunder,Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; Guszregan, Sylvester; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: Request for Waiver to 20 AAC 25.035(e)(1)(C) (ii) Mr. Maunder, Per our conversation this morning, • Operations Update o Currently at the 7-5/8" casing shoe with our 2nd 7-1/2" underreamer bha run. • First underreamer bha-underreamed from TD @ 13866' and upward to 12750' and (1116' and interval). • Hole Section remaining to be underreamed from 12750' and to 7-5/8" casing shoe @ 11377' and (1373' and interval). o Perform Wiper Trip-Spot lubricated pill on bottom. o Pooh and LD underreamer bha#2. o RU and RIH with 6" expandable liner. o RIH with 4" drill pipe, Pressure test well to 4500 psi for 30 minutes. o Displace well to SW and then monitor static for 30 minutes to ensure negative pressure test. o Pooh, RIH with 2500' of 3-1/2"tubing. o Land tubing hanger, RILD screws and test. Install BPV, ND BOPE and Install Tree. o Remove TWC, Install TWC, test tree. Remove TWC and circulate diesel freeze protect in top 2500' of well. o RDMO to ODSK-41 K well. • We will still need a waiver to run the 6" expandable liner. o Status on 6" ram blocks. Hydril found a set of ram blocks in Canada that can be bored out to 6" and I have executed this order(see attached). The only other option as we discussed is that Hydril is working on the design for VBR's that could cover this size; however, these are -4 to 6 months out. Currently it looks as if we could be running liner as early as Sunday, October 5th. Again, thank you for your consideration of the waiver request- I will keep you updated regarding any changes to this plan. Waded, 10/13/2008 Page 5 of 7 poe Pam Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya a,pxd.com Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Polya, Joe Sent: Friday, September 26, 2008 9:10 PM To: Maunder,Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; Guszregan, Sylvester; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: Request for Waiver to 20 MC 25.035(e)(1)(C) (ii) Mr. Maunder, One additional item I forgot to mention, the BOPE was tested today 9/26 with 4" ram block in both pipe rams -- see attached. From: Polya, Joe Sent: Fri 9/26/2008 8:58 PM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Hazzard, Vance; Cody, Rick; Franks, James; Guszregan, Sylvester Subject: Request for Waiver to 20 MC 25.035(e)(1)(C) (ii) Mr. Maunder, REQUEST: As per our telephone conversation, Pioneer is requesting a waiver to run -2850 lineal feet of 6" expandable liner without utilizing 6"pipe blocks in the pipe rams as required in 20 AAC 25.035(e)(1)(C)(ii). SITUATION: 1. There is not a set of 6" ram blocks available anywhere at the present time: • Hydril thought they had a set of 6" ram blocks available in Houston; unfortunately, it turns out that these rams were bored out to 8-5/8" size to satisfy another request. There are no other 6" ram blocks available through Hydril anywhere in the world at the present time. • I checked with BOP Ram Rental, Allis Chalmers and Variable Bore Rams Rental in Lafayette, LA and none of these companies have or know of anyone with a set of 6" ram blocks available. • As you are aware, Hydril does not make variable bore rams for the 11" 5M stack; however, they are designing and manufacturing the 3-1/2"x 6"size; however, these will not be available for another 6 months or so. 2. I will have Hydril provide a set of 6" ram blocks, rubber elements and top seals for future jobs; however, this will require boring out a smaller ram block which will take at best 5 days to locate, machine, test and ship which is not a option for this well. I will instruct Hydril to do this on Monday so we have a set for future. Lead time to manufacture a new 6" ram block is several weeks. 10/13/2008 Page 6 of 7 JUSTIFICATION: 2. As you are aware, ODSN-45i 9-7/8" hole was drilled from the 10-3/4"surface casing shoe at 4973' and (3482'tvd)to a total depth of 13866' and (6210'tvd). A 7-5/8"casing was then run into the well and stuck off bottom at 11392' and (-2500' off bottom)and cemented in place. • The Torok Disposal Zone is currently behind the 7-5/8"casing (10042' and to 10700' md). • The Kuparuk Formation was absent in this well --eroded at the Lower Cretaceous Unconformity. • The Nuiqsut is exposed 40'at the total depth of the well from 13826' and to 13866' and --data has been provided that demonstrates that the Nuiqsut is tight sand with low permeability and viscous oil which is not capable of flow to surface unassisted. • The pore pressure of the Nuiqsut is 9.6 ppg EMW and the current MW in the hole is 12.6 ppg. • A wiper trip was made and the drilling bha was pulled from the total depth after TD and there was no signs of swabbing and hole fill was correct. 3. The Nabors 19AC rig is currently RIH with a clean out assembly to drill out the float track and clean the hole out to TD. 4. Approximately 2850'of 6"expandable liner will be made up and RIH. This liner will then be run to total depth @ 13866 on 4"drill pipe. 5. In the unlikely event the well were to start flowing: 174) A crossover made up to an open floor safety valve will be readily available on the floor-this will be made up. B43 The annular preventer will be closed around the pipe. 14) A stand of 4"drill pipe will be made up. 043 The closure pressure on the annular will be reduced and the liner run into the hole to place the 4"drill pipe adjacent to the pipe rams-this will allow the well to be shut in on the pipe rams 6. If it were necessary to POOH with the liner and the well showed tendency to swab due to the plunger effect, the liner could be pumped out of the hole to replace fluid for metal and fluid displacment. In conclusion, Pioneer has an extremely high confidence level that this operation can be safely executed without harm to personnel or the environment and without damage to facilities or equipment. As stated above, Pioneer will order the 6" ram blocks,rubber elements and top seals to ensure that future 6" expandable liners can be run in compliance with 20 AAC 25.035(e)(1)(C)(ii). Thanks in advance for your consideration in this matter. Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources, Alaska 907-244-0668 10/13/2008 STATE OF ALASKA 11/28/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: - Contractor: Nabors Rig No.: 19AC DATE: 9/26/2008 Rig Rep.: Jim West Rig Phone: 670-6630 Rig Fax: 670-6673 Operator: PNRA Op. Phone: 670-6606 Op.Fax: 670-6673 Rep.: Jim Brown Field/Unit&Well No.: Oooguruk/ODSN-45i PTD# 208-100 Operation: Drig: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly x Test Pressure: Rams: 250/4,5000 Annular: 250/3,500 Valves: 250/4,500 TEST DATA MISC.INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P DrI. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 FP Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 11" P Quantity Test Result Pipe Rams 1 4" P No.Valves 14 P Lower Pipe Rams 1 4" P Manual Chokes 1 P Blind Rams 1 P Hydraulic Chokes 1 P Choke Ln.Valves 1 3-1/8" P HCR Valves 2 3-1/8" P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8" P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 2050 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 19 Sec. P Trip Tank P P Full Pressure Attained 1 min 41 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles(avg): 5x© 1750 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time: 5 Hours Components tested 28 Repair or replacement of equipment will be made within N/A days. Notify the North Slope Inspector 659-3607,follow with written confirmation to Superviser at: Remarks: Tested choke manifold as tripping out of hole.Testing TIW valve failed cont.to test with Inside BOP.Then Change out TIW Valve Tested 250 psi&4500psi 5min ea. 24 HOUR NOTICE GIVEN YES Yes NO Waived By Lou Gamaldi Date 09/26/08 Time 6:00 Witness Steve Beard/Jeff Clark Test start 22:30 Finish 3:30 BOP Test(for rigs) BFL 11/28/07 BOP Test Nabors 19AC 9-26-08.xls 'llnifE SARAH PALM,GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 James Franks Senior Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G. Street Ste 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk-Nuiqsut Oil Pool, ODSN-45i Sundry Number: 308-340 Dear Mr. Franks: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Of Daniel T. Seamount, Jr. Chair DATED this `Sday of September, 2008 End. I .".VGs VCL) STATE OF ALASKA , F"._f' 2 3 2008/ OaQ ALASr'H OIL AND GAS CONSERVATION COMMIoSION ��� ,iii ��'' APPLICATION FOR SUNDRY APPROVALSi, 20 AAC 25.280 1.Type of Request: Abandon❑ Suspend ❑ Operational shutdown Q Perforate ❑ Waiver❑ Other❑ Alter casing❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program Q Pull Tubing❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: is, 5. Permit to Drill Number: �, Pioneer Natural Resources Alaska Inc. Development . 0 Exploratory p • 208-100/308-329 3.Address: Stratigraphic ❑ .011 Service Service I .§.API Number: it 700 G Street,Suite 600 Anchorage,AK 99501 P,�y*t7P 50-703-20577-00- 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ElNo I=1 ODSN-45u 9.Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 355037/ADL 355036 57.12' MSL • Ooogurk- Nuiqsut Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13866 6210 11394 5462 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 4820' 10-3/4" 4973' 3438' 5210 2470 Intermediate 11350' 7-5/8" 11395' 5462' 6890 4790 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open Hole N/A Packers and SSSV Type: Packers and SSSV MD(ft): N/A N/A 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Development ❑., Service ❑ 15. Estimated Date for 16.Well Status after proposed work: 9/23/2008 Commencing Operations: Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ E WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya,343-2111 Printed Name James Franks Title Senior Drilling Engineer Signature Phone Date 343-2179 9/23/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SundryNumber: A? — D Plug Integrity ❑ BOP Test gs Mechanical Integrity Test ❑ Location Clearance ❑ Other: c\kC.-ct'.4,'i c- `-A\ ®A,, vJ\-\C v, ©r_(-G.-`�l-,S Q..0 e\,--y SU Subsequent Form Required: LkO1 t /� `i �\� Q, _ -0 P\ ��� oh\, (\_APPROVED BY ,e-t.) V� p Approved by: , / COMMISSIONER THE COMMISSION Date: 7/2 s/ `' Form 10-403 Revised 06/2006 J ® 1 G I NI A L RBOMS DFL SEP 2 b 2O Submit in Duplicate y 7./•es P4I 0 N E eR NATURAL RESOURCES September 23, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry Notice for casing and completion design change and operational shutdown of ODSN-45i — previous Sundry# 308-329 Surface Location: 2,889' FSL, 1176' FEL, Sec. 11, T13N, R7E, UM X = 469,821.86; Y = 6,031,005.53, ASP 4 NAD27 Pioneer Natural Resources Alaska has had to change the casing design plan on the ODSN-45i (PTD#208-100) due to our inability to get the 7-5/8" intermediate casing to drilled TD of 13,866' MD. The 7-5/8" casing is currently set at 11,392' MD. Multiple attempts to free the pipe were - unsuccessful and as such, PNRA is planning to cement the casing where it is. The plan forward is to regain the hole already drilled to 13,866' and set a cemented, expandable liner from TD to inside the 7-5/8" intermediate casing string and then continue with an /operational shutdown of the well. The operational shutdown of the well is due to the need to install a 4-1/2" liner w/ Injection Conformance Devices in the 6-1/8" horizontal lateral of the Oooguruk-Nuiqsut to aid in the efficient placement of injection water—this lateral was originally planned for an openhole completion. Unfortunately the liner casing and hardware (ICD's, Swell Packers, Liner Hanger and Packer) are long lead items which are currently not in Pioneer's inventory and are the primary reason for this operational shutdown request. 1' The plan is to move the rig back onto the well in April 2009 to drill and case the lateral and run the completion. With the addition of the expandable liner, the 4-1/2" liner is now going to be planned to cover the expandable and be hung off in the 7-5/8" casing. For the operational shutdown, the 7-5/8" casing and the expandable liner will be pressure tested to 4500 psi for 30 minutes and a negative test will be performed by monitoring the well with sea water for 30 minutes to ensure it is static. Later a freeze protect 2-7/8" or 3-1/2" tubing string will be run to 2500' MD, the BOPE removed and the tree installed, and then the well will be freeze protected to —2000' TVD. Alaska Oil & Gas Conservation Commission September 22, 2008 Page 2 of 2 As previously discussed, Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to amend the planned completion and perform and operational shutdown on ' ODSN-45i after the setting of the expandable drilling liner. Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) Documentation on the current well conditions and justification for suspension. 3) A revised operational shutdown wellbore schematic 4) A revised as planned wellbore schematic showing the changes due to the expandable liner The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report James Franks, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2179 iames.franks a(�pxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) (907) 343-2133 douq.waterstc'Dpxd.com Sincerely, James Franks Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-45i Well File PIONEER NATURAL RESOURCES Pioneer Natural Resources Well Plan ODSN-45i Amended Well Construction and PlanOperational Shutdown Plan Forward Currently 7-5/8" Casing stuck at-11,392' MD 15460' TVDrkb As Drilled TD -13866' MD/ 6204' TVDrkb Rig Activity: Cement the 7-5/8" casing, recover the 9-7/8" hole, set expandable liner and suspend operations 1 Cement the 7-5/8", 29.7# intermediate casing at 11,392'. Bump the plug with 500 psi over max pump pressure seen during the job using 11.5 ppg drilling fluid. Hold pressure for- 5minutes. Release pressure and ensure floats are holding. Note: The casing will not be pressure tested at this time and will be tested after the cement has set up 2. LD 5" DP from the derrick utilizing the mousehole. 3. PU and RIH with 4" DP and stand back in the derrick. 4. Test the BOPE to 250/4500 psi 5. Pressure test the 7-5/8" casing to 4500 psi-chart and hold for 30 minutes 6. MU BHA with 6-3/4" bit, BAT sonic and 7.5" Hole Opener and RIH to the float collar. Drill out the shoe track and cleanout the 9-7/8" hole to TD @ -13866' MD. 7. Activate the Hole Opener and backream out of the hole to the intermediate casing shoe. Note: The hole opener is there to ensure that the hole is >7.5" for the running and cementing of the expandable liner 8. Mad Pass the casing shoe interval with the BAT sonic tool in recorded mode to get cement quality data. 9. PU the 6" x 7-5/8" expandable liner and RIH on 4" DP to TD 10. Cement the casing from TD to the 7-5/8" intermediate casing shoe. Expand the liner and the liner top. 11 POH Standing back 4" DP. LD Expandable Launcher. 12. Pressure test the 7-5/8" casing and expandable liner to 4500 psi-chart and hold for 30 minutes. 13. MU Mule Shoe on 4" DP and RIH from the derrick to the expandable liner shoe 14. Displace the well over to Seawater Monitor the well for 30 minutes. 15 POH LD 4" DP. 16. RIH with -2500' MD of 2-7/8" or 3-1/2" tubing. 17. Land the tubing and RILDS. 18. Install TWC. 19. ND BOPE, NU tree and test to 5,000 psi. 20. Pull TWC. 21. Reverse circulate diesel to freeze protect the well to -2000' TVD and allow to u-tube. 22. RDMO to ODSN-43. PIONEER - NATURAL RESOURCES Pioneer Natural Resources Well Plan ODSN-45i Amend.d Well Construction and PlanOperational Shutdow Plan Forward Current 7-5/8" Casing stuck at—11,392' MD/5460' TV' rkb s Drilled TD —13866' MD/6204'TVDrkb Rig Activity: Cement the 7- 8" casing, recover the 9-7/8" hole, set -xpandable liner and suspend operations 1. Cement the 7-5/8", 29.7 'ntermediate casing at 11,392'. Bu p the plug with 500 psi over max pump pressure -en during the job using 11.5 pp, drilling fluid. Hold pressure for•-5minutes. Release pr- .sure and ensure floats are h'-Iding. Note: The casing will not be p -ssure tested at this time -nd will be tested after the cement has set up SUPERSEDED) 2. LD 5" DP from the derrick utilizing he mousehole. 3. PU and RIH with 4" DP and stand back in the derric . 4. Test the BOPE to 250/4500 psi 5. Pressure test the 7-5/8"casing to 4505 .si—ch- and hold for 30 minutes 6. MU BHA with 6-3/4" bit, BAT sonic and 5" H. e Opener and RIH to the float collar. Drill out the shoe track and cleanout the 9-7/8' o - to TD @ —13866' MD. 7. Activate the Hole Opener and backream ou of the hole to the intermediate casing shoe. Note: The hole opener is there to ensure a he hole is >7.5"for the running and cementing of the expandable liner. 8. Mad Pass the casing shoe interval wit the BAT onic tool in recorded mode to get cement quality data. 9. PU the 6"x 7-5/8"expandable liner :nd RIH on 4" D- to TD 10. Cement the casing from TD to the -5/8" intermediate asing shoe. Expand the liner and the liner top. POH above the top of the expandable lin= 11. Pressure test the 7-5/8"casing :nd expandable liner to 4,00 psi—chart and hold for 30 c_ minutes. 0 12. POH LD 4" DP. 13. RIH with remaining 4"fro the derrick and LDDP _ 14. Pressure test the 7-5/8" 'Using and expandable liner to 4500 ps —chart and hold for 30 minutes. 15. RIH with —2500' MD . 2-7/8"or 3-1/2"tubing. 16. Land the tubing and "ILDS. 17. Install TWC. 18. ND BOPE, NU tr•e and test to 5,000 psi. 19. Pull TWC. 20. Reverse circ ate diesel to freeze protect the well to —2000'TVD and allow .1 u-tube. 21. RDMO to ••SN-43. PIONEER NATURAL RESOURCES Rio Activity: Plan forward The plan forward for the ODSN-45i well is to return to the well in the April 2009 timeframe to drill the lateral as planned in the approved Permit to Drill, 208-100. Following the successful drilling of the lateral, a 4-1/2" liner and will be run (liner top to be above the expandable liner top)with injection conformance devices installed to aid in the placement of the injection water. The completion of the well will be in accordance with the approved PTD, with the well construction adjustments included in this document, following the installation of the liner. ODSN-45i Nuiqsut Inj Proposed Suspension w/Expandable Liner Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor 153'MDrkb/153'TVDrkb 3-1/2",9.3#L-80 TSHP Or Diesel to-2000'TVDrkb 2-7/8"6.5#L-80 IBT-M _ Tubing to-2500'MD 10-3/4",45.5#L-80 BTC,9.95"ID 4973'MDrkb/3442'TVDrkb Seawater from-2000'TVDrkb Estimated Top of Cement @ 10900' MD 1-5310'TVDrkb 7-5/8",29.7#L-80 BTC-M,6.875"ID 11392'MDrkb/5460'TVDrkb 6",18.6#L-80 Expanded to 6.767"OD, 6.19"ID,6.131"Drift 13866'MDrkb/6204'TVDrkb Date: Revision By: Comments 9/22/2008 JDF Proposed Suspension Completion v2 Y'jr Z•a. ODSN-45i Injector Suspension Well Schematic PIONEER NATURAL RESOURCES ODSN-45i Nuiqsut lnj Proposed Completion w/Expandable Liner Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor ` 153'MDrkb/153'TVDrkb 3-1/2"ScSSSV,2.813"ID @—750' —143-1/23,-.1m/2m" 2"MMG GLM @ 4638'MD/3330'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 1 4973'MDrkb/3442'TVDrkb 3-1/2",9.3#L-80 TSHP J4— 3-1/2"MMG GLM @ 10950'MD � •00 3-1/2"Sliding Sleeve @ 11100'MD X Nipple,2.813"ID 7-5/8"x 3-1/2"Retrievable Packer @-11150'MD Estimated Top of Cement @ 10900' MD/—5310'TVDrkb 7-5/8"x 4-1/2"Liner Top Hanger/Packer @-11200'MD I P, I 7-5/8",29.7#L-80 BTC-M,6.875"ID 11392'MDrkb/5460'TVDrkb X Nipple,2.813"ID w/RHC-M Plug XN Nipple,2.725"ID Nogo @—11400' 13866'MDrkb/6204'TVDrkb 4-W Solid Liner with Flow 6",18.6#L-80 Expanded to 6.767"OD, Conformance devices 6.19"ID,6.131"Drift \ O 0 0 0 0 0 O 0 0 0 0 0 O 0 0 0 0 0 �� J 20725'MDrkb/6267'TVDrkb Date: Revision By: Comments �tjt ' 9/22/2008 JDF Proposed Completion v2 ': ODSN-45i Injector Well Schematic PIONEER NATURAL RESOURCES Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 24, 2008 9:14 AM To: Regg, James B (DOA) Subject: FW: ODSN-45i (PTD 208-100) Attachments: Daily Drilling Reports.zip From: Franks,James [mailto:James.Franks@pxd.com] Sent: Tuesday, September 23, 2008 5:08 PM To: Maunder,Thomas E (DOA) Cc: Polya, Joe; OoogurukDrillingSupervisor Subject: ODSN-45i (PTD 208-100) Tom, As requested, here are the drilling reports from the BOPE test prior to drilling out the surface casing until now. Let me know if there is anything else I can help with. CA AL-k—OSS- Take care, james Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 7/27/2009 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 23, 2008 4:44 PM To: 'OoogurukDrillingSupervisor' Cc: 'Polya, Joe'; 'Franks, James'; 'Vaughan, Alex' Subject: RE: Request ODSN-45 (208-100) From: OoogurukDrillingSupervisor [mailto:OoogurukDrlgCm@pxd.com] Sent: Tuesday, September 23, 2008 4:43 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Franks, James; Vaughan, Alex Subject: RE: Request ODSN-45 (208-100) Tom, had diverter waiver on well, so no BOP test until after drilling our surface casing, but understand what you are requesting, (long day myself, &will have Joe Polya, (or Town Engineer), e-mail all the daily reports to you in morning..,.:,...JB From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 23, 2008 4:22 PM To: OoogurukDrillingSupervisor; DOA AOGCC Prudhoe Bay Cc: Polya, Joe; Franks, James Subject: RE: Request ODSN-45 (208-100) Jim, et al, One further request; please provide the drilling reports for this well beginning with the BOP test prior to drilling out surface casing. Email is fine. Thanks in advance. Tom Maunder, PE AGOCC From: OoogurukDrillingSupervisor [mailto:0oogurukDrlgCm@pxd.com] Sent: Tuesday, September 23, 2008 4:00 PM To: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Cc: Polya, Joe; Franks, James; Vaughan, Alex; Clark, Jeff; Scales, Nick; Klepzig, Rod; Bob Finkbiner; Beard, Steve; West, James L. Subject: Re: Upcoming BOPE Test for Nabors 19-AC Tom, per conversation w/Joe Polya, the rig will continue to LD the 5" DP, & at which time is completed, rig up to pressure test, & close the Blind rams to perform the casing test to 4,500psi (.5hr), &chart same. As long as test results satisfactory, will then rig to & PU 4" DP&single in hole, pump through pipe to ensure clear& hoist/rack back. A full BOPE test will then be performed, (Notify AOGCC representative tomorrow w/closer test time), prior to MU next assembly in the Hole to drill out shoe track&clean out run to bottom. If there is something I have missed, or not satisfactory in detail, please call or e-mail myself back, &will deal with it in prudent fashion. Thank you for time &attention to this matter......JB Jim Brown Rig Supervisor: Gravel, Snow, & Shallow Water Pioneer Natural Resources (Alaska), Inc. Anchorage Office# 1-907-277-2700 7/27/2009 Page 2 of 2 Home# 1-403-547-0825 E mail: jim.brown@pxd.com Pioneer Camp On Ooogurak Island, AK Office# 1-907-670-6606/6609 Fax# 1-907-670-6673 Pioneer/Cruz Camp @ Hansen-Anchor Pt., AK Office# 1-907-226-2180 *New Contact Numbers* This email was sent on 9/23/08 at 4:00 PM by brownji. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. This email was sent on 9/23/08 at 4:42 PM by brownji. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 7/27/2009 Page 1 of i Maunder, Thomas E (DOA) From: Franks, James [James.Franks@pxd.cor] Sent: Tuesday, September 23, 2008 1:28 PM To: Maunder, Thomas E (DOA) Subject: RE: ODSN-45i (PTD 208-100)Well Construction change and Operational Shutdown (Sundry 308- 329) Tom, It always seems that I am apologizing for the delay in my reply„. We do not need to isolate the expandable from the stand of the effects of injection;we are planning to set the 4- 1/2" liner over the top of the expandable simply because the expandable cannot handle the collapse if the pipe were to be totally evacuated, As this is an injector, this should not happen, but you never know. My thinking on this is if we cover the expandable with the 4-1/2" liner(without cementing the 4-1/2"x expandable annulus)and the pipe were to become totally evacuated, the expandable might collapse on the 4-1/2", but that the 4-1/2"would hold it back: Of course, at the end of the day,we still want to do all we can to ensure that we can inject into the Oooguruk- Nuiqsut and feel confident all other zones are isolated, Thanks for your time. I am in the process of performing the edits on the 10-403 and should have it over this afternoon, At this point, we have cemented the 7" in place at 11,392'and are performing some drill pipe management, james James Franks Sr. Drilling Engineer Pioneer Natural Resources Alaska 907,343 2179 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 23, 2008 10:01 AM To: Franks, James Subject: RE: ODSN-45i (PTD 208-100) Well Construction change and Operational Shutdown (Sundry 308-329) James, I have not had a chance to view the latest information you provided this morning, I suspect the sundry will be arriving later this morning, With regard to the expandable liner and then hanging the 4-1/2"through it; you have stated the intent in doing this is to isolate the expandable from the active injection. Based on the drawing, it would appear that in order to accomplish this that you will likely have to do the Banzai or provide some other deeper sealing device to isolate the expandable. Is my understanding correct? I look forward to your reply, Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks@pxd.com] Sent: Monday, September 22, 2008 3:28 PM To: Maunder, Thomas E (DOA) Subject: RE: ODSN-45i (PTD 208-100) Well Construction change and Operational Shutdown (Sundry 308-329) oc 7/27/2009 ..... . . ....... Page 2 of/ Sorry for the delay in my reply... The cementing of the expandable liner is just to ensure that we have isolation of the Nuiqsut from the 7-5/8° shoe and to bind it to the formation. The expandable has an expanded burst rating of 6150 psi and a collapse rating of 2760 psi. In a production case, we do not feel that the expandable can stand up—based on collapse—if there was total evacuation of the pipe. As such, we will be covering the expandable in its entirety with a 4-1/2"liner. I have not figured out if we will cement the portion of the 4-1/2"liner that covers the expandable— Banzai style.„ Injection pressure will have no effect on the expandable liner. Certainly we would like to keep the It)of the string and would prefer to not have to set the packer inside the 4-1/2" "cover up" liner. What do you think? james James Franks Sr. Drilling Engineer Pioneer Natural Resources Alaska 907.343 2179 From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Monday, September 22, 2008 2:26 PM To: Franks, James Subject: RE: ODSN-45i (PTD 208-100) Well Construction change and Operational Shutdown (Sundry 308-329) James, If I remember our conversation this morning, you will be cementing the expandable liner due to burst or collapse concerns, is that correct?? I am uncertain regarding your plan to set the packer above the expandable liner. Is this to preserve ID? How will the injection pressure affect the expandable I look forward to your reply. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks@pxd.com] Sent: Monday, September 22, 2008 2:21 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Vaughan, Alex; Hazzard, Vance; Polya, Joe Subject: ODSN-45i (PTD 208-100) Well Construction change and Operational Shutdown (Sundry 308-329) Tom, I have attached 2 drawings to this e-mail for you to see. The first drawing is of the condition PNRA would like to leave the well in while we wait on materials for our horizontal. The second drawing is the condition we would like to leave the well in and still be able to inject into the Oooguruk-Nuiqsut. I am still working on the procedural summary and will be able to send it soon, but I wanted to make sure you had a chance to see these. As I said on the phone, we will be running the HES BAT Sonic tool to get a Cement Quality Log over the 7-5/8" shoe so we can set our completion packer above the top of the expandable liner and in an interval with cement behind pipe. More to follow. Thanks for your time. james 7/27/2009 ODSN-45i Nuiqsut Inj Proposed Suspension w/Expandable Liner Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor , 153'MDrkb/153'TVDrkb 3-1/2",9.3#L-80 TSHP j Or Diesel to-2000'TVDrkb 2-7/8"6.5#L-80 IBT-M „�.,. _ Tubing to-2500'MD 10-3/4",45.5#L-80 BTC,9.95"ID OIL 4973'MDrkb/3442'TVDrkb r Seawater from-2000'TVDrkb Estimated Top of Cement @ 10900' MD/-5310'TVDrkb 7-5/8",29.7#L-80 BTC-M,6.875"ID 11400'MDrkb/5462'TVDrkb 6",18.6#L-80 Expanded to 6.767"OD, 13866'MDrkb/6204'TVDrkb 6.19"ID,6.131"Drift Date: Revision By: Comments 9/22/2008 JDF Proposed Suspension Completion v2 ODSN-45i Injector Suspension Well Schematic PIONEER ODSN-45i Nuiqsut Inj Proposed Completion w/Expandable Liner Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal L 16"Conductor AI 153'MDrkb/153'TVDrkb _-----' 3-1/2"ScSSSV,2.813"ID @—750' I 24 i 3-1/2"MMG GLM @ 4638'MD/3330'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID V. 4973'MDrkb/3442'TVDrkb 3-1/2",9.3#L-80 TSHP jig L 3-1/2"MMG GLM @ 10950'MD 0 0 0-4 3-1/2"Sliding Sleeve @ 11100'MD X Nipple,2.813"ID 7-5/8"x 3-1/2"Retrievable Packer @-11150'MD Estimated Top of Cement @ 10900' _ MD/—5310'TVDrkb ._. ._. 7-5/8"x 4-1/2"Liner Top Hanger/Packer @-11200'MD 7-5/8",29.7#L-80 BTC-M,6.875"ID 11400'MDrkb/5462'TVDrkb X Nipple,2.813"ID w/RHC-M Plug XN Nipple,2.725"ID Nogo @—11400' 13866'MDrkb/6204'TVDrkb ' 4-'/z"Solid Liner with Flow 6",18.6#L-80 Expanded to 6.767"OD, Conformance devices 6.19"ID,6.131"DriftAV 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 - 20725'MDrkb/6267'TVDrkb / `,,. Date: Revision By: Comments i • \\ 9/22/2008 JDF Proposed Completion v2 (' ODSN-45i Injector �� Well Schematic PIONEER SARAH PAL1N, GOVERNOR ALASKA OIL AND GAS333 W 7th AVENUE,SUITE 100 CONSERVATIONCOM IISSJT o ANCHORAGE ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 James Frank Senior Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Ooo g uruk Field, Nuiqsut Oil Pool, ODSN-45i \�\O-0q Sundry Number: 308-329 Dear Mr. Frank: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 1 � Daniel T. Seamount, Jr. Chair DATED this day of September, 2008 Encl. PIONEER NATURAL RESOURCES E REGI .SEPI 2 2008 Alaska Oil& Gas Cons. Anchorage Commiss;�. September 12, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 42:2)^7) „- II RE: Application for Sundry Notice to sODSN-45i Surface Location: 2,889' FSL, 1176' FEL, Sec. 11, T13N, R7E, UM X = 469,821.86; Y = 6,031,005.53, ASP 4 NAD27 Pioneer has elected to install a 4-1/2" liner w/ Injection Conformance Devices in the 6-1/8" horizontal lateral in the Oooguruk-Nuiqsut to aid in the efficient placement of injection water— this lateral was originally planned for an openhole completion. Unfortunately the liner casing and hardware (ICD's, Swell Packers, Liner Hanger and Packer) are long lead items which are currently not in Pioneer's inventory and are the primary reason for this suspension request. The plan is to move the rig back onto the well in April 2009 to drill and case the lateral and run the completion. The 7-5/8" intermediate casing will be run into the well, cemented and drilling fluid displaced out of the well with sea water. A positive casing test to 4500 psi for 30 minutes and a negative test will be performed by monitoring the well with sea water for 30 minutes to ensure it is static. Later a freeze protect 2-7/8" or 3-1/2" tubing string will be run to 2500' MD and a diesel cap installed — the well will be monitored for 30 minutes to ensure it is static prior to installing the tree and a BPV. As previously discussed, Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to suspend ODSN-45i after the intermediate hole section. The remainder of the completion will be in accordance to the approved Permit to Drill (208-100). Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) Documentation on the current well conditions and justification for suspension. 3) Current condition wellbore schematic 4) As suspended wellbore schematic 5205 N.O'CONNOR BLVD, SUITE 200 - IRVING,TEXAS 75039-3746 - MAIN 972-444-9001 - FAX 972-969-3587 Alaska Oil & Gas Conservation NEER September 12, 2008 jj Page 2 of 2 NATURAL RESOURCES The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report James Franks, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2179 joe.polya(a�pxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) (907) 343-2133 douq.waterspxd.com Sincerely, James Franks Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-45i Well File 5205 N.O'CONNOR BLVD,SUITE 200 - IRVING,TEXAS 75039-3746 - MAIN 972-444-9001 - FAX 972-969-3587 STATE OF ALASKA A, „s...... ALASt.m OIL AND GAS CONSERVATION COMMI6ION APPLICATION FOR SUNDRY AP ROVALS 1�.RECEOV 20 AAC 25.280 +D�' 1 RECEIVED 1.Type of Request: Abandon El Susp ' Operational shutdown V Perforate ❑ Waive; 8 1 2 200OOther El Alter casing❑ Repair welt ❑ Plug Perforations [1] Stimulate ❑ T m. )Cte(r,?tion ❑ Change approved program El Pull Tubing El Perforate New Pool ❑ Re-enter Suspended Welf Oi'S Cons. cc, 2.Operator Name: 4.Current Well Class: 5. Permit to Drilr11/41pn, MfriissioP Pioneer Natural Resources Alaska Inc. Development ❑ Exploratory ❑ 208-100 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 700 G Street,Suite 600 Anchorage,AK 99501 50-703-20577-00 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E ODSN-45i 9. Property Designation: 10. KB Elevation(ft): 11. Field/Pool(s): ADL 355037/ADL 355036 57.12' MSL Ooogurk - Nuiqsut Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13583 6100 13583 6100 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 4820' 10-3/4" 4973' 3438' 5210 2470 Intermediate Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open Hole N/A Packers and SSSV Type: Packers and SSSV MD(ft): N/A N/A 13.Attachments: Description Summary of Proposal Q 14.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 15. Estimated Date for 16.Well Status after proposed work: Commencin Operations: 9 5/200 g p L1 9.711A,SA5 Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17.Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ 0 WDSPL ❑ Commission Representative: — 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact James Franks,343-2179 Printed Name James Franks Title • Senior Drilling Engineer Signature ►' Phone Date �� ----7 343-2179 9/12/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:c30y-3,9 Plug Integrity 111BOP Test LiMechanical Integrity Test ❑ EILocation Clearance Other: (Aq.,CAC-ohZ(., txp .c-t C..c:V\dN b c-- \c�-lv-FtN.-V 4t.v (--vWe\ Subsequent Form Required: LAf c� ,.c_.�vv A----, (1CLs--- )v Ar- 74'7+0\ `N; APPROVED BY (y'� Approved by: OP/". "#°$-''...--('--...----...*I,..-> COMMISSIONER THE COMMISSION Date: ,)// 6 U Form 10-403 Revised 06/2006 ORIGINAFIBINS BFL SEP 1 7 2008 Submit in Duplicate-,------: 74- Pioneer Natural Resources Well Plan ODSN-45i Suspension Plan and Plan Forward Currently tripping for failed MWD in 9-7/8" hole from -13538' MD/6100' TVD Rig Activity: Drill intermediate hole, case and suspend 1. Drill 9-7/8" intermediate hole to estimated casing point of 13860' MD/6170' TVDrkb. 2. Wiper trip to the surface casing shoe. 3. Circulate the hole clean at TD. 4. POH standing back 5" DP and LD BHA. 5. Change one set of pipe rams to 7-5/8" and test BOPE as required. 6. Run and cement the 7-5/8", 29.7# intermediate casing. Bump the plug using seawater and increase the pressure to 4500 psi for 30 minutes, chart and send saam,a to Operations Drilling Engineer. Release pressure and ensure floats are holding. Note: If plug is not bumped, pressure will be held on the casing until the cement is set. The casing will then be tested following the running of the 'kill string'. 7. RIH with -2500' MD of 2-7/8" or 3-1/2" tubing. 8. Land the tubing and RILDS. Note: If the plug did not bump, pressure test the casing to 4500 psi-chart and hold for 30 minutes-send chart to ODE. 9. Install TWC. 10. ND BOPE, NU tree and test to 5,000 psi. 11. Pull TWC. 12. Reverse circulate diesel to freeze protect the well to -2000' TVD and allow to u-tube. 13. RDMO to ODSN-43 to drill and complete that well. Rig Activity: Plan forward The plan forward for the ODSN-45i well is to return to the well in the April 2009 timeframe to drill the lateral as planned in the approved Permit to Drill, 208-100. Following the successful drilling of the lateral, a 4-1/2" liner and will be run with injection conformance devices installed to aid in the placement of the injection water. The completion of the well will be in accordance with the approved PTD following the installation of the liner. ODSN-45i Nuiqsut Injector Present Condition (when 10-403 was sent in) Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor 11111 153'MDrkb/153'TVDrkb Diesel to—2000'TVDrkb 10-3/4",45.5#L-80 BTC,9.95"ID 5000'MDrkb/3442'TVDrkb 9-7/8"Hole ` J 13538'MDrkb/6100'TVDrkb Date: Revision By: Comments 1. 9/12/2008 JDF Present condition ODSN-45i Injector Present Condition Well Schematic PIONEER NATURAL RESOURCES ODSN-45i Nuiqsut Injector Proposed Suspension Completion Well Head: 10-3/4",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor 153'MDrkb/153'TVDrkb Diesel to—2000'TVDrkb 3-1/2",9.3#L-80 TSHP Or 2-7/8"6.5#L-80 IBT-M 10-3/4",45.5#L-80 BTC,9.95"ID 1 5000'MDrkb/3442'TVDrkb Seawater from 2000'TVDrkb Estimated Top of Cement @ 12695' 1 MD/—5820'TVDrkb lil' 7-5/8",29.7#L-80 BTC-M,6.875"ID 13860'MDrkb/6170'TVDrkb Date: Revision By: Comments (.771 9/12/2008 JDF Proposed Suspension Completion Ett ODSN-45i Injector Suspension Well Schematic PIONEER NATURAL RESOURCES Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, August 28, 2008 11:48 AM To: 'Polya, Joe' Cc: Hazzard, Vance; Franks, James; 000gurukdrillingsupervisor@pxd.com; DOA AOGCC Prudhoe Bay Subject: RE: ODSN-45i BOPE Test Pressure lOr Joe, v It is acceptable to proceed with your fishing operations. MASP for this well is calculated at-2500 psi so the 3500 psi test pressure well exceeds it. You are correct that the 4500 psi test was established based on the ultimate casing test pressure. Hopefully, the procedure you are establishing should help avoid such confusion in the future. Communication at all levels is important. I realize that the execution document guiding the actual drilling operations will contain far more detail than the PTD document I will have reviewed. It is most important that the returned PTD document and your execution procedure agree. It is my opinion that the formal authorization to drill the well is the entire package that was submitted to the Commission and subsequently returned. During my review, it is not unusual for me to provide/make "mark up" comments in the document. If there are specific issues/plans that I feel should be emphasized, I normally will speak with yourself or one of the Drilling Engineers however on occasion that may not occur. Good luck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC From: Polya,Joe [mailto:Joe.Polya@pxd.com] Sent: Thursday, August 28, 2008 11:19 AM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Franks, James; 000gurukdrillingsupervisor@pxd.com Subject: ODSN-45i BOPE Test Pressure Mr. Maunder, First of all I would like to inform you of the following event which I eluded to in the phone mail I left on your office phone: EVENT: The Nabors 19AC Rig tested BOPE to 250 psi low/3500 psi high pressure for the Scheduled BOPE Test on August 27, 2008-the AOGCC Approved Drilling Permit for ODSN-45i specifies a high test pressure of 4500 psi. The ROOT CAUSE of this event is that the Nabors 19AC Rig Procedure for Testing BOPE had incorporated steps that specified the 3500 psi high pressure test value based on the most recent wells that were drilled being producers. • Unfortunately, this is an injector well and has a 4500 psi high pressure requirement for the intermediate/longstring casing test to meet the injection service pressure. Other CAUSAL FACTORS are that the rig has recently lost a tool pusher and have promoted personnel to new positions and the new tour pusher was promoted from his driller's position whereby he is familiar with the recent high pressure test to 3500 for producers. Also, the tool pusher was present in the pre-job meeting where the procedure was reviewed and it was discussed that the high pressure requirement was 4500 psi; however, he was relieved by the newly promoted tour pusher who executed the BOPE Test. REMEDY to PREVENT REOCCURRENCE is that the NABORS 19AC Rig Procedure for Testing BOPE has been revised to align with the Well Plan and Forward Plans which simply instruct the crews to Test the BOPE to the pressures outlined in the AOGCC Approved Permit to Drill. These permits are posted and readily available in the Drill Site Leader's Office, the Tool Pusher's Office and in the Dog House on the Rig Floor. 8/28/2008 Page 2 of 2 Secondly, Pioneer requests that AOGCC grant approval to conduct the upcoming drilling operations under the 250 psi low and 3500 psi high pressures until the next scheduled BOPE Test(NLT August 10 or sooner based on casing running date). Pioneer will test the BOPE to 250 psi low/4500 psi high as specified in the approved ODSN-45i Permit to Drill for all future BOPE Tests on this well. Thanks, I will call you again later today to discuss this in detail. Joe Polya 1-907-244-0668 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 8/28/2008 Page 1of1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday,August 26, 2008 2:54 PM To: 'Franks, James' Cc: Polya, Joe; Hazzard, Vance;Vaughan, Alex Subject: RE: PTD 2Q8-100 -temporarily changing a permitted well from an injector to a producer? James, Yes, that would be the proper way to proceed. Please include the new completion diagram and any changes in the procedure. Call or message with any questions. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks@pxd.com] Sent: Tuesday, August 26, 2008 2:50 PM To: Maunder,Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance; Vaughan, Alex Subject: PTD 208-100 - temporarily changing a permitted well from an injector to a producer? Tom, Is the 10-403 the appropriate way to request changing a permitted well from an injector completion to a producer completion? Background info: With the continuing delays in the rig schedule, we are looking into the possibility of temporarily completing the ODSN-45i well (PTD 208-100)as an ESP producer instead of the permitted injector completion. In doing this, we can see two Oooguruk-Nuiqsut production rates prior to going back to drilling Oooguruk-Kuparuk wells in the winter season - Nov 1. These production rate verifications will be very handy in the determination of our need to stimulate the wells in the reservoir. We would plan on leaving the well completed as a production well for 3 to 6 months prior to re-completing as an injector. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907.343.2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 8/26/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Jc 0 >\ -\ _ S � Sent: Thursday, August 21, 2008 10:04 AM C� To: 'Polya, Joe Cc: DOA AOGCC Prudhoe Bay; Hazzard,Vance Subject: RE: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk Joe, We have examined the performance information for the BOP tests on Nabors 19AC. Your request to change the test interval to 14 days is APPROVED effective immediately. Please remember that the testing interval requirement is"not to exceed 14 days". In contrast to the 7 day test interval, extensions to exceed 14 days are rarely granted. It is our expectation that testing will be accomplished on an irregular time interval with the testing date determined by actual well operations. Good luck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya@pxd.com] Sent: Wednesday, July 30, 2008 1:49 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk Mr. Maunder, As per our recent discussion regarding Pioneer's request to AOGCC to extend our current 7 day BOPE Test Cycle to 14 days, I am sending a summary of our BOP Test Dates, Agency Witnessed vs. Waived Status, Test Duration and Failures. I propose that the BOP Tests results demonstrate both the reliability of the Nabors 19AC BOP Equipment and Crews. We are requesting that AOGCC extend our test cycle to 14 days beginning with the drilling of the ODSN-45i well which should spud on Friday or Saturday August 1st or 2nd. Pioneer appreciates that the extensions which have been available with the 7 day test cycle are not an option when operating within the 14 day test cycle. Please copy Mr. Vance Hazzard va,ice hazzai d@pAd corn i with your response to this request as I will be on vacation beginning Wednesday, July 30th through Thursday, August 7th. Thank you for your time and consideration of this matter, 7'4 , 98ePo4a Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 8/21/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Thursday, August 21, 2008 10:05 AM To: Maunder, Thomas E (DOA) Subject: RE: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk I think a copy 01 your response to Pioneer and attached background info (their request, test performance summary)I belongs in both the ng file (Nabors 19AC) and well file (ODSN-45, PTD 2081000) Thank you for handlirea this- I'm sure Pioneer will appreciate it. Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Maunder, Thomas E (DOA) Sent: Thursday, August 21, 2008 9:49 AM To: Regg, James B (DOA) Subject: RE: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk I will send a reply to Joe, et al and copy you. How do we want to archive/save this information? I do have a directory on the W drive titled Drilling_Rig_Info although I don't have a Nabors 19AC folder but that is easily added. Do we want these messages in the 19AC rig file up front? Should it be put in the file for this well? Tom From: Regg, James B (DOA) Sent: Thursday, August 21, 2008 9:30 AM To: Maunder, Thomas E (DOA) Subject: RE: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk See attached. Test performance at Nabors 19AC (including their test procedure) supports allowing Pioneer to test BOPE at intervals not to exceed 14 days. I'm sure you will remind them about looking for opportunities to test early. and that there will be no extensions to the 14 day window. Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Maunder, Thomas E (DOA) Sent: Wednesday, August 20, 2008 4:06 PM To: Regg, James B (DOA) Subject: FW: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk Here is the message from Pioneer regarding going to the 14 day BOP test. I thought I had seen a document 8/21/2008 Page 2 of 2 earlier than July 30, but I cannot find anything. Looking at their spreadsheet, the performance of late looks pretty good. I don't have the reports to actually compare with. Looks like in general that the test interval early on was more than 7 days. I know they were having problems at times. I have not sent a reply back to Joe. Tom From: Polya, Joe [mailto:Joe.Polya©pxd.com] Sent: Wednesday, July 30, 2008 1:49 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: Formal Request to Extend the BOPE Test Cycle to 14 days for the Nabors 19AC Rig at Oooguruk Mr. Maunder, As per our recent discussion regarding Pioneer's request to AOGCC to extend our current 7 day BOPE Test Cycle to 14 days, I am sending a summary of our BOP Test Dates, Agency Witnessed vs. Waived Status, Test Duration and Failures. I propose that the BOP Tests results demonstrate both the reliability of the Nabors 19AC BOP Equipment and Crews. We are requesting that AOGCC extend our test cycle to 14 days beginning with the drilling of the ODSN-45i well which should spud on Friday or Saturday August 1st or 2nd. Pioneer appreciates that the extensions which have been available with the 7 day test cycle are not an option when operating within the 14 day test cycle. Please copy Mr. Vance Hazzard vance.hazzard(doxd.cc' with your response to this request as I will be on vacation beginning Wednesday, July 30th through Thursday, August 7th. Thank you for your time and consideration of this matter, p8eoeq4 Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907)244-0668 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 8/21/2008 CG 0 I J iv- o) c N L 4= O 0 Y 0 c E ce m 7 o L E L..-- c o LL c (6 Q 5 ai Y N c a) cow m o a) _ E .c CL c J 0 d c U Q n. a > a. c m cnCL tai CO Q co co � �' cis '' O c co CD rn a) cc) ao c0 a) Q t a) m Z' c N 03• al +' CO t- F. 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Cl � a a a a a CL CL CI . a 5 0 o E o 0 o o o o o o E o o o o o E o 0 0 0 0 0 0 ''- 0 0 0 U z CD C- CD 0 Q If a a a a Cr) If el.) a a a a a d a a a a a a a a a a a a a a a >, W0000 a) a) a) a) 000000000000000000000 i-- ommmm0000mmmmmmmmmmmmmmmmmmmmm 2 O O op ao 90 00 000 CO aO0 aO0 aOo o aOo ao0 co aOO OOOOO co co aOo O 92 co aOQOOO Q000000QOOOO000000000QOOOOOOOOO N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 00 zo co M O) N COO co t 1 N -- O CD UD M ,- a0 CVO t 1 O> u) M ,- O) co a) ' N — .- N (V v- A- N N A- N A- r- N A- N N M � ,- N N � '— N N y- F- N N `- ,- N N N N M M M 4 4 d' in UD n co CC) 45 a) VD ti r- 85 r r CD CD CD CD CD CD CD a• 00 a0 CO CO 01 M CD 0 O F- ,- r e- c- r O A- a N- N N- r t- CO 00 O o O 0 O O O N N N N N N N AT V r CO 141 yr M O O M M M M V Y Y Y Y Z Z 0 0 0 0 0 0 0 0 000 0 0 0 0 Test Date Witnessed By Test Time Failures Comments 12/15/2007 N/A(None mentioned) 0 Diverter Test 12/28/2007 Bob Noble (witnessed) 16.0 hrs 2 Changed rubbers on blind rams&choke due to manufacture defect. 1/14/2008 Lou Grimaldi (witnessed) 21.0 hrs 3 Replaced Hydril element, repaired sensor F/superchoke casing gauge, repaired close lamp on blind rams remote. 1/23/2008 Chuck Sheve(waived) 7.0 hrs 0 Re-tested blind ram due to test being run against hydralic valve instead of positive. 1/29/2008 John Crisp (waived) 0 Diverter Test 2/5/2008 Lou Grimaldi (waived) 0 Diverter Test 2/18/2008 John Crisp (waived) 0 Diverter Test Tightened fitting on U.Pipe Ram, Changed 2/23/2008 Chuck Sheve (waived) 5.0 hrs 0 out bad section of kill line and re-test 5K 3/1/2008 Bob Noble (witnessed) 5.0 hrs 0 3/15/2008 Chuck Sheve(waived) 5.0 hrs 0 3/22/2008 Lou Grimaldi (witnessed) 4.0 hrs 0 4/1/2008 John Crisp (waived) 4.0 hrs 0 4/10/2008 Chuck Sheve (waived) 5.5 hrs 0 4/19/2008 Bob Noble(waived) 3.0 hrs 0 4/25/2008 Chuck Sheve (waived) 3.0 hrs 0 Rented TIW failed. Replaced with NAD & 5/13/2008 Jeff Jones (waived) 5.0 hrs 1 test. 5/21/2008 Lou Grimaldi (witnessed) 3.5 hrs 0 PNR TIW on location & passed by AOGCC Upper Top Drive IBOP failed, replaced same 5/28/2008 Bob Noble (waived) 10.5 hrs 1 and tested. 6/9/2008 Chuck Sheve (waived) 3.5 hrs 0 Tested Choke Manifold while POOH 6/16/2008 Bob Noble (waived) 2.0 hrs 0 Tested Choke Manifold while POOH 6/25/2008 Jeff Jones (waived) 3.0 hrs 0 Tested Choke Manifold while POOH 6/29/2008 Lou Grimaldi (waived) 3.0 hrs 0 Tested Choke Manifold while POOH 7/5/2008 Bob Noble (waived) 4.0 hrs 0 Tested Choke Manifold while POOH 7/13/2008 John Crisp (witnessed) 5.5 hrs 0 7/21/2008 Chuck Sheve (waived) 2.5 hrs 0 Tested Choke Manifold while POOH a nft,LSEA 4111 +.. SARAH PAL/N, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO11 1ISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G Street, St 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk- Nuigsut Oil Pool, ODSN -45i Pioneer Natural Resources Alaska Inc. Permit No: 208 -100 Surface Location: 2889' FSL, 1176' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 2802' FSL, 2250' FEL, SEC. 9, T13N, R7E, UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, O 74' Daniel T. Seamount, Jr. Chair DATED this LL day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED EIVED STATE OF ALASKA ALAI* OIL AND GAS CONSERVATION COMA/310N I [ �r7 JUN ?008 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas Cons. Cornmi.s.sjort la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposed for: A nc h orage Drill 0 - Redrill ❑ Stratigraphic Test ❑ Service el • Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone , 151 Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket • Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 - ODSN -45i 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 20,434' • TVD: 6,263' 4a. Location of Well (Governmental Section): 7. Property Designation: Oooguruk - Nuiqsut Oil Pool Surface: 2889' FSL, 1176' FEL, Sec. 11, T13N, R7E, UM • ADL 355036 / ADL 355037 ° Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3369' FSL, 3072' FEL, Sec. 15, T13N, R7E, UM 417497 6/25/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 2802' FSL, 2250' FEL, Sec. 9, T13N, R7E, UM 5760 + 5724 = 11,484 Property: 13481' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 469821.86 • y- 6031005.53 • Zone- ASP 4 (Height above GL): 57.5 feet ° Within Pool: N/A 16. Deviated wells: N/A Kickoff depth: 500' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.88 degrees Downhole: 3172 psig , Surface: 2487 psig . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H -40 Welded 109' Surface Surface 153' • 153' ' Driven 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3500' Surface Surface 3544' . 2995' , 476 sx Permafrost 'L'; 239 sx Class '0' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 13875' Surface Surface 13919' . 6224' . 293 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat el Diverter Sketch 111 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joe Polya, 343 -2111 Prepared By: Kathy Campoamor, 343 - 2183 • Printed Name Joe Polya Title Sr. Staff Drilling Engineer Signature Z----• Phone 343 -2111 Date 6/11/2008 Commission Use Only Permit to Drill 2 �/� API Number: �• Permit pprov See cover letter for other Number: 50 763 - J 77 " Date: ( • •01 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed / methane, gas hydrates, or gas contained in shales: Other: M ‘,74 ccome+∎ . Samples req'd: Yes[] Not Mud log req'd: Yes❑ No[' "15 d® V C >W? \ nv VkG , H measures: Yes❑ No Q' Directional svy req'd: YesR]' No❑ �r k - 1�.C. .- Cc. oQ�e \A ti.s\r <1(30 -i Ai�3� UGC c \�csc.. cki6 \e. ,bac) V -A r Q ` � . -< ' DtivctC� c . c � Z v D O A P Q aS.O 7 ,S ci.)()) , / j APPROVED BY THE COMMISSION (6 / DATE: 9 , COMMISSIONER Form 10 -401 ` Revised 12/2005 ubmit in Duplicate ( s r- ��G1NAL ,`',, 4 '/7. at, • • RECEIVED ,iUN 1 1 2008 PIONEER t & ^ NATURAL RESOURCES ALASK Alaska INC. * laska it & l3 '. C o' ; Cornrn June 11, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN -45i Surface Location: 2889' FSL, 1176' FEL, Sec 11, T13N, R7E, UM X = 469821.86, Y = 6031005.53, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill an injection • well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be an injection well in the Oooguruk - Nuiqsut formation. PNRA requests the permit to drill based on approved Pool Rules. As indicated in the attachments, the drilling program will entail drilling a directional 13 -1/2" surface hole to approximately 3544' MD / 2995' TVDrkb, where surface casing will be set. A 9 -7/8" directional wellbore will be drilled into and set at the top of the Oooguruk - Nuiqsut interval at approximately 13919' MD / 6224' TVDrkb. The horizontal injection interval will be drilled to 20434' MD / 6263' TVDrkb, the final TD of the well. The proposed casing program will utilize 10 -3/4" surface casing, 7 -5/8" intermediate casing and an open hole completion of the 6 -1/8" hole section. The completion will utilize 3 -1/2" tubing. PNRA requests allowance to deviate from 20 AAC 25.412 (b) in setting the packer within 200' — MD from the injection interval. PNRA requests to set the packer in the intermediate casing in a section covered by cement in the annulus and at an angle less than 73 degrees to facilitate wireline and slick line operations. For this well, the set depth of the packer would be -981' MD / 279' TVD above the injection interval. Unlike other wells in the Oooguruk Development, it is planned to drill and complete this well in entirety. 700 G STREET, STE. 600 • ANCHORAGE, ALASKA 99501 • MAIN. (907) 277 -2700 Alaska Oil & Gas Conser.n Commission • June 7, 2008 Page 2of3 r> .:r PIONEER NATURAL RESOURCES ALASKA, INC. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a -.. diverter system be installed on the well while drilling the surface interval. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path — including travelling cylinder and development layout plots 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 � AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2s contamination in the drilling mud system will be maintained on the ODS. 700 G STREET, STE 600 • ANCHORAGE, ALASKA 99501 • MAIN. (907) 277 -2700 Alaska Oil & Gas Consen n Commission • June 7, 2008 Page 3 of 3 PIONEER NATURAL RESOURCES ALASKA, INC In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joe Polya, Senior Drilling Engineer (20 AAC 25.070) 907/343 -2111 ioe.polva a(�,pxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) 907/343 -2133 tavia. iackson a pxd . com The anticipated spud date for this well is June 23, 2008. If you have any questions or require further information, please contact Joe Polya at 907/343 -2111. Sincerely, a _ J e Polya Senior Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSN -45i Well File 700 G STREET, STE 600 • ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • • Oooguruk Well Plan Summary: Permit to Drill ODSN -45i — Nuiqsut Injection Well Surface Location: 2889' FSL, 1176' FEL, Sec 11, T13N, R7E, UM • ASP 4 (NAD27) projection X = 469821.86 • 1 Y = 6031005.53 • Target: 3369' FSL, 3072' FEL, Sec15 , T13N, R7E, UM X = 462631.73 1 Y = 6026238.62 1 6,224' TVDrkb Bottom Hole Location: 2802' FSL, 2250' FEL, Sec9 , T13N, R7E, UM X = 458189.00 1 Y = 6030974.00 6,263' TVDrkb AFE Number: TBD Est. Start Date: June 25, 2008 Rig: Nabors 19AC Operating days: 35.7 days Drill and Complete TD: 20,434 MD / 6,263 TVDrkb • Objective: Nuiqsut ' Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Slim hole — Injector — wp10 • Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' • RKB to Ground Level: 44' Rig Elevation: RKB + MSL = 57.5' Conductor: 153' MDrkb Well Control: Based on calculations below, BOP equipment will be tested to 4,500 psi. Surface Section: • Maximum anticipated BHP: 1340 psi CO 2995' TVDrkb (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 1011 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Intermediate Section: • Maximum anticipated BHP: 3172 psi @ 6224' TVDrkb • Maximum surface pressure: 2487 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3172 psi @ 6224' TVDrkb • Maximum surface pressure: 2487 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Planned BOP test ressure: 4500 psi (annular to 2500 psi) p ( p ) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 1 of 9 • Diverter (see attached schematic): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 10 -3/4" Surface Shoe Rathole + 20' to 50' from 9 -5/8" shoe LOT 12.0 ppg 7 -5/8" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 13 -1/2" hole S ud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 — 15 unrestricted Final 9.2 -9.6 70 -100 25 — 35 15 — 25 10 — 15 <12 Intermediate Hole Mud Properties: 9 -7/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 8.8 -9.3 40 - 60 15 - 25 15 — 20 < 12 6 - 8 HRZ to TD 12.0 • 40 — 60 15 - 25 20 - 30 < 15 3 — 5 (8 -10 HTHP) Production Hole Mud Pro erties: 6 -3/4" hole Baradril -N Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 10.4 • 40 - 60 15 - 25 15 — 20 0 <4 Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 2 of 9 . • Hydraulics: Surface Hole: 13 -1/2" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf to BPRF 700 5" 19.5# 110 2100 10.0 N/A 16,16,16,12 .7 BPRF to TD 700 5" 19.5# 110 2100 10.0 N/A 18,18,18,16 .7 Intermediate Hole: 9 -7/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf Shoe to TD 575 5" 19.5# 195 4100 13.1 N/A 6x16 1.18 Production Hole: 6 -3/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Int Shoe to TD 250 4" 15.7# 210 4200 12.2 N/A 5x11 0.464 Formation Markers: TVD Pore Press. EMW Formation Tops MD (rkb) (psi) (ppg) Comments Base Permafrost 1617 1608 Top West Sak 2485 2396 1058 8.7 Base of fluvial sands Hue Shale 3446 2964 Tuffaceous Shales 3661 3030 Top Torok Sand 10180 5020 2245 8.7 Top of Disposal Zone Base Torok Sand 10848 5273 Base of Disposal Zone Top HRZ 12286 5766 Base HRZ 12704 5889 Kalubik Marker 13013 5978 Top Kuparuk C 13261 6051 3084 9.8 Base Kuparuk C 13297 6061 Top Nuiqsut • 13919 6224 3172 9.8 Base Nuiqsut n/a Not penetrated Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 3 of 9 • • Logging Program: 13 -1/2" Section: Drilling: Mud logging . Dir/GR Open Hole: N/A Cased Hole: N/A 9 -7/8" Section: Drilling: Mud logging • Dir / GR / Res / Dens / Neut / PWD • Open Hole: N/A Cased Hole: N/A 6 -3/4" Section: Drilling: Mud logging . Dir / GR / Res / Dens (Azm) / Neut / PWD ' Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 109' Surface 153' / 153' • 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3500' Surface 3544'/2995' ' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 13875' Surface 13919' / 6224' • Tubing 3 -1/2" 9.3# L -80 TSHP/TCII 12906' Surface 12950' / 5960' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Strength Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 10 -3/4" 45.5# L -80 9.95" 9.794" BTC 5210 2470 1063M 1063M 7 -5/8" 29.7# L -80 6.875" 6.75" BTC -M 6890 4790 683 M 683 M Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 4 of 9 • • Cement Calculations: Casing Size: 1 10 -3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3044' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 352 bbls / 476 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 50 bbls / 239 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 324 bbls Mud Temp BHST -55° F, BHCT -60° F estimated During drilling operations, should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed, if needed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 7-5/8" Intermediate Casing - single stage Basis: Tail: 1159' of open hole with 30% excess, plus 85' shoe track Tail TOC: - 12760' MD (1133' above the shoe) - 500' MD above the top of the Kuparuk Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Tail 62 bbls / 293 sx of 15.8 ppg Premium "G" + adds. 1.18 cf /sk, 5.18 gps water req. Displ 636 bbls mud Temp _ BHST -- 165° F at 6100' TVDrkb, -135° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone . II I Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 5 of 9 • • Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. The Oooguruk Drill Site Class 1 / Class 2 Disposal Well, ODSDW1 -44, has been drilled and commissioned for disposal. 3. A procedure for handing the access of the MGT into the Disposal Well while we are drilling the surface hole of ODSN -45i needs to be in place. Riq Activity: Drill and Complete 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. • 2. Nipple up spacer spools and riser. Note: In the cover letter for this permit to drill request, a diverter waiver is also requested based on information turned in previously. 3. MU 13 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point at 3544' MD / 2995' TVDrkb, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 10 -3/4 ", 45.5# surface casing Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Riser, NU BOPE and test. Test BOPE to 250/4500 psi 7. Close blind rams and test 10 -3/4" casing to 3,500 psi for 30 minutes -- chart and send to Operations Drilling Engineer. 8. MU 9 -7/8" directional drilling, MWD /LWD assembly. RIH and cleanout the casing to landing collar. Displace the well over to intermediate hole drilling fluid. 9. Drill 9 -7/8" intermediate hole to casing point at 13919' MD/ 6224' TVDrkb. Note: Perform short trips at 1500' intervals or every 12 hours, which ever comes first to gauge hole conditions. Short trip frequency can be reduced or extended based on results of each subsequent short trip. At TD make a wiper trip to the surface casing shoe. Circulate and condition the drilling fluid to run casing. POH standing back some of the 5" DP and LD the rest of the 5" DP or per the pipe management plan yet to be developed by core rig team on location. 10. Change one set of pipe rams to 7 -5/8" and test BOPE as required. 11. Run and cement the 7 -5/8 ", 29.7# intermediate casing. Bump the plug and increase the pressure to 4500 psi for 30 minutes, chart and send same to Operations Drilling Engineer. Release pressure and ensure floats are holding. Note: If plug is not bumped, the casing will be tested by closing blind rams after BOPE Test. 12. PU, RIH and rack back enough 4" DP to drill to production hole TD minus the amount of pipe that will be picked up while RIH with BHA to drill float equipment. 13. Change pipe rams to 4" and Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 14. MU 6 -3/4" directional drilling, MWD /LWD assembly. RIH with BHA on 4" while PU singles and cleanout to landing collar. 15. Drill out shoe tract, cement, rat hole and 20' of new formation below 7 -5/8" shoe. Pull the bit back into the 7 -5/8" casing and perform an FIT. 16. Displace the well over to production hole drilling fluid. 17. Drill the 6 -3/4" production hole to TD at -20434' MD/ 6263' TVDrkb. At TD circulate and condition while displacing the open hole lateral to clean drilling fluid system. Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 6 of 9 • • 18. POH to the intermediate casing shoe standing back the 4" DP per the pipe management plan Yet to be developed by core rig team on location. 19. Displace the well over to 10.2 ppg Brine. 20. POH standing back some of the 4" DP and LD the rest of the 4" DP per the pipe management plan yet to be developed by core rig team on location. 21. MU completion with Retrievable Packer and RIH. 22. Verify spaceout and place the packer at depth that allows for placing compression in the tubing (verify with Weatherford) 23. Reverse circulate corrosion inhibited brine down to the packer. 24. Drop the ball and rod and allow to seat. 25. Pressure up to set the packer and test the tubing to 4,500 psi - chart and hold for 30 minutes. Bleed off pressure and send chart to Operations Drilling Engineer. 26. Land the tubing and RILDS. Install TWC. 27. ND BOPE, NU tree and test to 5,000 psi. 28. Pull TWC. 29. Pressure test the annulus to 4,500 psi - chart and hold for 30 minutes. Bleed off pressure and send chart to Operations Drilling Engineer. 30. RU Slickline and pull the dummy valve from the upper GLM. 31. Reverse circulate diesel to freeze protect the well to -2000' TVD and allow to u -tube. 32. Pull the ball and rod. Pull the RHC -m plug. Install Dummy Valve in the upper GLM. 33. RD Slickline. RDMO to ODSN -43 to drill and complete that well. Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 7 of 9 • • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test (or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit) with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT /FIT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. Note: For FIT, do not take to leak off • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the LOT /FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 8 of 9 • ODSN -45i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre- reservoir meeting to outline heightened awareness and kick detection. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and , perform a flow check to verify there isn't any overpressure. o During the drilling of ODSDW01 -44 and ODSK -33, no increase in pressure was seen, . but we will be in a new fault block at the wellpath intersection with the Kuparuk. Hydrates and Shallow gas • No hydrates are expected in this area. • Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Be on the look out for lost circulation events and follow the Decision Tree as required. • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the faults seen in and below the Torok Sands. • Lost Circulation was seen in drilling with MOBM in the abandoned wellbore on ODSN -40. The losses continued after swapping the intermediate hole drilling fluid over to SWBM. At this time, assume that any faults drilled in the intermediate hole will have lost circulation issues. • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33. During the sidetrack of ODSK -33, this zone was not problematic. In any case, close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Interval Maximum Influx Mud Exp Pore Min LOT / FIT Volume Weight Press 10 -3/4" Surface / 9 -7/8" hole 91 bbls 10.5 • 3054 12.5 ppg (LOT) 7 -5/8" Interm / 6 -3/4" hole Infinite 10.2 = 3142 12.5 ppg (FIT) NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating • Procedures for H precautions should be followed at all times. Faults • 2 seismically visible faults are expected to be crossed and sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Fault Location MD TVDrkb Throw Direction Uncertainty Intermediate Hole 11300 5832 -20' Down to the East +/- 300' MD Production Hole 19500 6268 -50' Down to the East +/- 300' MD CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources Last Revised: June 1, 2008 ODSN -45i Permit To Drill Page 9 of 9 • I ODSN -45i Nuiqsut Injection Well Proposed Completion Well Head: 10 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal f 16" Conductor ` 153' MDrkb / 153' TVDrkb 3 -1/2" ScSSSV, 2.813" ID @ —750' 10 -3/4 ", 45.5# L -80 BTC, 9.95" ID 3544' MDrkb / 2995' TVDrkb 3 -1/2" MMG GLM @ 4650' MD / 3330' TVDrkb 3 -1/2 ", 9.3# L -80 TSHP Estimated Top of Cement @ 12760' MD / —5905' TVDrkb 1 4 3 -1/2" MMG GLM @ 11478' MD / 5510' TVDrkb © • 3 -1/2" Sliding Sleeve @ 12850' MD / 5931' TVDrkb X Nipple, 2.813" ID 7" x 3 -1/2" Retrievable Packer @- 12900' MD / 5945' TVDrkb X Nipple, 2.813" ID w /RHC -M Plug ■ ■ XN Nipple, 2.725" ID Nogo 13919' MDrkb / 6224' TVDrkb @ 12950' MD, 73 degrees 6 -1/8" Open Hole 7 -5/8 ", 29.7# L -80 BTC -M, 6.875" ID 20434' MDrkb / 6263' TVDrkb . Date: Revision By: Comments 6/11/2008 JDF Proposed Completion ODSN -45i Injector r ' tT k Well Schematic WP10 PION EER NATURAL. RESOURCES 111 0 i t 1 i , 1 1 4 , Well Planning - Pioneer - Oooguruk m , Oooguruk Developement t I Oooguruk Drill Site J g ODSN-45i - Slot ODS-45 ODSN-45i PN13 1 t -.4 1 , $ Y.. 4 q t li i 'g Plan: ODSN-45i IN13 wp10 'e A i , 1 f 0 4 . Standard Proposal Report i f ' 10 June, 2008 ; 4 1 ; , i. h, , 4 ) 1 a — 0 t4. i : 0 I ' ; HALLIBURTON Sperry Drilling Services 1 ! -., WELL DETAILS: ODSN -45i RE FEREN C E INF ORMATION HALL1BURTON Co-or dinate (N E)Reference: wallOD -45i- Slot ODS -45, True N rrth Ground Level: 13 V ert i ca l ( 'rvD ) Reference: 44' + 13 5' @ 57.5ft (Nabors 19AC) 1. +N / -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Sperry Drilling Services 0.0 0.0 6031005.53 469821.86 70° 29'44.804 N 150° 14'48.350 W ODS -45 I Calculation Method: Minimum Curvature PIONEER SURVEY PROGRAM WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Date: 2008-06-05700:00:00 Validated: Yes Verson: Project: Oooguruk Developement Name ND +N / -5 +E/ -W Northing Easting Shape Depth From Depth To Survey/Plan Tool 1100 .0 ODSN-45i IN13 wp10 CB-GYRO-SS Site: Oooguruk Drill Site Geopoly HRZ 5650.0 - 7869.1 - 4817.8 6023156.89 464972.69 Polygon 1100.0 20434.4 ODSN -45i IN13wp10 MWD +SAG +CA +IIFR +MS Well: ODSN -45i N13 v10 T1B 5650.0 - 6206.5 - 5864.0 6024823.52 463933.28 Point N13 v9 TS 6147.5 - 2009.5 - 9731.8 6029035.80 460083.00 Point Wellbore: ODSN-45i PN13 Geo Poly 6150.0 - 4778.1 - 7394.6 6026257.97 462408.70 Polygon CASING DETAILS COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Plan: ODSN -45i IN13 w p 10 N13 v9 T3 6157.5 - 3623.5 - 8212.1 6027415.78 461595.98 Point - - - - -. N13 v9 T4 6237.5 - 2895.6 - 8895.7 6028146.33 460915.41 Point ND MD Name Size Calculation Method: Minimum Curvature N13 v9 T2A 6247.5 - 4567.7 - 7362.7 6026468.22 462441.42 Point 2995.0 3544.3 9 5 /8" 9.625 Error System: ISCWSA N13 v9 T7 6262.5 -78.8 - 11633.8 6030974.00 458189.00 Point 6247.5 14218.5 7" 7.000 Scan Method: Tray. Cylinder North N13 v9 T6 6272.5 - 1167.9 - 10540.5 6029880.50 459277.80 Point Error Surface: Elliptical Conic -1200- Warning Method: Rules Based - -600 - 7.15 SECTION DETAILS • _ /2 =, N Start Dir 1.00/100' 500.00' MD, 500.00' D DDI = 7.155 Sec MD Inc Azi ND +N / -S +E / -W DLeg TFace VSec Target 1 44.0 0.00 0.00 44.0 0.0 0.0 0.00 0.00 0.0 2 500.0 0.00 0.00 500.0 0.0 0.0 0.00 0.00 0.0 0 Start Dir 1.50/100' 1000.00' MD, 999.40' TVD 3 1000.0 5.00 170.00 999.4 -21.5 3.8 1.00 170.00 -3.6 - 4 1661.4 14.92 170.00 1650.0 -134.0 23.6 1.50 0.00 -22.7 _ 5 1764.9 14.92 170.00 1750.0 -160.2 28.3 0.00 0.00 -27.2 - - 6 3526.0 72.37 212.00 2989.5 - 1197.2 -421.3 3.50 46.44 429.4 600 End Dir 1661.40' MD, 1650.00' TVD 7 3544.3 72.37 212.00 2995.0 - 1211.9 -430.5 0.00 0.00 438.7 8 3912.8 72.37 217.80 3106.7 - 1499.8 -631.3 1.50 90.88 641.5 - 9 7192.4 72.37 217.80 4100.0 - 3969.6 - 2547.1 0.00 0.00 2573.9 Start Dir 3.50/100' 1764.90' MD, 1750.00' TVD 10 7197.0 72.38 217.97 4101.4 - 3973.0 - 2549.7 3.50 85.37 2576.6 1200 - , - 10° 12 11902.0 72.39 300.00 5650.0 - 6206.5 - 5864.0 3.50 104.74 5905.9 IN13 v10 TIB Base of Permafrost 13 12552.6 73.11 320.43 5844.8 - 5807.6 - 6335.4 3.00 90.96 6374.6 - ' 14 13655.4 73.11 320.43 6165.1 - 4994.1 - 7007.6 0.00 0.00 7041.2 Start Dir 1.50/100' 3544.30' MD, 2995.00' TVD 15 14218.5 90.00 320.00 6247.5 - 4567.7 - 7362.7 3.00 -1.49 7393.5 IN13 v9 T2A E 1800- 16 14387.8 94.65 317.97 6240.6 - 4440.1 - 7473.7 3.00 -23.56 7503.6 w 1 17 15332.0 94.65 317.97 6164.0 - 3741.1 - 8103.9 0.00 0.00 8129.0 0 - 25° End -Dir 3526.00' MD, 2989.50' TVD 18 15492.0 90.00 316.80 6157.5 - 3623.5 - 8212.1 3.00 - 165.88 8236.4 IN13 v9 T3 p - ' - 19 15679.9 84.36 316.81 6166.7 - 3486.7 - 8340.5 3.00 179.85 8363.9 2400- - 20 16306.2 84.36 316.81 6228.3 - 3032.3 - 8767.0 0.00 0.00 8787.4 p6 9 5/8" , - - . - 21 16494.2 90.00 316.67 6237.5 - 2895.6 - 8895.7 3.00 -1.48 8915.1 IN13 v9 T4 -C - , , - - End Dir 3912.80' MD, 3106.70' TVD 22 16656.7 94.88 316.71 6230.6 - 2777.5 - 9007.0 3.00 0.48 9025.6 n - Top West Sak c , - - - _ - - 23 17552.6 94.88 316.71 6154.5 - 2127.8 - 9619.1 0.00 0.00 9633.3 • 3000 " - - - - 24 17716.2 90.00 316.14 6147.5 - 2009.5 - 9731.8 3.00 - 173.35 9745.1 IN13 v9 T5 _ - Start Dir 3.50/100' 7192.40' MD, 4100.00' TVD 25 17979.4 82.10 316.32 6165.6 - 1820.0 - 9913.3 3.00 178.66 9925.4 T6 26 18623.6 82.10 316.32 6254.1 - 1358.4- 10354.0 0.00 0.00 10362.9 o - Hue Shales , 27 18891.1 90.00 314.89 6272.5 - 1167.9 - 10540.5 3.00 -10.32 10548.1 1N13 v9 T6 ' ^ E nd , Dir 7197.00' MD, 4101.40' TVD 28 18903.5 90.37 314.89 6272.5 - 1159.2 - 10549.3 3.00 0.00 10556.9 • 3600 - , 29 20434.4 90.37 314.89 6262.5 - 78.8 - 11633.8 0.00 0.00 11634.1 IN13 v9 T7 a) Tuffaceous Shales , ' Start Dir 3.50/100' 9689.40' MD, 4855.70' ND 4200 Brook 2B - - _ . rY End Dir 12552.60' MD, 5844.80' TVD End Dir 14387.80' MD, 6240.60' ND End Dir 16656.70' MD, 6230.60' ND - / Start Dir 3.00/100' 17552.60' MD, 6154.530' ND FORMATION TOP DETAILS Start Dir 3.00/100' 13655.40' MD, 6165.10' ND 4800 - - TVDPathTVDssPath MDPath Formation ` Start Dir 3.00/100' 15332.00' MD, 6164.00' TVD End Dir 17979.40' MD, 6165.60' ND - 1607.5 1550.0 1617.5 Base of Permafrost s - 2396.2 2338.7 2485.3 Top West Sak ` • End Dir 15679.90' MD, 6166.70' ND Start Dir 3.00/100' 18623.60' MD, 6254.10' ND 5400 2963.5 2906.0 3446.2 Hue Shales ` ' - 3030.5 2973.0 3661.4 Tuffaceous Shales Top torok Sand ` - 4238.4 4180.9 7649.7 Brook 2B IN13v10T1B _ A . Start Dir 3.00/100' 16306.20' MD, 622 NjY ' End Dir 18903.50' MD, 6272.50' TVD r r 5019.6 4962.1 10179 Top torok Sand , Total De th at 20345.10' MD, 6262.50' TVD 6000 5273.1 5215.6 10847.8 Base Torok Sand _ - - - - !°� p - 5766.1 5708.6 12286.3 Top HRZ Top HRZ - HRZ - - - - - - " ■ . . - - 5888.8 5831.3 12704.1 Base HRZ - - - - / ; ( 5978.4 5920.9 13012.6 Kalubik Marker Kalubik Marker - - . ' • 6600 - 6050.5 5993.0 13260.8 Top Kuparuk C - 1 IN13 v9 T3 I IN13 v9 TS t t ■ ODSN - 45i IN13 wp10 -- 6061.0 6003.5 13296.9 Base Kuparuk (LCU) - Base Kuparuk (LCU) • IN73 v9 T6 ‘ 6224.0 6166.5 13918.5 Top Nuiqsut Top Kuparuk C IN13 v9 T2* IN1av9 T41 3 v9 T7 IIrlI I I I I I I II [f11 11 I I I I II I I I I I.. . - i , l - .T - i.I7 - ETJf II I..rtip lI II I I I II I I I I I I II I I I II II II I Il i I I I I I I II I I I I I I I II I I I I I II I I II IIIII - 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 , Vertical Section at 269.61 bearing (1500 ft/in) lki WELL DETAILS: ODSN -45i REFERENCE INFORMATION 1 HALLI ®URTON Ground Level• 13.5 Co-ordinate (N/E) Reference: Well ODSN-45i - Slot ODS- 45, True North +N / -S +E/-W Northing Fasting Latittude Longitude Slot Vertical (TVD) Reference: 44' + 13.5' @ 57.59 (Nabors 19AC) 0.0 0.0 6031005.53 469821.86 70° 29' 44.804 N 150° 14' 48.350 W ODS -45 Measured Depth Reference: 44' + 13.5' @ 57.511 (Nabors 19AC) Sperry Drilling Services Calculation Method: Minimum Curvature PIONEER SECTION DETAILS SURVEY PROGRAM Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target Date: 2008 06 05T00:00.00 Validated: Yes Version: 1 44.0 0.00 0.00 44.0 0.0 0.0 0.00 0.00 0.0 Depth From Depth To Survey/Plan Tod Project: Oooguruk Developement 2 500.0 0.00 0.00 500.0 0.0 0.0 0.00 0.00 0.0 44.0 1100.0 ODSN -45i IN13 wp10 CB-GYRO -SS Site: Oooguruk Drill Site 3 1000.0 5.00 170.00 999.4 -21.5 3.8 1.00 170.00 -3.6 1100.0 20434.4 00514 -45i IN13wp10 MWD +SAG +CA +IIFR +MS 4 1661.4 14.92 170.00 1650.0 -134.0 23.6 1.50 0.00 -22.7 Well: ODSN -45i 5 1764.9 14.92 170.00 1750.0 -160.2 28.3 0.00 0.00 -27.2 Wellbore: ODSN -45i PN13 6 3526.0 72.37 212.00 2989.5 - 1197.2 -421.3 3.50 46.44 429.4 CASING DETAILS 7 3544.3 72.37 212.00 2995.0 - 1211.9 -430.5 0.00 0.00 438.7 Plan: ODSN -45i IN13 wp10 8 3912.8 72.37 217.80 3106.7 - 1499.8 -631.3 1.50 90.88 641.5 TVD MD Name Size 9 7192.4 72.37 217.80 4100.0 - 3969.6 - 2547.1 0.00 0.00 2573.9 2995.0 3544.3 9 5/8" 9.625 10 7197.0 72.38 217.97 4101.4 - 3973.0 - 2549.7 3.50 85.37 2576.6 6247.5 14218.5 7" 7.000 600 11 9689.4 72.38 217.97 4855.7 - 5845.8 - 4011.1 0.00 0.00 4050.6 12 11902.0 72.39 300.00 5650.0 - 6206.5 - 5864.0 3.50 104.74 5905.9 IN13 v10 T1E Total Depth at 20345.10' MD, 6262.50' TVD 13 12552.6 73.11 320.43 5844.8 - 5807.6 - 6335.4 3.00 90.96 6374.6 Start Dir 1.00 /100' 500.00' MD, 500.00' TVD 14 13655.4 73.11 320.43 6165.1 - 4994.1 - 7007.6 0.00 0.00 7041.2 15 14218.5 90.00 320.00 6247.5 - 4567.7 - 7362.7 3.00 -1.49 7393.5 IN13 v9 T2A Start Dir 1.50/100' 1000.00' MD, 999.40' TVD . 0 - \ I - .1N13 v9 117 16 14387.8 94.65 317.97 6240.6 - 4440.1 - 7473.7 3.00 -23.56 7503.6 - - -/ 17 15332.0 94.65 317.97 6164.0 - 3741.1 - 8103.9 0.00 0.00 8129.0 ODSN -45i IN 13 wplO 1 18 15492.0 90.00 316.80 6157.5 - 3623.5 - 8212.1 3.00 - 165.88 8236.4 IN13 v 9 T3 End Dir 1661.40' MD, 1650 TVD 2000 19 15679.9 84.36 316.81 6166.7 - 3486.7 - 8340.5 3.00 179.85 8363.9 - -600 20 16306.2 84.36 316.81 6228.3 - 3032.3 - 8767.0 0.00 0.00 8787.4 2soo 21 16494.2 90.00 316.67 6237.5 - 2895.6 - 8895.7 3.00 -1.48 8915.1 IN13 v9 T4 Start Dir 3.50/100' 1764.90' MD, 1750.00' a 2 22 16656.7 94.88 316.71 6230.6 - 2777.5 -9007.0 3.00 0.48 9025.6 End Dir 18903.50' MD, 6272.50' I I - ,3 v N19 TTi 23 17552.6 94.88 316.71 6154.5 - 2127.8 - 9619.1 0.00 0.00 9633.3 9 9/8" -1200 - _ = 24 17716.2 90.00 316.14 6147.5 - 2009.5 - 9731.8 3.00 - 173.35 9745.1 IN13 v9 T5 25 17979.4 82.10 316.32 6165.6 - 1820.0 - 9913.3 3.00 178.66 9925.4 ' - 26 18623.6 82.10 316.32 6254.1 - 1358.4 - 10354.0 0.00 0.00 10362.9 0' Start Dir 1.50/100' 3544.30' MD, 2995.00' TVD Start Dir 3,00 /100' 18623.60' MD, 6254.10' TVD 27 18891.1 90.00 314.89 6272.5 - 1167.9 - 10540.5 3.00 -10.32 10548.1 IN13 v9 T6 28 18903.5 90.37 314.89 6272.5 - 1159.2 - 10549.3 3.00 0.00 10556.9 , -1800 End Dir 17979.40' MD, 6165.60' TVD I 29 20434.4 90.37 314.89 6262.5 -78.8 - 11633.8 0.00 0.00 11634.1 IN13 v9 T7 \\ End Dir 3526.00' MD, 2989.50' TVD 1 [N13 v9 T ■ Start Dir 3.00 /100' 17552.60' MD, 6154.530' TVD -2400 j End Dir 3912.80' MD, 3106.70' TVD C End Dir 16656.70' MD, 6230 TVD I DDI =7.15 �o i - - - I IN13 v9 Ti1 -3000 .- Start Dir 3.00/100' 16306.20' MD, 6228.30' TVD t p __ - I - IIN13 v9 '13 -3600 ._ - - - - _ End Dir 15679.90' MD, 6166.70' TVD - a q°b o - 4200 _ - • , L Start Dir 3.50/100' 7192.40' MD, 4100.00' TVD •� Start Dir 3.00/100' 15332.00' MD, 6164.00' TVD 7" IIN13 v9 T2A _ l i s - 4800 End Dir 14387.80' MD, 6240 TVD 1 • _ _ - 9 End Dir 12552.60' MD, 5844.80' TVD End Dir 7197.00' MD, 4101.40' TVD s Start Dir 3.00/100' 13655.40' MD, 6165.10' TVD -5400 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) - 6000 - - I 8 • Name TVD +N / -S +E/ -W Northing Easting Shape Geopoly HRZ 5650.0 - 7869.1 - 4817.8 6023156.89 464972.69 Polygon N13 v10 TIB 5650.0 - 6206.5 - 5864.0 6024823.52 463933.28 Point /I . IN13 v9 T5 6147.5 - 2009.5 - 9731.8 6029035.80 460083.00 Point • . COMPANY DETAILS: Well Planning - Pioneer - Oooguruk -6600 IN13 vt0 T Geo Poly 6150.0 - 4778.1 - 7394.6 6026257.97 462408.70 Polygon IN13 v9 T3 6157.5 - 3623.5 - 8212.1 6027415.78 461595.98 Point Start Dir 3.50 /100' 9689.40' MD 4855.70' TVD Calculation Method: Minimum Curvature Error System:ISCWSA IN13v9T4 6237.5 - 2895.6 - 8895.7 6028146.33 460915.41 Point Scan Method: Tray. Cylinder North - IN13 v9 T2A 6247.5 - 4567.7 - 7362.7 6026468.22 462441.42 Point Error Surface: Elliptical Conic -7200 IN13 v9 T7 6262.5 -78.8 - 11633.8 6030974.00 458189.00 Point Warning Method: Rules Based IN13 v9 T6 6272.5 - 1167.9 - 10540.5 6029880.50 459277.80 Point -12600 -12000 -11400 -10800 -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 - 4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 West( - )/East( +) (1500 ft/in) • • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM _Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS-45 Company: Well Planning - Pioneer - Oooguruk ND Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) • Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) , Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Wellbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Project Oooguruk Developement Map System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSN -45i - Slot ODS -45 Well Position +N /-S 0.0 ft Northing: 6,031,005.53 ft • Latitude: 70° 29' 44.804 N +E / -W 0.0 ft Easting: 469,821.86 ft , Longitude: 150° 14' 48.350 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft . Wellbore ODSN -45i PN13 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 3/6/2007 23.24 80.81 57,643 Design ODSN -45i IN13 wp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 44.0 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) (bearing) 44.0 0.0 0.0 269.61 6/10/2008 5 :27 :14PM Page 2 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: ' Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Weilbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Man Sections Measured Vertical TVD Dogleg Build Turn Depth inclination Azimuth Depth System +NI-S +E / -W Rate ' Rate Rate Tool Face (ft) ( ?) ( (ft) ft (ft) (ft) ( ? /10(Ift) (7/100ft) ( ?/100ft) ( ?) 44.0 0.00 0.00 44.0 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 500.0 0.00 0.00 500.0 442.5 0.0 0.0 0.00 0.00 0.00 0.00 1,000.0 5.00 170.00 999.4 9419 -21.5 3.8 1.00 1.00 0.00 170.00 1,661.4 14.92 170.00 1,650.0 1,592.5 -134.0 23.6 1.50 1.50 0.00 0.00 1,764.9 14.92 170.00 1,750.0 1,692.5 -160.2 28.3 0.00 0.00 0.00 0.00 3,526.0 72.37 212.00 2,989.5 2,932.0 - 1,197.2 -421.3 3.50 3.26 2.38 46.44 3,544.3 72.37 212.00 2,995.0 2,937.5 - 1,211.9 -430.5 0.00 0.00 0.00 0.00 3,912.8 72.37 217.80 3,106.7 3,049.2 - 1,499.8 -631.3 1.50 0.00 1.57 90.88 7,192.4 72.37 217.80 4,100.0 4,042.5 - 3,969.6 - 2,547.1 0.00 0.00 0.00 0.00 7,197.0 72.38 217.97 4,101.4 4,043.9 - 3,973.0 - 2,549.7 3.50 0.28 3.66 85.37 9,689.4 72.38 217.97 4,855.7 4,798.2 - 5,845.8 - 4,011.1 0.00 0.00 0.00 0.00 11,902.0 72.39 300.00 5,650.0 5,592.5 - 6,206.5 - 5,864.0 3.50 0.00 3.71 104.74 12,552.6 73.11 320.43 5,844.8 5,787.3 - 5,807.6 - 6,335.4 3.00 0.11 3.14 90.96 13,655.4 73.11 320.43 6,165.1 6,107.6 - 4,994.1 - 7,007.6 0.00 0.00 0.00 0.00 14,218.5 90.00 320.00 6,247.5 6,190.0 - 4,567.7 - 7,362.7 3.00 3.00 -0.08 -1.49 14,387.8 94.65 317.97 6,240.6 6,183.1 - 4,440.1 - 7,473.7 3.00 2.75 -1.20 -23.56 15,332.0 94.65 317.97 6,164.0 6,106.5 - 3,741.1 - 8,103.9 0.00 0.00 0.00 0.00 15,492.0 90.00 316.80 6,157.5 6,100.0 - 3,623.5 - 8,212.1 3.00 -2.91 -0.73 - 165.88 15,679.9 84.36 316.81 6,166.7 6,109.2 - 3,486.7 - 8,340.5 3.00 -3.00 0.01 179.85 16,306.2 84.36 316.81 6,228.3 6,170.8 - 3,032.3 - 8,767.0 0.00 0.00 0.00 0.00 16,494.2 90.00 316.67 6,237.5 6,180.0 - 2,895.6 - 8,895.7 3.00 3.00 -0.08 -1.48 16,656.7 94.88 316.71 6,230.6 6,173.1 - 2,777.5 - 9,007.0 3.00 3.00 0.03 0.48 17,552.6 94.88 316.71 6,154.5 6,097.0 - 2,127.8 - 9,619.1 0.00 0.00 0.00 0.00 17,716.2 90.00 316.14 6,147.5 6,090.0 - 2,009.5 - 9,731.8 3.00 -2.98 -0.35 - 173.35 17,979.4 82.10 316.32 6,165.6 6,108.1 - 1,820.0 - 9,913.3 3.00 -3.00 0.07 178.66 18,623.6 82.10 316.32 6,254.1 6,196.6 - 1,358.4 - 10,354.0 0.00 0.00 0.00 0.00 18,891.1 90.00 314.89 6,272.5 6,215.0 - 1,167.9 - 10,540.5 3.00 2.95 -0.54 -10.32 18,903.5 90.37 314.89 6,272.5 6,215.0 - 1,159.2 - 10,549.3 3.00 3.00 0.00 0.00 20,434.4 90.37 314.89 6,262.5 6,205.0 -78.8 - 11,633.8 0.00 0.00 0.00 0.00 l 6/10/2008 5:27:14PM Page 3 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS-45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) • Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Welibore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N /-S +E/-W Northing Easting DLS Vert Section (ft) (Z) (bearing) (ft) ft (ft) (ft) (ft) (ft) -13.50 44.0 0.00 0.00 44.0 -13.5 0.0 0.0 6,031,005.53 • 469,821.86 • 0.00 0.00 100.0 0.00 0.00 100.0 42.5 0.0 0.0 6,031,005.53 469,821.86 0.00 0.00 200.0 0.00 0.00 200.0 142.5 0.0 0.0 6,031,005.53 469,821.86 0.00 0.00 300.0 0.00 0.00 300.0 242.5 0.0 0.0 6,031,005.53 469,821.86 0.00 0.00 400.0 0.00 0.00 400.0 342.5 0.0 0.0 6,031,005.53 469,821.86 0.00 0.00 500.0 0.00 0.00 500.0 442.5 0.0 0.0 6,031,005.53 469,821.86 0.00 0.00 • Start Dir 1.00/100' 500.00' MD, 500.00' TVD 600.0 1.00 170.00 600.0 542.5 -0.9 0.1 6,031,004.67 469,822.01 1.00 -0.15 700.0 2.00 170.00 700.0 642.5 -3.4 0.6 6,031,002.09 469,822.45 1.00 -0.58 800.0 3.00 170.00 799.9 742.4 -7.7 1.4 6,030,997.79 469,823.19 1.00 -1.31 900.0 4.00 170.00 899.7 842.2 -13.7 2.4 6,030,991.78 469,824.23 1.00 -2.33 1,000.0 5.00 170.00 999.4 941.9 -21.5 3.8 6,030,984.05 469,825.56 1.00 -3.64 Start Dir 1.50/100' 1000.00' MD, 999.40' TVD 1,100.0 6.50 170.00 1,098.9 1,041.4 -31.3 5.5 6,030,974.17 469,827.26 1.50 -5.31 1,200.0 8.00 170.00 1,198.1 1,140.6 -43.8 7.7 6,030,961.74 469,829.40 1.50 -7.42 1,300.0 9.50 170.00 1,296.9 1,239.4 -58.7 10.4 6,030,946.75 469,831.98 1.50 -9.96 1,400.0 11.00 170.00 1,395.3 1,337.8 -76.3 13.4 6,030,929.22 469,835.00 1.50 -12.93 1,500.0 12.50 170.00 1,493.2 1,435.7 -96.3 17.0 6,030,909.15 469,838.45 1.50 -16.33 1,600.0 14.00 170.00 1,590.5 1,533.0 -118.9 21.0 6,030,886.56 469,842.34 1.50 -20.16 1,617.5 14.26 170.00 1,607.5 1,550.0 -123.1 21.7 6,030,882.35 469,843.06 1.50 -20.87 Base of Permafrost 1,661.4 14.92 170.00 1,650.0 1,592.5 -134.0 23.6 6,030,871.46 469,844.94 1.50 -22.72 End Dir 1661.40' MD, 1650.00' TVD 1,700.0 14.92 170.00 1,687.3 1,629.8 -143.8 25.4 6,030,861.66 469,846.62 0.00 -24.38 1,764.9 14.92 170.00 1,750.0 1,692.5 -160.2 28.3 6,030,845.19 469,849.46 0.00 -27.17 Start Dir 3.50/100' 1764.90' MD, 1750.00' TVD 1,800.0 15.79 173.27 1,783.8 1,726.3 -169.4 29.6 6,030,836.00 469,850.77 3.50 -28.45 1,900.0 18.49 180.86 1,879.4 1,821.9 -198.8 31.0 6,030,806.61 469,852.00 3.50 -29.61 2,000.0 21.42 186.50 1,973.4 1,915.9 -232.8 28.7 6,030,772.62 469,849.56 3.50 -27.08 2,100.0 24.49 190.82 2,065.5 2,008.0 -271.3 22.7 6,030,734.14 469,843.45 3.50 -20.86 2,200.0 27.66 194.21 2,155.3 2,097.8 -314.2 13.1 6,030,691.31 469,833.69 3.50 -10.98 2,300.0 30.89 196.95 2,242.5 2,185.0 -361.3 -0.1 6,030,644.30 469,820.31 3.50 2.53 2,400.0 34.17 199.21 2,326.8 2,269.3 -412.4 -16.8 6,030,593.28 469,803.37 3.50 19.60 2,485.3 37.00 200.86 2,396.2 2,338.7 -459.0 -33.8 6,030,546.72 469,786.15 3.50 36.95 Top West Sak 2,500.0 37.49 201.12 2,407.9 2,350.4 -467.3 -37.0 6,030,538.45 469,782.94 3.50 40.19 2,600.0 40.83 202.76 2,485.4 2,427.9 -525.8 -60.7 6,030,480.00 469,759.08 3.50 64.21 2,700.0 44.20 204.20 2,559.1 2,501.6 -587.8 -87.6 6,030,418.16 469,731.89 3.50 91.57 2,800.0 47.58 205.46 2,628.7 2,571.2 -652.9 -117.8 6,030,353.15 469,701.46 3.50 122.18 2,900.0 50.97 206.60 2,693.9 2,636.4 -721.0 -151.0 6,030,285.22 469,667.91 3.50 155.91 3,000.0 54.37 207.64 2,754.6 2,697.1 -791.8 -187.3 6,030,214.62 469,631.38 3.50 192.64 3,100.0 57.78 208.59 2,810.4 2,752.9 -864.9 -226.4 6,030,141.62 469,591.98 3.50 232.24 3,200.0 61.20 209.47 2,861.1 2,803.6 -940.2 -268.2 , 6,030,066.48 469,549.87 3.50 274.56 3,300.0 64.62 210.29 2,906.7 2,849.2 - 1,017.4 -312.6 6,029,989.49 469,505.21 3.50 319.43 3,400.0 68.05 211.07 2,946.8 2,889.3 - 1,096.2 -359.3 6,029,910.93 469,458.16 3.50 366.70 6/10/2008 5 :27 :14PM Page 4 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALL1BURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN - 45i - Slot ODS - 45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Spa: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Wefbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 2,906.00 3,446.2 69.63 211.42 2,963.5 2,906.0 - 1,133.0 - 381.6 6,029,874.18 469,435.66 3.50 389.30 Hue Shales 3,500.0 71.48 211.81 2,981.4 2,923.9 - 1,176.2 -408.2 6,029,831.11 469,408.91 3.50 416.18 3,526.0 72.37 212.00 2,989.5 2,932.0 - 1,197.2 -421.3 6,029,810.18 469,395.76 3.50 429.38 End Dir 3526.00' MD, 2989.50' TVD 3,544.3 72.37 212.00 2,995.0 2,937.5 - 1,211.9 - 430.5 6,029,795.46 469,386.48 0.01 438.70 Start Dir 1.50/100' 3544.30' MD, 2995.00' TVD - 9 5/8" 3,600.0 72.36 212.88 3,011.9 2,954.4 - 1,256.8 -459.0 6,029,750.75 469,357.81 1.50 467.50 3,661.4 72.35 213.84 3,030.5 2,973.0 - 1,305.7 -491.2 6,029,702.02 469,325.43 1.50 500.01 Tuffaceous Shales 3,700.0 72.35 214.45 3,042.2 2,984.7 - 1,336.1 -511.8 6,029,671.66 469,304.67 1.50 520.86 3,800.0 72.35 216.03 3,072.5 3,015.0 - 1,413.9 -566.8 6,029,594.07 469,249.38 1.50 576.36 3,900.0 72.37 217.60 3,102.8 3,045.3 - 1,490.2 -623.9 6,029,518.01 469,191.97 1.50 633.98 3,912.8 72.37 217.80 3,106.7 3,049.2 - 1,499.9 -631.4 6,029,508.39 469,184.48 1.49 641.50 End Dir 3912.80' MD, 3106.70' TVD 4,000.0 72.37 217.80 3,133.1 3,075.6 - 1,565.5 -682.3 6,029,442.94 469,133.28 0.00 692.88 4,100.0 72.37 217.80 3,163.4 3,105.9 - 1,640.8 -740.7 6,029,367.88 469,074.57 0.00 751.80 4,200.0 72.37 217.80 3,193.7 3,136.2 - 1,716.1 -799.1 6,029,292.82 469,015.86 0.00 810.72 4,300.0 72.37 217.80 3,224.0 3,166.5 - 1,791.4 -857.5 6,029,217.76 468,957.15 0.00 869.64 4,400.0 72.37 217.80 3,254.3 3,196.8 - 1,866.7 -915.9 6,029,142.71 468,898.43 0.00 928.56 4,500.0 72.37 217.80 3,284.6 3,227.1 - 1,942.1 -974.4 6,029,067.65 468,839.72 0.00 987.48 4,600.0 72.37 217.80 3,314.8 3,257.3 - 2,017.4 - 1,032.8 6,028,992.59 468,781.01 0.00 1,046.40 4,700.0 72.37 217.80 3,345.1 3,287.6 - 2,092.7 - 1,091.2 6,028,917.53 468,722.30 0.00 1,105.33 4,800.0 72.37 217.80 3,375.4 3,317.9 - 2,168.0 - 1,149.6 6,028,842.47 468,663.59 0.00 1,164.25 4,900.0 72.37 217.80 3,405.7 3,348.2 - 2,243.3 - 1,208.0 6,028,767.41 468,604.88 0.00 1,223.17 5,000.0 72.37 217.80 3,436.0 3,378.5 - 2,318.6 - 1,266.4 6,028,692.35 468,546.17 0.00 1,282.09 5,100.0 72.37 217.80 3,466.3 3,408.8 - 2,393.9 - 1,324.8 6,028,617.29 468,487.45 0.00 1,341.01 5,200.0 72.37 217.80 3,496.6 3,439.1 - 2,469.2 - 1,383.2 6,028,542.23 468,428.74 0.00 1,399.93 5,300.0 72.37 217.80 3,526.8 3,469.3 - 2,544.5 - 1,441.7 6,028,467.18 468,370.03 0.00 1,458.85 5,400.0 72.37 217.80 3,557.1 3,499.6 - 2,619.8 - 1,500.1 6,028,392.12 468,311.32 0.00 1,517.77 5,500.0 72.37 217.80 3,587.4 3,529.9 - 2,695.1 - 1,558.5 6,028,317.06 468,252.61 0.00 1,576.69 5,600.0 72.37 217.80 3,617.7 3,560.2 - 2,770.4 - 1,616.9 6,028,242.00 468,193.90 0.00 1,635.61 5,700.0 72.37 217.80 3,648.0 3,590.5 - 2,845.7 - 1,675.3 6,028,166.94 468,135.19 0.00 1,694.53 5,800.0 72.37 217.80 3,678.3 3,620.8 - 2,921.0 - 1,733.7 6,028,091.88 468,076.48 0.00 1,753.45 5,900.0 72.37 217.80 3,708.6 3,651.1 - 2,996.3 - 1,792.1 6,028,016.82 468,017.76 0.00 1,812.37 6,000.0 72.37 217.80 3,738.9 3,681.4 - 3,071.6 - 1,850.5 6,027,941.76 467,959.05 0.00 1,871.29 6,100.0 72.37 217.80 3,769.1 3,711.6 - 3,146.9 - 1,909.0 6,027,866.70 467,900.34 0.00 1,930.21 6,200.0 72.37 217.80 3,799.4 3,741.9 - 3,222.2 - 1,967.4 6,027,791.64 467,841.63 0.00 1,989.13 6,300.0 72.37 217.80 3,829.7 3,772.2 - 3,297.5 - 2,025.8 6,027,716.59 467,782.92 0.00 2,048.05 6,400.0 72.37 217.80 3,860.0 3,802.5 - 3,372.8 - 2,084.2 6,027,641.53 467,724.21 0.00 2,106.97 6,500.0 72.37 217.80 3,890.3 3,832.8 - 3,448.1 - 2,142.6 6,027,566.47 467,665.50 0.00 2,165.89 6,600.0 72.37 217.80 3,920.6 3,863.1 - 3,523.4 - 2,201.0 6,027,491.41 467,606.78 0.00 2,224.81 6,700.0 72.37 217.80 3,950.9 3,893.4 - 3,598.7 - 2,259.4 6,027,416.35 467,548.07 0.00 2,283.74 6,800.0 72.37 217.80 3,981.1 3,923.6 - 3,674.0 - 2,317.8 6,027,341.29 467,489.36 0.00 2,342.66 6,900.0 72.37 217.80 4,011.4 3,953.9 - 3,749.4 - 2,376.2 6,027,266.23 467,430.65 0.00 Z401.58 6/10/2008 5:27:14PM Page 5 COMPASS 2003.16 Build 428 i • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN - 45i - Slot ODS - 45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN - 45i Survey Calculation Method: Minimum Curvature Welibore: ODSN - 45i PN13 Design: ODSN -45i 1N13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 3,984,22 7,000.0 72.37 217.80 4,041.7 3,984.2 - 3,824.7 - 2,434.7 6,027,191.17 467,371.94 0.00 2,460.50 7,100.0 72.37 217.80 4,072.0 4,014.5 - 3,900.0 - 2,493.1 6,027,116.11 467,313.23 0.00 2,519.42 7,192.4 72.37 217.80 4,100.0 4,042.5 - 3,969.5 - 2,547.0 6,027,046.76 467,258.98 0.00 2,573.86 Start Dir 3.50/100' 7192.40' MD, 4100.00' TVD 7,197.0 72.38 217.97 4,101.4 4,043.9 - 3,973.0 - 2,549.7 6,027,043.31 467,256.27 3.46 2,576.58 End Dir 7197.00' MD, 4101.40' TVD 7,200.0 72.38 217.97 4,102.3 4,044.8 - 3,975.3 - 2,551.5 6,027,041.06 467,254.51 0.00 2,578.35 7,300.0 72.38 217.97 4,132.6 4,075.1 - 4,050.4 - 2,610.1 6,026,966.17 467,195.57 0.00 2,637.49 7,400.0 72.38 217.97 4,162.8 4,105.3 - 4,125.5 - 2,668.8 6,026,891.28 467,136.64 0.00 2,696.63 7,500.0 72.38 217.97 4,193.1 4,135.6 - 4,200.7 - 2,727.4 6,026,816.38 467,077.71 0.00 2,755.78 7,600.0 72.38 217.97 4,223.4 4,165.9 - 4,275.8 - 2,786.0 6,026,741.49 467,018.77 0.00 2,814.92 7,649.7 72.38 217.97 4,238.4 4,180.9 - 4,313.2 - 2,815.2 6,026,704.27 466,989.48 0.00 2,844.31 Brook 2B 7,700.0 72.38 217.97 4,253.6 4,196.1 - 4,351.0 - 2,844.7 6,026,666.59 466,959.84 0.00 2,874.06 7,800.0 72.38 217.97 4,283.9 4,226.4 - 4,426.1 - 2,903.3 6,026,591.70 466,900.91 0.00 2,933.20 7,900.0 72.38 217.97 4,314.2 4,256.7 - 4,501.2 - 2,961.9 6,026,516.81 466,841.97 0.00 2,992.34 8,000.0 72.38 217.97 4,344.4 4,286.9 - 4,576.4 - 3,020.6 6,026,441.91 466,783.04 0.00 3,051.48 8,100.0 72.38 217.97 4,374.7 4,317.2 - 4,651.5 - 3,079.2 6,026,367.02 466,724.11 0.00 3,110.63 8,200.0 72.38 217.97 4,405.0 4,347.5 - 4,726.7 - 3,137.8 6,026,292.13 466,665.17 0.00 3,169.77 8,300.0 72.38 217.97 4,435.2 4,377.7 - 4,801.8 - 3,196.5 6,026,217.23 466,606.24 0.00 3,228.91 8,400.0 72.38 217.97 4,465.5 4,408.0 - 4,876.9 - 3,255.1 6,026,142.34 466,547.31 0.00 3,288.05 8,500.0 72.38 217.97 4,495.7 4,438.2 - 4,952.1 - 3,313.7 6,026,067.45 466,488.37 0.00 3,347.19 8,600.0 72.38 217.97 4,526.0 4,468.5 - 5,027.2 - 3,372.4 6,025,992.55 466,429.44 0.00 3,406.34 8,700.0 72.38 217.97 4,556.3 4,498.8 - 5,102.4 - 3,431.0 6,025,917.66 466,370.51 0.00 3,465.48 8,800.0 72.38 217.97 4,586.5 4,529.0 - 5,177.5 - 3,489.6 6,025,842.76 466,311.58 0.00 3,524.62 8,900.0 72.38 217.97 4,616.8 4,559.3 - 5,252.6 - 3,548.3 6,025,767.87 466,252.64 0.00 3,583.76 9,000.0 72.38 217.97 4,647.1 4,589.6 - 5,327.8 - 3,606.9 6,025,692.98 466,193.71 0.00 3,642.90 9,100.0 72.38 217.97 4,677.3 4,619.8 - 5,402.9 - 3,665.6 6,025,618.08 466,134.78 0.00 3,702.04 9,200.0 72.38 217.97 4,707.6 4,650.1 - 5,478.1 - 3,724.2 6,025,543.19 466,075.84 0.00 3,761.19 9,300.0 72.38 217.97 4,737.9 4,680.4 - 5,553.2 - 3,782.8 6,025,468.30 466,016.91 0.00 3,820.33 9,400.0 72.38 217.97 4,768.1 4,710.6 - 5,628.3 - 3,841.5 6,025,393.40 465,957.98 0.00 3,879.47 9,500.0 72.38 217.97 4,798.4 4,740.9 - 5,703.5 - 3,900.1 6,025,318.51 465,899.04 0.00 3,938.61 9,600.0 72.38 217.97 4,828.7 4,771.2 - 5,778.6 - 3,958.7 6,025,243.62 465,840.11 0.00 3,997.75 9,689.4 72.38 217.97 4,855.7 4,798.2 - 5,845.8 - 4,011.1 6,025,176.66 465,787.42 0.00 4,050.63 Start Dir 3.50/100' 9689.40' MD, 4855.70' TVD 9,700.0 72.29 218.34 4,858.9 4,801.4 - 5,853.7 - 4,017.4 6,025,168.74 465,781.15 3.50 4,056.92 9,800.0 71.44 221.92 4,890.1 4,832.6 - 5,926.4 - 4,078.6 6,025,096.35 465,719.63 3.50 4,118.64 9,900.0 70.65 225.52 4,922.6 4,865.1 - 5,994.7 - 4,144.0 6,025,028.28 465,654.02 3.50 4,184.45 10,000.0 69.94 229.16 4,956.3 4,898.8 - 6,058.5 - 4,213.2 6,024,964.78 465,584.55 3.50 4,254.10 10,100.0 69.31 232.83 4,991.1 4,933.6 - 6,117.5 - 4,286.0 6,024,906.09 465,511.49 3.50 4,327.32 10,179.8 68.85 235.78 5,019.6 4,962.1 - 6,161.0 - 4,346.5 6,024,862.88 465,450.82 3.50 4,388.11 Top torok Sand 10,200.0 68.75 236.53 5,026.9 4,969.4 - 6,171.5 - 4,362.2 6,024,852.44 465,435.11 3.50 4,403.86 10,300.0 68.27 240.26 5,063.6 5,006.1 - 6,220.2 - 4,441.4 6,024,804.01 465,355.69 3.50 4,483.42 10,400.0 67.88 244.01 5,100.9 5,043.4 - 6,263.6 - 4,523.4 6,024,761.00 465,273.53 3.50 4,565.70 6/10/2008 5 :27 :14PM Page 6 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALL1BURTDN Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Welibore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E./ -W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft), (ft) - (ft) (ft) 5,081.34 10,500.0 67.57 247.78 5,138.8 5,081.3 - 6,301.4 - 4,607.8 6,024,723.55 465,188.94 3.50 4,650.40 10,600.0 67.35 251.56 5,177.2 5,119.7 - 6,333.5 - 4,694.4 6,024,691.82 465,102.23 3.50 4,737.20 10,700.0 67.22 255.35 5,215.8 5,158.3 - 6,359.7 - 4,782.8 6,024,665.92 465,013.73 3.50 4,825.78 10,800.0 67.18 259.15 5,254.6 5,197.1 - 6,380.1 - 4,872.7 6,024,645.95 464,923.77 3.50 4,915.81 10,847.8 67.19 260.96 5,273.1 5,215.6 - 6,387.7 - 4,916.1 6,024,638.52 464,880.35 3.50 4,959.25 Base Torok Sand 10,900.0 67.23 262.94 5,293.3 5,235.8 - 6,394.4 - 4,963.8 6,024,631.97 464,832.68 3.50 5,006.95 11,000.0 67.37 266.74 5,331.9 5,274.4 - 6,402.7 - 5,055.6 6,024,624.05 464,740.79 3.50 5,098.86 11,100.0 67.60 270.52 5,370.2 5,312.7 - 6,404.9 - 5,148.0 6,024,622.22 464,648.47 3.50 5,191.20 11,200.0 67.91 274.28 5,408.1 5,350.6 - 6,401.0 - 5,240.4 6,024,626.47 464,556.04 3.50 5,283.62 11,300.0 68.31 278.03 5,445.4 5,387.9 - 6,391.1 - 5,332.6 6,024,636.79 464,463.86 3.50 5,375.79 11,400.0 68.80 281.75 5,482.0 5,424.5 - 6,375.1 - 5,424.3 6,024,653.15 464,372.26 3.50 5,467.35 11,500.0 69.36 285.45 5,517.7 5,460.2 - 6,353.1 - 5,515.1 6,024,675.49 464,281.59 3.50 5,557.96 11,600.0 70.01 289.12 5,552.4 5,494.9 - 6,325.3 - 5,604.6 6,024,703.71 464,192.19 3.50 5,647.30 11,700.0 70.73 292.76 5,586.0 5,528.5 - 6,291.6 - 5,692.5 6,024,737.73 464,104.39 3.50 5,735.01 11,800.0 71.52 296.36 5,618.4 5,560.9 - 6,252.3 - 5,778.6 6,024,777.40 464,018.52 3.50 5,820.78 11,900.0 72.37 299.93 5,649.4 5,591.9 - 6,207.4 - 5,862.4 6,024,822.58 463,934.90 3.50 5,904.29 11,902.0 72.39 300.00 5,650.0 5,592.5 - 6,206.5 - 5,864.0 6,024,823.52 463,933.28 3.50 5,905.91 IN13v10T1B 12,000.0 72.36 303.09 5,679.7 5,622.2 - 6,157.6 - 5,943.6 6,024,872.71 463,853.87 3.00 5,985.19 12,100.0 72.39 306.23 5,710.0 5,652.5 - 6,103.4 - 6,022.0 6,024,927.21 463,775.72 3.00 6,063.21 12,200.0 72.46 309.38 5,740.2 5,682.7 - 6,045.0 - 6,097.3 6,024,985.94 463,700.65 3.00 6,138.12 12,286.3 72.57 312.09 5,766.1 5,708.6 - 5,991.3 - 6,159.7 6,025,039.89 463,638.52 3.00 6,200.11 Top HRZ 12,300.0 72.59 312.52 5,770.2 5,712.7 - 5,982.5 - 6,169.4 6,025,048.73 463,628.89 3.00 6,209.72 12,400.0 72.76 315.66 5,800.0 5,742.5 - 5,916.1 - 6,237.9 6,025,115.42 463,560.61 3.00 6,277.83 12,500.0 72.98 318.79 5,829.5 5,772.0 - 5,845.9 - 6,302.8 6,025,185.81 463,496.01 3.00 6,342.24 12,552.6 73.11 320.43 5,844.8 5,787.3 - 5,807.6 - 6,335.4 6,025,224.26 463,463.57 3.00 6,374.58 End Dir 12552.60' MD, 5844.80' TVD 12,600.0 73.11 320.43 5,858.6 5,801.1 - 5,772.7 - 6,364.3 6,025,259.34 463,434.83 0.00 6,403.23 12,700.0 73.11 320.43 5,887.6 5,830.1 - 5,698.9 - 6,425.2 6,025,333.34 463,374.18 0.00 6,463.68 12,704.1 73.11 320.43 5,888.8 5,831.3 - 5,695.9 - 6,427.7 6,025,336.37 463,371.70 0.00 6,466.15 Base HRZ 12,800.0 73.11 320.43 5,916.7 5,859.2 - 5,625.1 - 6,486.2 6,025,407.35 463,313.54 0.00 6,524.13 12,900.0 73.11 320.43 5,945.7 5,888.2 - 5,551.4 - 6,547.1 6,025,481.35 463,252.89 0.00 6,584.58 13,000.0 73.11 320.43 5,974.8 5,917.3 - 5,477.6 - 6,608.1 6,025,555.36 463,192.25 0.00 6,645.03 13,012.6 73.11 320.43 5,978.4 5,920.9 - 5,468.3 - 6,615.7 6,025,564.65 463,184.63 0.00 6,652.62 Kalubik Marker 13,100.0 73.11 320.43 6,003.8 5,946.3 - 5,403.8 - 6,669.0 6,025,629.36 463,131.61 0.00 6,705.48 13,200.0 73.11 320.43 6,032.8 5,975.3 - 5,330.1 - 6,730.0 6,025,703.37 463,070.96 0.00 6,765.93 13,260.8 73.11 320.43 6,050.5 5,993.0 - 5,285.2 - 6,767.0 6,025,748.35 463,034.10 0.00 6,802.67 Top Kuparuk C 13,296.9 73.11 320.43 6,061.0 6,003.5 - 5,258.6 - 6,789.1 6,025,775.10 463,012.18 0.00 6,824.52 Base Kuparuk (LCU) 13,300.0 73.11 320.43 6,061.9 6,004.4 - 5,256.3 - 6,790.9 6,025,777.37 463,010.32 0.00 6,826.38 6/10/2008 5 :27 :14PM Page 7 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALL1BURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: ' 44' + 13.5' @ 57.5ft (Nabors 19AC) Project Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Wen: ODSN -45i Surrey Calculation Method: Minimum Curvature Welibore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth Typos +N /-S +F/ N Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,033.44 13,400.0 73.11 320.43 6,090.9 6,033.4 - 5,182.5 - 6,851.9 6,025,851.38 462,949.67 0.00 6,886.83 13,500.0 73.11 320.43 6,120.0 6,062.5 - 5,108.8 - 6,912.8 6,025,925.38 462,889.03 0.00 6,947.27 13,600.0 73.11 320.43 6,149.0 6,091.5 - 5,035.0 - 6,973.8 6,025,999.39 462,828.39 0.00 7,007.72 13,655.4 73.11 320.43 6,165.1 6,107.6 - 4,994.1 - 7,007.6 6,026,040.39 462,794.79 0.00 7,041.21 Start Dir 3.00/100' 13655.40' MD, 6165.10' TVD 13,700.0 74.45 320.40 6,177.6 6,120.1 - 4,961.1 - 7,034.9 6,026,073.50 462,767.64 3.00 7,068.28 13,800.0 77.45 320.32 6,201.9 6,144.4 - 4,886.4 - 7,096.7 6,026,148.43 462,706.06 3.00 7,129.65 13,900.0 80.45 320.24 6,221.0 6,163.5 - 4,811.0 - 7,159.4 6,026,224.16 462,643.67 3.00 7,191.85 13,918.5 81.00 320.23 6,224.0 6,166.5 - 4,796.9 - 7,171.1 6,026,238.25 462,632.04 3.00 7,203.44 Top Nuiqsut 14,000.0 83.45 320.16 6,235.0 6,177.5 - 4,734.9 - 7,222.8 6,026,300.48 462,580.61 3.00 7,254.71 14,100.0 86.45 320.09 6,243.8 6,186.3 - 4,658.5 - 7,286.7 6,026,377.17 462,517.08 3.00 7,318.04 14,200.0 89.45 320.01 6,247.4 6,189.9 - 4,581.8 - 7,350.8 6,026,454.02 462,453.23 3.00 7,381.68 14,218.5 90.00 320.00 6,247.5 6,190.0 - 4,567.7 - 7,362.7 6,026,468.22 462,441.42 2.99 7,393.45 7 " IN13v9T2A 14,300.0 92.24 319.02 6,245.9 6,188.4 - 4,505.7 - 7,415.6 6,026,530.42 462,388.75 3.00 7,445.96 14,387.8 94.65 317.97 6,240.6 6,183.1 - 4,440.1 - 7,473.7 6,026,596.27 462,330.95 3.00 7,503.59 End Dir 14387.80' MD, 6240.60' TVD 14,400.0 94.65 317.97 6,239.6 6,182.1 - 4,431.0 - 7,481.8 6,026,605.34 462,322.85 0.00 7,511.67 14,500.0 94.65 317.97 6,231.5 6,174.0 - 4,357.0 - 7,548.6 6,026,679.63 462,256.42 0.00 7,577.90 14,600.0 94.65 317.97 6,223.4 6,165.9 - 4,283.0 - 7,615.3 6,026,753.92 462,189.99 0.00 7,644.14 14,700.0 94.65 317.97 6,215.3 6,157.8 - 4,209.0 - 7,682.1 6,026,828.21 462,123.56 0.00 7,710.37 14,800.0 94.65 317.97 6,207.2 6,149.7 - 4,134.9 - 7,748.8 6,026,902.50 462,057.13 0.00 7,776.61 14,900.0 94.65 317.97 6,199.1 6,141.6 - 4,060.9 - 7,815.5 6,026,976.79 461,990.70 0.00 7,842.84 15,000.0 94.65 317.97 6,190.9 6,133.4 - 3,986.9 - 7,882.3 6,027,051.09 461,924.27 0.00 7,909.08 15,100.0 94.65 317.97 6,182.8 6,125.3 - 3,912.8 - 7,949.0 6,027,125.38 461,857.84 0.00 7,975.31 15,200.0 94.65 317.97 6,174.7 6,117.2 - 3,838.8 - 8,015.7 6,027,199.67 461,791.41 0.00 8,041.54 15,300.0 94.65 317.97 6,166.6 6,109.1 - 3,764.8 - 8,082.5 6,027,273.96 461,724.98 0.00 8,107.78 15,332.0 94.65 317.97 6,164.0 6,106.5 - 3,741.1 - 8,103.8 6,027,297.73 461,703.72 0.00 8,128.97 Start Dir 3.00/100' 15332.00' MD, 6164.00' TVD 15,400.0 92.68 317.47 6,159.6 6,102.1 - 3,690.9 - 8,149.5 6,027,348.12 461,658.28 3.00 8,174.29 15,492.0 90.00 316.80 6,157.5 6,100.0 - 3,623.5 - 8,212.1 6,027,415.78 461,595.98 3.00 8,236.41 IN13v9T3 15,500.0 89.76 316.80 6,157.5 6,100.0 - 3,617.7 - 8,217.5 6,027,421.62 461,590.54 3.00 8,241.83 15,600.0 86.76 316.80 6,160.6 6,103.1 - 3,544.8 - 8,285.9 6,027,494.74 461,522.43 3.00 8,309.75 15,679.9 84.36 316.81 6,166.7 6,109.2 - 3,486.7 - 8,340.5 6,027,553.03 461,468.15 3.00 8,363.88 End Dir 15679.90' MD, 6166.70' TVD 15,700.0 84.36 316.81 6,168.7 6,111.2 - 3,472.2 - 8,354.2 6,027,567.67 461,454.52 0.01 8,377.47 15,800.0 84.36 316.81 6,178.5 6,121.0 - 3,399.6 - 8,422.3 6,027,640.50 461,386.71 0.00 8,445.09 15,900.0 84.36 316.81 6,188.4 6,130.9 - 3,327.0 - 8,490.4 6,027,713.32 461,318.91 0.00 8,512.70 16,000.0 84.36 316.81 6,198.2 6,140.7 - 3,254.5 - 8,558.5 6,027,786.15 461,251.10 0.00 8,580.32 16,100.0 84.36 316.81 6,208.0 6,150.5 - 3,181.9 - 8,626.6 6,027,858.97 461,183.29 0.00 8,647.94 16,200.0 84.36 316.81 6,217.8 6,160.3 - 3,109.4 - 8,694.7 6,027,931.80 461,115.48 0.00 8,715.55 16,300.0 84.36 316.81 6,227.6 6,170.1 - 3,036.8 - 8,762.8 6,028,004.63 461,047.68 0.00 8,783.17 6/10/2008 5 :27 :14PM Page 8 COMPASS 2003.16 Build 428 1 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Wetlbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,170.76 16,306.2 84.36 316.81 6,228.3 6,170.8 - 3,032.3 - 8,767.0 6,028,009.14 461,043.47 0.00 8,787.36 Start Dir 3.00/100' 18306.20' MD, 6228.30' TVD 16,400.0 87.18 316.74 6,235.2 6,177.7 - 2,964.2 - 8,831.1 6,028,077.55 460,979.70 3.00 8,850.96 16,494.2 90.00 316.67 6,237.5 6,180.0 - 2,895.6 - 8,895.7 6,028,146.33 460,915.41 3.00 8,915.07 IN13v9T4 16,500.0 90.17 316.67 6,237.5 6,180.0 - 2,891.4 - 8,899.7 6,028,150.57 460,911.44 3.00 8,919.02 16,600.0 93.17 316.69 6,234.6 6,177.1 - 2,818.7 - 8,968.2 6,028,223.55 460,843.17 3.00 8,987.10 16,656.7 94.88 316.71 6,230.6 6,173.1 - 2,777.5 - 9,007.0 6,028,264.87 460,804.56 3.00 9,025.61 End Dir 16656.70' MD, 6230.60' TVD 16,700.0 94.88 316.71 6,226.9 6,169.4 - 2,746.1 - 9,036.6 6,028,296.38 460,775.10 0.00 9,054.98 16,800.0 94.88 316.71 6,218.4 6,160.9 - 2,673.6 - 9,104.9 6,028,369.18 460,707.08 0.00 9,122.81 16,900.0 94.88 316.71 6,209.9 6,152.4 - 2,601.1 - 9,173.2 6,028,441.97 460,639.05 0.00 9,190.65 17,000.0 94.88 316.71 6,201.4 6,143.9 - 2,528.6 - 9,241.6 6,028,514.76 460,571.03 0.00 9,258.48 17,100.0 94.88 316.71 6,192.9 6,135.4 - 2,456.0 - 9,309.9 6,028,587.55 460,503.01 0.00 9,326.31 17,200.0 94.88 316.71 6,184.4 6,126.9 - 2,383.5 - 9,378.2 6,028,660.34 460,434.98 0.00 9,394.15 17,300.0 94.88 316.71 6,175.9 6,118.4 - 2,311.0 - 9,446.6 6,028,733.13 460,366.96 0.00 9,461.98 17,400.0 94.88 316.71 6,167.4 6,109.9 - 2,238.5 - 9,514.9 6,028,805.92 460,298.93 0.00 9,529.81 17,500.0 94.88 316.71 6,158.9 6,101.4 - 2,166.0 - 9,583.2 6,028,878.71 460,230.91 0.00 9,597.65 17,552.6 94.88 316.71 6,154.5 6,097.0 - 2,127.8 - 9,619.1 6,028,917.00 460,195.13 0.00 9,633.33 Start Dir 3.00/100' 17552.60' MD, 6154.530' TVD 17,600.0 93.46 316.54 6,151.0 6,093.5 - 2,093.4 - 9,651.6 6,028,951.49 460,162.81 3.00 9,665.56 17,700.0 90.48 316.19 6,147.6 6,090.1 - 2,021.1 - 9,720.6 6,029,024.09 460,094.15 3.00 9,734.02 17,716.2 90.00 316.14 6,147.5 6,090.0 - 2,009.5 - 9,731.8 6,029,035.80 460,083.00 3.00 9,745.15 IN13v9T5 17,800.0 87.49 316.20 6,149.3 6,091.8 - 1,949.0 - 9,789.8 6,029,096.48 460,025.22 3.00 9,802.77 17,900.0 84.49 316.27 6,156.3 6,098.8 - 1,877.0 - 9,858.8 6,029,168.78 459,956.52 3.00 9,871.27 17,979.4 82.11 316.32 6,165.6 6,108.1 - 1,820.0 - 9,913.3 6,029,226.00 459,902.28 3.00 9,925.37 End Dir 17979.40' MD, 6165.60' TVD 18,000.0 82.10 316.32 6,168.4 6,110.9 - 1,805.2 - 9,927.4 6,029,240.81 459,888.25 0.00 9,939.36 18,100.0 82.10 316.32 6,182.2 6,124.7 - 1,733.6 - 9,995.8 6,029,312.72 459,820.14 0.00 10,007.28 18,200.0 82.10 316.32 6,195.9 6,138.4 - 1,661.9 - 10,064.2 6,029,384.63 459,752.04 0.00 10,075.19 18,300.0 82.10 316.32 6,209.6 6,152.1 - 1,590.3 - 10,132.6 6,029,456.54 459,683.93 0.00 10,143.11 18,400.0 82.10 316.32 6,223.4 6,165.9 - 1,518.7 - 10,201.0 6,029,528.45 459,615.83 0.00 10,211.02 18,500.0 82.10 316.32 6,237.1 6,179.6 - 1,447.0 - 10,269.4 6,029,600.36 459,547.73 0.00 10,278.94 18,600.0 82.10 316.32 6,250.9 6,193.4 - 1,375.4 - 10,337.8 6,029,672.27 459,479.62 0.00 10,346.86 18,623.6 82.10 316.32 6,254.1 6,196.6 - 1,358.5 - 10,353.9 6,029,689.25 459,463.55 0.00 10,362.89 Start Dir 3.00/100' 18623.60' MD, 6254.10' TVD 18,700.0 84.36 315.91 6,263.1 6,205.6 - 1,303.8 - 10,406.5 6,029,744.13 459,411.19 3.00 10,415.10 18,800.0 87.31 315.38 6,270.4 6,212.9 - 1,232.5 - 10,476.2 6,029,815.71 459,341.77 3.00 10,484.34 18,891.1 90.00 314.89 6,272.5 6,215.0 - 1,167.9 - 10,540.5 6,029,880.50 459,277.80 3.00 10,548.13 IN13v9T6 18,900.0 90.27 314.89 6,272.5 6,215.0 - 1,161.7 - 10,546.8 6,029,886.81 459,271.51 3.00 10,554.40 18,903.5 90.37 314.89 6,272.5 6,215.0 - 1,159.2 - 10,549.3 6,029,889.29 459,269.04 3.00 10,556.87 End Dir 18903.50' MD, 6272.50' TVD 19,000.0 90.37 314.89 6,271.8 6,214.3 - 1,091.1 - 10,617.6 6,029,957.67 459,200.96 0.00 10,624.77 6/10/2008 5:27:14PM Page 9 COMPASS 2003.16 Build 428 • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) • Site: Oooguruk Drill Site North Reference: True Weil: ODSN -45i Survey Calculation Method: Minimum Curvature Weitbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E./-W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,213.68 19,100.0 90.37 314.89 6,271.2 6,213.7 - 1,020.5 - 10,688.5 6,030,028.52 459,130.41 0.00 10,695.13 19,200.0 90.37 314.89 6,270.5 6,213.0 -949.9 - 10,759.3 6,030,099.38 459,059.86 0.00 10,765.50 19,300.0 90.37 314.89 6,269.9 6,212.4 -879.4 - 10,830.2 6,030,170.23 458,989.32 0.00 10,835.86 19,400.0 90.37 314.89 6,269.2 6,211.7 -808.8 - 10,901.0 6,030,241.08 458,918.77 0.00 10,906.23 19,500.0 90.37 314.89 6,268.6 6,211.1 -738.2 - 10,971.8 6,030,311.94 458,848.22 0.00 10,976.59 19,600.0 90.37 314.89 6,267.9 6,210.4 -667.6 - 11,042.7 6,030,382.79 458,777.67 0.00 11,046.95 19,700.0 90.37 314.89 6,267.3 6,209.8 -597.1 - 11,113.5 6,030,453.65 458,707.12 0.00 11,117.32 19,800.0 90.37 314.89 6,266.6 6,209.1 -526.5 - 11,184.4 6,030,524.50 458,636.57 0.00 11,187.68 19,900.0 90.37 314.89 6,266.0 6,208.5 -455.9 - 11,255.2 6,030,595.35 458,566.02 0.00 11,258.05 20,000.0 90.37 314.89 6,265.3 6,207.8 -385.3 - 11,326.1 6,030,666.21 458,495.47 0.00 11,328.41 20,100.0 90.37 314.89 6,264.7 6,207.2 -314.8 - 11,396.9 6,030,737.06 458,424.92 0.00 11,398.78 20,200.0 90.37 314.89 6,264.0 6,206.5 -244.2 - 11,467.8 6,030,807.92 458,354.37 0.00 11,469.14 20,300.0 90.37 314.89 6,263.4 6,205.9 -173.6 - 11,538.6 6,030,878.77 458,283.82 0.00 11,539.51 20,400.0 90.37 314.89 6,262.7 6,205.2 -103.0 - 11,609.4 6,030,949.63 458,213.27 0.00 11,609.87 20,434.4 • 90.37 314.89 6,262.5 . 6,205.0 -78.8 - 11,633.8 6,030,974.00 458,189.00 0.00 11,634.07 Total Depth at 20345.10' MD, 6262.50' TVD -1N13 v9 '17 6/10/2008 5:27:14PM Page 10 COMPASS 2003.16 Build 428 i • Sperry Drilling Services HALL1BURTOII J Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -45i - Slot ODS -45 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -45i Survey Calculation Method: Minimum Curvature Wellbore: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/ -W Northing Easting - Shape (7) (bearing (ft) (ft) (ft) (ft) (ft) IN13 v9 T4 0.00 0.00 6,237.5 - 2,895.6 - 8,895.7 6,028,146.33 460,915.41 - plan hits target - Point IN13 v9 T5 0.00 0.00 6,147.5 - 2,009.5 - 9,731.8 6,029,035.80 460,083.00 - plan hits target - Point IN13 v9 T6 0.00 0.00 6,272.5 - 1,167.9 - 10,540.5 6,029,880.50 459,277.80 - plan hits target - Point Geo Poly 0.00 0.00 6,150.0 - 4,778.1 - 7,394.6 6,026,257.97 462,408.70 - plan misses by 184.2ft at 14069.2ft MD (6241.7 TVD, - 4682.0 N, - 7266.9 E) - Polygon Point 1 6,150.0 - 4,778.1 - 7,394.6 6,026,257.97 462,408.70 Point 2 6,150.0 -966.4 - 10,990.1 6,030,083.85 458,829.07 Point 3 6,150.0 -884.2 - 11,066.8 6,030,166.35 458,752.71 Point4 6,150.0 -872.7 - 10,488.1 6,030,175.50 459,331.39 Point 5 6,150.0 -904.8 - 10,458.5 6,030,143.28 459,360.86 Point 6 6,150.0 - 4,551.4 - 7,015.2 6,026,483.11 462,788.98 Point 7 6,150.0 - 4,597.4 - 6,972.9 6,026,436.94 462,831.09 Point 8 6,150.0 - 6,028.5 - 5,873.7 6,025,001.53 463,924.36 Point 9 6,150.0 - 6,245.6 - 6,275.0 6,024,786.09 463,522.22 Point 10 6,150.0 - 4,778.1 - 7,394.6 6,026,257.97 462,408.70 IN13 v9 T7 0.00 0.00 6,262.5 -78.8 - 11,633.8 6,030,974.00 458,189.00 - plan hits target - Point IN13 v9 T3 0.00 0.00 6,157.5 - 3,623.5 - 8,212.1 6,027,415.78 461,595.98 - plan hits target - Point IN13 v9 T2A 0.00 0.00 6,247.5 - 4,567.7 - 7,362.7 6,026,468.22 462,441.42 - plan hits target - Point IN13 v10 TIB 0.00 0.00 5,650.0 - 6,206.5 - 5,864.0 6,024,823.52 463,933.28 - plan hits target - Pant Geopoly HRZ 0.00 0.00 5,650.0 - 7,869.1 - 4,817.8 6,023,156.89 464,972.69 - plan misses by 1519.2ft at 11000.0ft MD (5331.9 TVD, - 6402.7 N, - 5055.6 E) - Polygon Point 1 5,650.0 - 6,243.4 - 5,639.5 6,024,785.75 464,157.68 Point 2 5,650.0 - 5,689.5 - 5,835.3 6,025,340.38 463,964.15 Point 3 5,650.0 - 5,218.6 - 6,493.5 6,025,813.90 463,307.93 Point 5,650.0 - 7,279.8 - 5,611.5 6,023,749.35 464,181.47 Point 5 5,650.0 - 8,066.7 - 5,107.0 6,022,960.49 464,682.72 Point 6 5,650.0 - 8,442.8 - 4,813.3 6,022,583.23 464,974.86 Point 7 5,650.0 - 8,225.9 - 4,581.2 6,022,799.17 465,207.82 Point 8 5,650.0 - 7,869.1 - 4,817.8 6,023,156.89 464,972.69 • 6/10/2008 5 :27 :14PM Page 11 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN - 45i - Slot ODS Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Weil: ' ODSN -45i Survey Calculation Method: Minimum Curvature Weiibere: ODSN -45i PN13 Design: ODSN -45i IN13 wp10 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,544.3 2,995.0 9 5/8" 9.625 12.250 14,218.5 6,247.5 7" 7.000 8.750 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ?) (bearing) 3,446.2 2,963.5 Hue Shales 0.00 13,918.5 6,224.0 Top Nuiqsut 0.00 13,296.9 6,061.0 Base Kuparuk (LCU) 0.00 12,704.1 5,888.8 Base HRZ 0.00 7,649.7 4,238.4 Brook 2B 0.00 10,179.8 5,019.6 Top torok Sand 0.00 13,260.8 6,050.5 Top Kuparuk C 0.00 1,617.5 1,607.5 Base of Permafrost 0.00 13,012.6 5,978.4 Kalubik Marker 0.00 3,661.4 3,030.5 Tuffaceous Shales 0.00 12,286.3 5,766.1 Top HRZ 0.00 2,485.3 2,396.2 Top West Sak 0.00 10,847.8 5,273.1 Base Torok Sand 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/S +E / -W (ft) (ft) (ft) (ft) Comment 500.0 500.0 0.0 0.0 Start Dir 1.00/100' 500.00' MD, 500.00' TVD 1,000.0 999.4 -21.5 3.8 Start Dir 1.50/100' 1000.00' MD, 999.40' TVD 1,661.4 1,650.0 -134.0 23.6 End Dir 1661.40' MD, 1650.00' TVD 1,764.9 1,750.0 -160.2 28.3 Start Dir 3.50/100' 1764.90' MD, 1750.00' TVD 3,526.0 2,989.5 - 1,197.2 -421.3 End Dir 3526.00' MD, 2989.50' TVD 3,544.3 2,995.0 - 1,212.0 -430.5 Start Dir 1.50/100' 3544.30' MD, 2995.00' TVD 3,912.8 3,106.7 - 1,499.9 -631.4 End Dir 3912.80' MD, 3106.70' TVD 7,192.4 4,100.0 - 3,969.5 - 2,547.0 Start Dir 3.50/100' 7192.40' MD, 4100.00' TVD 7,197.0 4,101.4 - 3,973.0 - 2,549.7 End Dir 7197.00' MD, 4101.40' TVD 9,689.4 4,855.7 - 5,845.8 - 4,011.1 Start Dir 3.50/100' 9689.40' MD, 4855.70' TVD 12,552.6 5,844.8 - 5,807.6 - 6,335.4 End Dir 12552.60' MD, 5844.80' TVD 13,655.4 6,165.1 - 4,994.1 - 7,007.6 Start Dir 3.00/100' 13655.40' MD, 6165.10' TVD 14,387.8 6,240.6 - 4,440.1 - 7,473.7 End Dir 14387.80' MD, 6240.60' TVD 15,332.0 6,164.0 - 3,741.1 - 8,103.8 Start Dir 3.00/100' 15332.00' MD, 6164.00' TVD 15,679.9 6,166.7 - 3,486.7 - 8,340.5 End Dir 15679.90' MD, 6166.70' TVD 16,306.2 6,228.3 - 3,032.3 - 8,767.0 Start Dir 3.00/100' 16306.20' MD, 6228.30' TVD 16,656.7 6,230.6 - 2,777.5 - 9,007.0 End Dir 16656.70' MD, 6230.60' TVD 17,552.6 6,154.5 - 2,127.8 - 9,619.1 Start Dir 3.00/100' 17552.60' MD, 6154.530' TVD 17,979.4 6,165.6 - 1,820.0 - 9,913.3 End Dir 17979.40' MD, 6165.60' TVD 18,623.6 6,254.1 - 1,358.5 - 10,353.9 Start Dir 3.00/100' 18623.60' MD, 6254.10' TVD 18,903.5 6,272.5 - 1,159.2 - 10,549.3 End Dir 18903.50' MD, 6272.50' TVD 20,434.4 6,262.5 -78.8 - 11,633.8 Total Depth at 20345.10' MD, 6262.50' TVD 6/10/2008 5:27:14PM Page 12 COMPASS 2003.16 Build 42B SURVEY PROGRAM ANTI - COLLISION SETTINGS ORO 11 0' MD NL Depth Range From: 0.0 To 1100.0 Date: 2008- 06- 05T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth From Depth To Survey /Plan Tool Results Limited B Centre Distance: 2090.0 44.0 1100.0 ODSN -4Si IN13 wp10 CB-GYRO-SS Reference: Plan: ODSN -45i IN13 wp10 (ODSN- 45i /ODSN -451 PN13) 1100.0 20434.4 ODSN- 451IN13 wp10 MWD+SAG+CA +IIFR +MS Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria ODSN -13 PS15 I ODSN -147 1513 I I ODSN -12 PS14 ODSN -15 PS14 ODSDW1 44 Dis ODSN 117 IS1 p os�l ODSN - PNI4 - F C To MD Ran e 0 - 1000 ODSN -16i IS1 0 ' 9 Range 0 -1100' 44 250 I pF'•' 30 J � � -. '' / 1 30 ODS K- 3 5KupB 250 500 330 .• - !;. 1. 1::;;; ODSN -17 PS16 30 330 �' 1 di ,,,4'..f.... ( / / J / j i . a ,s = _ / / • ,dl , 7 J /r r 500 750 / / J, , i !, = 4 . .,i /I I , ODSK -18 Kupl� IJ I ! ✓ / 750 1000 -/� // % . A y e i1 II( " ti, l, � � � � � r � , - 1000 1250 ��_.>✓1 . � 4, i,1 20 -4 V:6.1,00 . / / ,i 0' , • ' 1250 1500 ` ; ji�. ' \ �., �` 300 ..; . A� ����, 1500 _ 1750 , r.� • 60 � .. 300 - ,� ! ,, ;, - 60 1750 2000 I : / -i � 2000 2250 i 1 � ODSDW2 -20 D isposJ �� \ ODSK36i KupD 2250 2500 , ! j. r \ , . 2750 / i ° ��oi2 , 2500 ODSDWI -44 Dispos 'I 1 i j�(• ';;1 ' 1c 4 ` 27 50 - 3000 , ,! / i Minor Risk 1/10 ?t 1 11'1 1 4 f ° • d 270 90 11 3000 3250 ,'S /�I j' _f t - (� / � -f �� 11 :;',, i �' ! 3250 3soo '' ������ :ill 1 ( 0 j - -"% , „..' , /,' JDSN -37 PN ,, ■ . r r t 350 3750 / , � '� 270 ODSK -411 Kup r �1 � f - ma - ; , ,,, 3750 4000 � t �� .�p iiiihi %!! i ' _ : N1 4000 - 5000 - /�., I 24 6000 7000 � . ■ ' � ' ' 7000 - 8000 ; ,iT1 oe 20 �.�. 1 ���'' 39i IN11 8000 9000 t \� _ , R: / y 9000 10000 : �, l - 1 t .... ,...., 51 10000 11000 210 �5 / / --- _ - 150 ``� ODSN ODSN 43 PN14 240 -06 KupA ■ �- -'�•� ODSN -43 PN14 Range 0 -10 120 71000 72000 � 30 ODSK 00' Minor Risk 1/10 ODSK -46 KupA 160 1' Mi nor Risk 1/201 ODSN -38 PN 1 5000 6000 13000 14000 '-��� ` Range 0 -1100' 75 15000 16000 15000 16000 'ravelling Cylinder Azimuth (TFO +AZI) (bearing( vs Centre to Centre Separation 120 ft /inI 210 - � � 150 16000 17000 17000 18000 it ' 18000 19000 180 19000 20000 SECTION DETAILS 20000 ' 21000 Sac MD Inc A71 TVD 0849 .E/-W DLeg TFace V9ec Target 1 440 0.00 000 440 0.0 00 000 000 00 21000 22000 2 5000 0.00 0.00 5000 00 00 000 000 00 3 1000.0 500 170.00 9994 -215 38 100 17000 -36 4 16614 14.92 1]0.0 1650.0 -1340 23.6 1.50 000 -227 Travelling Cylinder Azimuth (TFO +AZI) (bearing( vs Centre to Centre Separation [50 ft /inl 2 2000 23000 5 1761.9 14.92 1]000 17500 -1603 263 000 000 -2] 2 6 35260 7237 212.00 2989.5 - 1197.2 -4213 350 46.44 4294 7 35143 72 37 21200 2995.0 -1211 9 .4305 000 000 4387 8 39128 72.37 217.80 31063 - 14998 -5313 1.50 90.88 541.5 9 71924 72 37 217.87 41000 -39698 -254] 1 0.00 000 2573.9 10 7197.0 7238 217.97 4101.4 - 3973.0 - 2549.7 350 8537 25786 11 96894 72 38 217 97 48557 - 5845.8 -4011.1 000 000 4050.6 REFERENCE INFORMATION Well Planning Pioneer O uruk 12 11902.0 7239 300.00 56500 -62065 - 5884.0 350 104.74 5905.9 IN13010016 g ' one - oo g 13 12552.6 73.11 32043 5844 8 - 5807.6 -6335.4 3.00 9098 6374.6 14 136554 73.11 32043 6185.1 -49941 - 7007.6 000 0.00 7041.2 15 142185 90.00 32000 6247.5 -45677 - 7382.7 300 -149 7393.5 1513 0912A Co- ordinate (N /E) Reference: Well ODSN -45i - Slot ODS -45, True North Calculation Method: Minimum Curvature 16 143878 9465 317.97 6240.6 -44401 -7473.7 300 -2356 75038 Vertical (TVD) Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) 17 153320 94.65 31797 6164.0 3741.1 -81039 000 000 8129.0 Error System: ISCWSA 18 154920 9000 316.80 6157.5 38235 -82121 300 - 16588 82364 1513 v973 Section (VS) Reference: Slot - ODS- 45(0.0N, 0.0E) 19 156799 8436 31661 6186.7 3486.7 -83405 3.00 17985 8363.9 Measured De th Reference: 44' + 13.5' @ 57.5ft Nabors 19AC can Method: Tray. Cylinder North 20 163062 8436 31681 6228.3 -30323 -87670 000 000 8787.4 P @ ( ) 21 16494.2 90.00 316.67 8237.5 - 28958 -88957 300 - 148 8915.1' 1513 09 T6 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 22 16656.7 9466 31671 6230.6 -2]7] 5 - 9007.0 300 048 90256 Warning Method: Rules Based 23 17552 94.68 31671 61545 - 2127.8 -96191 0.00 0.00 9633.3 24 17716.2 9090 316.14 6167.5 - 2009.5 - 9731.8 3.00 - 17335 9745.1 1513 v9 05 25 17979.4 8210 31632 61656 - 1820.0 -99133 3.00 17888 99254 26 188236 8210 316.32 62511 - 1358.4 - 10354.0 000 0.00 103629 27 18891.1 90.00 31489 627225 - 1167.9 - 10510.5 300 -10.32 105481 1513 09 78 NAD 27 ASP Zone 4 : WELL DETAILS: ODSNdSi 28 20 90.37 314.89 62625 -11592 - 116838 300 000 1116334.11 1513 v917 Ground Level: 13.5 +NI-S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031005.53 469821.86 70° 29' 44.804 N 150° 14' 48.350 W ODS-45 1 • SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2008- 06-05T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 1100.0 To 3545.0 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 2090.0 44.0 1100.0 ODSN -45i 1N13 wp10 CB GYRO - SS Reference: Plan: ODSN -45i IN13 wp10 (ODSN -45i /ODSN -45i PN13) 1100.0 20434.4 ODSN -05i 1N13 wp10 MWD+SAG+CA +TIER +MS Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria ODSDW1 -44 Disposal FOR USE FROM 1 ODSDW2 -20 Disposal ODSK .411 KupP u ODSDWI -44 Disposal • Range 1100' -1250 ODSN -37 PN8 N�p��ao� 30 , Range 1100' -1500' 330 , ,•,,,), ♦ we - ` _\� �. 30 From Color To MD 330 _ 30 • Minor Risk 11200 ♦ . s �� 44 250 > - --r . 4 I 250 500 ,:: ,� � / ••� ♦. _ _ 500 ]50 2t I . - C ` C. /"v ♦ ♦ ► / 7750 1000 , %; . � , ;� \ � /� / ' 1000 1250 300 41/ 60 300 ••• • •• ' (� � 1 � ■ i � • � � 60 ODSN37 P 1500 1750 /*SA, N q , r � / �✓ - J 1]50 - 2000 \ . � I ', • 444 / • 2000 - 2250 hl i / 250 ` \ . �/ i 3 t l a I, �r . � zwo 172500 750 � • • / 'I 1 1 ' x 444 2]50 3000 .! 4 i / , te• \\ . - I l 7 t, � �J 3000 3250 90 v / / _ % I. 3250 3500 2 / ' 1 / � _ \ 1 , o ,•114 ( 3500 - 3050 , Ii / , g � �� ' / I / � �- l% /, � �. ,', ,)� ODSN -393 IN1 37750 a000 ��� 270 ;� \ ( I � .. r 4000 . ._._ , 5000 i j - 1 :1(ff /� 0 . ! •! I moo 5000 t it i�s . . '•er / 0 / I ODSN39i IN1 , 6. 4t6 '- / I 60 00 7000 , ,,, /. - ] 00 0 8000 `, ,, , , 8000 9000 � � �(� 9009 - ,0099 240 , ,1111 , 120 • r If', � � A L i ' 10090 _. _ 11000 \ ......... ' i i I . 11000 12000 1 • � sp 12000 300 ' /�� �' • - / i ODSN 40 PN1' � •eV 13000 14099 _. -1- ` \ ••••”11 14000 -- 15000 5009 16000 \ - --. 21 g - 0 ��� i' 150 Z40 _ ` � ., 120 16000 17000 30 ` \ 1]000 18000 ` 18000 19900 ODSK 46 c °. �: 180 ` 19990 21000 Range 1100' - 1250' 20000 21000 Minor Risk 1!200 7 21090 22000 ` - �...... 22000 23000 Travelling Cylinder Azimuth (TFO+AZ[) (bearing( vs Centre to Centre Separation 120 ft/in] 210 Nillw -`, `I 150 I07,FM - 43 PN1 1 SECTION DETAILS 180 Sec MD Inc Ae TVD 4NI -9 4EI DLeg TFace VS. Target 44.0 0.00 0.00 440 0.0 0 0.00 000 00 1 0.0 5000 0.00 000 5000 00 00 900 000 0.0 3 10000 5.00 170.00 9994 -21.5 38 1.00 170 00 -3.6 4 1861.4 1492 170.00 18500 -134.0 23.6 150 000 -22.7 5 1064.9 1492 17000 1050 0 -1602 283 000 000 -272 Travelling Cylinder Azimuth (TFO +AZI) bearing' vs Centre to Centre Separation 150 ft /inl 6 3526.0 72 37 212.00 29895 -119] 2 -4213 350 4844 429.4 3514.3 7237 212.00 2995.0 -12119 -430.5 000 0.00 438.7 8 39128 72 37 217.80 3108.7 - 1499 8 -631.3 1.50 9088 6415 9 7192.4 7237 217.80 4100.0 -39898 - 2547.1 0.00 000 25739 10 ]19].0 7238 217.97 41016 -39]30 -2549] 3.50 8537 25768 11 9689.4 72 38 21].9] 48587 -58158 -40111 0.00 000 4050 8 REFERENCE INFORMATION 12 119020 7239 30000 56500 62065 -58840 350 104.74 59059 IN13 v10T1B Well Planning - Pioneer - Oooguruk 13 12552.6 7311 32043 58448 - 5807.6 6335.4 3.00 9096 63746 14 13655.4 7311 320 43 61651 -49941 - 7007.6 000 000 70412 Co- ordinate ( N/E ) Reference: Ref Well ODSN -45i • Slot ODS -45, True North 15 14218.5 90.00 32000 6247.5 -4567.7 -73827 3.00 -1.49 73935 6913 v9 T24 Vertical (TVD) Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Calculation Method: Minimum Curvature 18 14387.8 94 317.97 82408 -4440.1 - 7473.7 300 -2358 7503.6 17 153320 94.66 5 317.97 61640 - 3741.1 61039 000 990 8129.0 Section (VS) Ref Slot - ODS-45 0.ON, 0.0E Error System: ISCWSA 18 154920 9000 31650 61575 - 31323.5 - 8212.1 300 -16588 8236.4 114134903 ( ) erence: ( ) 19 156799 8436 31681 8168.7 3186.7 6340.5 300 17985 83639 Measured Depth Reference: 44' + 13.5 @ 57.5ft (Nabors 19AC) Scan Method: Tray. Cylinder North 20 16306.2 8436 316.81 6228.3 30323 6767.0 0.00 0.00 6787.4 21 16494.2 90.00 316.67 6237.5 -2895.6 6895.7 3.00 -148 89151 IN13 09 T4 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 22 166567 9488 316.71 82306 -27775 - 9007.0 300 048 90286 Warning Method: Rules Based 23 175528 9488 318.71 8154.5 -212] 8 - 9619.1 000 0.00 9633.3 9 24 177162 90.90 318.14 8147.5 - 2099.5 - 9731.8 300 -17335 9745.1 1813 0905 25 17979.4 8210 31832 61656 -16200 - 9913.3 3.00 178.66 9925.4 26 188235 8210 31832 8254.1 - 13584 - 10354.0 0.00 000 10362.9 27 18891.1 9000 31089 62725 - 116]9- 19540.5 300 -10 10548.1 1813.9 06 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN-45i 26. z0434a 9 314.89 62625 11 88 - 1 000 000 1163 641349 T7 314.89 6272 5 Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031005.53 469821.86 70° 29' 44.804 N 150° 14' 48.350 W ODS -45 SURVEY PROGRAM ANTI - COLLISION SETTINGS Date: 2008 -06- 05700:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 3545.0 To 20434.4 Depth From Depth To Survey/Plan Tool Results Limited By: Centre Distance: 2239.0 44.0 1100.0 ODSN -45i IN13 wp10 CB- GYRO SS Reference: Plan: ODSN -45i IN13 wp10 (ODSN -45i /ODSN -451 PN13) • 1100.0 20434.4 ODSN-45i 1N13 wp10 MWD+SAG+CA +IIFR +MS Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference FOR USE FROM ODSN -17 PS16 3545'TD Range 12000 -13000 o From Color To 1000 MD 4 0 44 250 250 500 33 Soo 750 750 -. ' .. • ___ ,• ,` ... I ` 1000 1250 #VV\ 300 .4 ', • y/ ` `� 1500 1750 300 , � , 60 �� 1500 - 2750 , � '�� ` 2 000 225 i ,` • i lir& ` ` ` 2250 2500 _ ' O 1441/k1 4 ` 2500 2750 2750 "' 3000 I / ' li 30 00 3250 270 � i h tiA 3250 3500 ''• _ ; 3500 - ' 3750 � t 3750 4000 till 4000 -- 5000 `5000 ` 6000 6000 ' 7000 24 70 00 . 8000 20 270 , , 6666 - 9666 i 9 I. 000 100 240 ‘ 1 00, 120 10000 11000 2 , ' ' 11000 _-- 12000 30 � ' 12000 13000 180 ` ` la' 13000 14000 ' 14000 15000 Travelling Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation 120 ft /in] 15000 16000 210 ` �' 150 16000 --- __ - " - "- 17000 100 ' 17000 18000 18000 19000 SECTION DETAILS 180 19000 20000 Sec MO Inc Aa TVD +8I -S •EI -W 131_e9 TFace VSec Target 1 440 000 0.00 440 00 00 000 000 00 20000 21000 2 5000 0.00 000 5000 00 0.0 000 000 00 3 10000 500 170.00 999.4 -21.5 3.3 1.00 170 00 3.8 21000 22000 4 16614 1492 17080 1650.0 -134.0 238 1.50 000 -227 5 1764.9 1492 170.00 1750.0 -1602 28.3 0.00 000 -27.2 22000 23000 8 3526.0 7237 21200 2989.5 -11972 -421.3 3.50 4644 4254 p c c 7 3544.3 72 37 21200 2995.0 - 1211.8 -430.5 000 000 438.7 T ravellin (TFO+AZI) Azimuth lind Azith FO +AZI [beating] vs Centre to Centre Separation ft /in 8 3912.8 7237 217.80 3108.7 - 1499.8 -631.3 1.50 9088 641.5 Y l l [ b� p araton 5 I ) 9 71924 7237 21780 41000 3969 6 - 25471 000 000 2573 9 • 10 7197.0 7238 217.97 4101.4 -39730 -25497 350 8537 25766 11 9689.4 7238 217.97 4855.7 -58458 -4011.1 000 000 40506 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk 12 125 3.11 3 56448 - -633 00 1 9 9 96 6 63746 1513 410 T1B 14 13655.4 7211 320 43 61651 -4994.1 -7007 6 0.00 000 70412 15 142185 9000 32080 6247.5 -4587.7 -73827 300 - 1.49 73935 151365024 Co-ordinate (N /E) Reference: Well ODSN-45i - Slot ODS -45, True North 18 14387.8 9465 317.97 62406 -44401 - 7473.7 300 -2356 75036 Vertical (TVD) Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Calculation Method: Minimum Curvature 17 153320 9465 317.97 61640 -37411 -81039 000 000 8129.0 Error S ISCWSA 18 154920 9080 316.80 8157.5 - 3623.5 -82121 3.00 - 18588 82364 16134903 Section (VS) Reference: Slot • ODS- 45(0.0N, 0.OE) 19 156799 6436 31881 61667 3486.7 -83405 300 179.85 83638 Measured Depth Reference: 44' + 13.5' @ 57.5ft (Nabors 19AC) Scan Method: Tray. Cylinder North 20 16304,2 3436 316.81 62383 -30323 5767.0 0.00 -000 8787.4 9413 49 04 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 22 16656.7 94.88 31671 6230.6 - 2777.5 -90070 300 048 90258 Warning Method: Rules Based 23 175526 94.88 31671 6154.5 -2127.8 -96191 000 0.00 9633.3 g 24 177162 9000 31514 6147.5 -2009 5 -97318 200 -17335 97451 1113 v9 T5 25 179794 82.10 316.32 61658 - 18200 -99133 300 17566 9925.4 26 18623 6 8210 316 32 6254.1 - 1358.4 - 10354 0 0.00 000 10382 9 27 18891.1 9000 31489 62725 - 1167.9 - 10540.5 300 -1032 105481 15134976 28 18903 5 90.37 314.89 62725 - 1759.2 - 105493 3 00 000 10556.9 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN -45i 29 204344 9037 31489 626225 -788 - 116338 000 0.00 116341 11413 49 17 Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031005.53 469821.86 70° 29' 44.804 N 150° 14' 48.350 W ODS-45 • • • • ' 1. 11d1GY IYPE C 3 1/6' -5000 PSI GTE WLVE 2. MOM rat C 2 9/16' -5000 PSI CATE'VALYE CHOKE MANIFOLD SC EMATIC 0 2 1/16 -10000 PSI RENOIE OIOkE 4 . OIO RNYLL- CSYWER 3 1/6".-5000 PSI MANUAL CHOKE • • NABORS ALASKA RIG 19AC S. "LANCED 1EE 21/16' X 21/16' X 2 I /I6' -5000 PSI • . , ' a 5 WAY FLOW (LOCK 3 1 /6 X 3 I/6' X 2 1 /16 X 2 1/t6' x 2 1 /16 -5000 PS1 • ■ 7. $ WAY FLOW 6L0CK•3 1 /6' X 3 1/6• x 3 1/6' X 3 1/6' X 2 1/16 =5000 PSI • 3' I. ♦ WAY FL BLOCK 2 1/16' X 2 1/16' X 2 1/16' X 2 1/16' -5000 PSI T Q ' 9. 2 1/16 . -5000 PSI SENSOR BLOCK . 10. 2 1/16'- IO.000PSI Z 2 1/16 -5000 PSI SPOOL $� UD II. 3 3 1 x 2 1/16 -6006 P9 SP00L 1pp • .I2. 2 1 /16• X 2 I /96' -5000 PSI SPOOL 13. 3 1 /6' -0000 PSI x 2 1/16' -0000 P9 SPOOL 1 14. 2 1/16'- 10.000 PS X 2 1/16 . -5000 PS DOUBLE MID AWACS Q TP 15. 2 1/16 -5000 PS TARGET RANCE / 16. 3 1/6' -5000 P51 TARGET FLANGE 3' © 17. 3 1 /B' -5000 PSI X 2 1/16' -5000 PSI 001181E SIIA ADAM la 3 1 /6' X 3 1/6 5000 P9 SPOOL P - wil 1, I 19. 3 WAY FLOW BLOCK 3 1 /6 x 3 1 /6' x 3 1 /6 -5000 P51 Ne 1.9R I 20. S WAY f.OW BLOCK 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16' -5000 PSI 1 3� T ' t 1s \ . 0 r • `�- �� 6 .ii 1( ,,,!.ID • . . • . T , . © O �� i , . God • ® 3 • .(z: .•. 1 3 • © . d • 'E{• -' -,1 ,,54:> Vti: 1.N ir ._ 1, • I . • w WobwrsAAa;o m c'w"�' ."�". : • I .w...... Ai Nn ...rx .'a' -a1 • Ma Ma " sDAS MaSKA C 19nC CnoAE rw1WOLD scauftne WtNar is awe wo wan _ a a� • m -2' '�. ��• NTS .24 MAN �~ INCA • • . i • • • • • • • • • • t HYDRIL 11" 5k PSI • ., GK ANNULAR OP I 3' -1 SCREWED H D . • FUWGED BOITQM C NNECTION • I ( 47 3/4 LENGTH . i J - +--- -- 1 t " 5000/ • 4 -7 • - I FLANGED HYDRIL t3'- 1 DOUBLE CATE PREVENTOR 3 1/ 5000/ HC VALVE - - - - -- ; - 55" LENGTH • \ a • �S a; • 3 1/8 5000/ HCR VALVE . • 1 , - 3"_CHOKE L E� -- �1i►� 41 411t ,-- 4 iii 4 1, -,i11- _ ----- KILL LINE- • l x 3 1J8" 5000/ ATE VALVE r 1 r 3" 5000 / GATE VALVE HYDRIL i l 5k . 3' -5i' - -- - - - - -- - - - -- — -- HYORAUUC RAM SINGLE PSI GATE 4 I I 3 % CONNECTION CITI}tON rii • • NABORS ALASKA RIG 19AC . ' BOP STACK CONFIGURATION • II Or�..war• =1Z • `` 7 ax e. riAaxS NAM PC lire i! 10t prnr-0ur ne»mot SieG% wsxan uu, [ + i w roue -I' No - - . • • • • 2 . I I. lilt, i I iill 1.1 tui 1 i !All hii 2 1 - - e I la J1 i :: — I 4" 4 k ii s I 11 Ji 1 c i ' 1 i m ! . i , i t ' h c: i 0 ......• ...i. i V : . • k . Is 1, . 1 1 I . + I . I 1 ' 0 , . ■ , i 1 000 ir;:i 1 12T c!.1 i . de -,,„---4-----4 e.W4 44 i 0 I II a MI a -,-----' L —1=111.---yilmi — , le 1 t ii 11 4, 1 ' 11111111 1 ant; 1111 6.1111 j 1 MIN 1.1 ll M I I I II N - - - -i12- - I=MINNIIMI ___1:11., r illEdwil - 0 - 1 1 1 t . 1 • • Legend ti .r • • ..%.._ e ti A. —tw Conductor M • • 0 O b • • _ • r �owllan ' • • e • •. . .. A rye 4 " 'I.. k .l.N ti . 1• b • • .0 i • S ,, • , � ' 4 Location ' Map • GRAPHIC SCM 'kg • •• • . (n) . .,k • • .y"r • / � P :• 1 °j •• e � i is my • • 4% �...� ••••• ��r • • •' : • ^ / lip G. Daft a ° . 0 9• ; S J} ti, No. 41105 • : „ >'''' 0 . 1 • • 43 i .. � F, • ' • r• S i 4,1 P • • . `� � "OfESSiON� ,p,* + 1Q ` t 1 \�1.•∎•••" ► ry ° ° o v . + :o'r'b • • • i . • s P IN . . : Plan..r Natural R..ouo.. if' JOB. NAME: Oodguruk Drill SltO DRAWN BY: it I CHECKED BY: MJD • • LOCATION: Prolroot• i SsoUon ,11 SCALE: 1'•30' • Township 13 North . • Reny. 7 East', I i DATE: 7 -12 -07 • • umiot Manakin I! • Not ' Notes: u NANUQ JOB NO. SHEET • ; Coordinobs are 0.1ed on sheets 3 and 41 DESCRIPTION: Alaska Had 27, Zorn 4 Conductor A. —buqlt Plan i 05204 10l 4 • . • • 0 • + I .. it l --� ... 1a , to a r I _ 1 . . 1 ' I -Vier id Eosin• I ' S orner o \ c'J 000Rux E TE Protracted Section 11 s ,11 , .' 11 Coordinates I 3 i : i �,� N 6028111.04 I. E4/ ••• t 8 , 1 • IJ . s . II P1 - \ Ref. AK , BLM 7 . es , ¢ a • " �` �\ Harrison; Boy .TrocI.. * A * { _ I s • -24\ . .p r. PrCWi ft I. \ �A a ' - a I /Ail )i f Plr CM ItYrncc �P ABC6 \ �. • Near Shen laroat+v3.81= • ' PI-13 s _0"/ el 20 to Dooc_•r.ik Ms 1 � PI 7 to P t ;t ` i v 1 . • / — r „F-1., . tun ro Waco • a • e F s ^ • DS 3 i SAP. OF a % t PI- Roods to i Bic ' / . IN -/ ,= - _ Bas of Location ' � ' � DS -3H West Monument - � , Coordinates iiir ' 1 : , 3 • , N 6001016.61 ' •STAKED P1 INFORNCAll ON ONLY '��� ; E 498081.23 Y p •i — _ .. .. . . _ . _. Ref. ; Lownsbury do Assoc. CC � ∎ r < Drawing No. ■ ; �� • � CC NS . —d672 ..... o ... ... • f - A t 4 1,� _. .. -� ,; r te ' ,`; .01;; I ie rr "10 0 '.." ;OO .: • • ... a• --tea` Fes: ^}*' ; `- � = ; 7r G. - VS. No.41104 /I' a': �h•,+ ' ru:v 4 %, ortssionAx- or Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL , CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North • Range 7 East ' DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 . 2 of 4 • 1 0 .....--...-.......... ___,_ - - - - - $te Alaska ts PlanQ A a • Seefion Line Of ---- V _--P-ad---Ie . --. --- - - _e.t :.k. --engitv.d: . Isl. mt. -- _... _._., .„.....„-_----- ---,.._. f -- ',col,wi,4 469.920, 7Q294626 15Q1446466 3O3 5 - lor SEM - 70 2946,19262 160 3050 1062 1 • $ -- 6,03 - 1714 ; 1 - ,$.9 -- 469;00:69 ---- 702546 ISQ 14 45,7 --- 6025 1067 1150 6,031,166,46 469,906,07 • 70 29 46.09465 160 i44589799 502 1092 - I - UO -- 6 -- 6:031,151,4 - 5 469,900,74 ' 70 29 46,04636 150 14 46,04262 3015 1097 1460 . 5 6,051,126,61 469,695,60 70 29 46,99660 150 14 46,16755 6010 - 1102 13 . --- 6031;11173 469,553,13 70 3 160 14 46,55079 207 1115 1$,50 6 - 6, -- 0 - 31 - J0673 469 7a 4S2fo2 150 14 46,M7. 1 2 - 992 1120 . 13,60 9 6,01,10175 469:673,26 70 29 4.71iO4 - 1 - 60 - 1 - 4 46 2.f37 M11111$, 0 ---- --- - 6031,0913,79 - 40,$08,$ 70 294572286 150 14 46,99170 2902 --- - - 1130 1 ISM 6,051,093,64 - 469,063,39 . 70 29 45,67698 150 1447.13760 - 2977 1135 --- 15,50 IIIIIIMMINCOMIturNal 7 - I - • 9 45 62490 - 1 60 297 1140 13,60 Mar 6,03f,076,06 460:$45:6T 10VO - 1$014 4152:6 ---- 26) Th li 52 1111011111 . 469,134,0 70 29444932 160 14 47,79770 2065 1157 13,50 15 ---- 6;031,066,15 469,835,96 70 29 150 14 47,94165 2050 11 --- 13 . 16 6,031,061,16 469,831,04 70 29 il.$f4S *1.0. I446,0006 1167 13,50 17 6,031,056,25 469,626,11 7029 46,30277 16014 4623042 2940 1172 13 • ---T 6,0l1 ,061,27 -- - 469 - , - 621 if 7O "2 15014 - 40740 - 6 --- 2955 1177 - 1 - 19 6,01,06,a 4960650 70 20 4,12/ati I 40,74666 2922 1109 if$Q 20 - - 6,03 - 1 - ,03 - 660 469,003,60 70 29 46,07611 160 14 4:W6T 2917 1194 13,60 21 6,031,020,63 A 69,70;62 70 ".9 - 100 144 2912 1199 22 6,01,026,58 . 409,70,67 70 29 44,90414 150 14 4918144 2907 1204 1$;50 2$ " 469,766.16 44:94067 1 f if:4.44661 2902 , 1209 I150 • 24 - 6,wi3O1.60 A69,7a:64 70 20 4A 160 Tif40 2097. IMILIS 1160 • .•.:" OF A( 9 .. .........4 .. if . . • ,r41/41:', • , . 1 1 - - -------v4-- -11 4 - - . . .... ,.. . . . . . . 07 i f f 9 7 ." 6.. 77-' • 1 - - 1 . ' Philip CT; e 1 No. 41104 .. de • - - :::;;. ; 1."1- 44 a iv. , : _t_ l e ia -"fa' 1 , .........040,„.... :IX :'i il I .9 ortsmw p,t, t'' ~ It ‘% , 2.•■•■"' - ' 1. : 1 w::t k.IT:!, • 41.c $. •tig -*.%:,•; ....".7-10 Nei= N:: -:-•!..- .-t-,. ,..0_, • - .-"4:4::::: t; : : S I I rItvcilyn; ore bsl§ed on E3P mcgn SCO LC*, - - - 2. Coordinotce ore bored on Alceko Stote Florio Nod 27, Zone 4/ 1 All condv m cto or within Protrocted Section 11, Pinar Neturol Reg9uces JO NAME; 0c4ogyruk Drill site ccpn ow ctQr* DRAWN 5Y: IX CHECKED SY: MJD LOCATION, Protrocted section ii SCALE: N/A Townehip 1 North . Ronge 7 Colt DATE: 7-12-07 Urniot Merldion ,-.,-- NAN VV 'NC, SHEET DESCRIPTION: A--built CoordinoWs 05204 3 of 4 Wt1t • AAiaska Slate Plane - • 4) . ' • i_ 'Section Line Offset jej. 25 6,031,128.32 469,943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 . 6,031,123.35 469,938.69 70 29 45:96722 150 14 44 .92442 3008 1060• 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 ~' 300 • ; 1065 .13.50 28 6,031,113..39 469,928.66• 70 29 45.86587 ~ 150 14 45.21260 2997 1070 13.50 29.' 6,031,108.44 469,923.95 70 29 45.81999 150 14 45,35655 • 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50, 31 6,031,090.65 469,906.38 70 29 45.64431: 150 14 45.87163 - 2975 ' 1092.' ' 13.50 32 6,031,085.68 469,901.39 70 29 45.59523 ' 150 14 46.01793 2970 1097 _ 13.50 3 3. 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 . 6,031,075.73 469,891.57 70 29 45.49698 150 "14 46.30581 2960 w • 1106 13.50 . . 35 6,031,070.76 469,886.60" 70 29 45.44789 150 14 46.45152. 2955 . 1111 • 13.50 36 6,031,065.83• 469,881.69 70 29 45.39921 ' 150 14 46.59547 2950 1116 13.50 ' . ,'3170 ,,. i i GS,5C9.00 70 29 45.27251 150-1-4-46,982A • 1 • 1 3 8 6,031;047.99 469,864.14 ' 70 29 45.22304 150 14 47.10995 2932 1134• 13.50 3 9 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 . 1139 13.50 4 0 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 .•1144 . 13.50 41 6,031,033.05 469,549.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 r 70 29 45.02692 150 14 47.68925 2912 1154 ._ 13.50 • 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13,50 44 6,031,010.49 469,826.79 70 29 44.85272 _ 150 14 48.20493 2894. 1171 • 13.50 ., 4 5 . 6,031,005.53 469,821.86 / .70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000:54 469,816.94 70 29 44.75446 150 14 48.49369 . 2884 • 1181 13.50 47 6,030,995.50. _ 469,811.98 70 2944.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.76304 2874 • 1191 • ' 13.50 .. -..__ ..... ...._........ .... . ... ... --`t �`,�F,ql%�\ SURVEYOR'S CERJLFIS,ATF• • . -O ' i k • � - + • •• • % t 1 1 _ r- PROPERLY I HEREBY CERTIFY THAT I AM �` �_� 0' j oar j . 1! i R - A M - • ' 4 - 1 H ; '* L ICENSED TO PRACTICE LAND - _ ' e " ' SURVEYING IN THE STATE OF , • . • /. • • . . . i 0 ALASKA AND THAT TiifS PLAT N ? { � ;; • ;lip G: Dav , o ` / REPRESENTS A SURVEY DONE BY '� .�. "+ °sJ n J} 1 Ne . 41104 4' ME OR UNDER MY SUPERVISION t=' ^ �' '. �-%�''f" I t .• .P .� AND THAT I BELIEVE THAT ALL -i Tt st ~ • 401 .I At N '� 'o DIMENSIONS AND OTHER DETAILS _ v ^ ms ' s . ' .,' '► a .,T r • i � ARE CO RRECT AS SUEIdITTED TO " a ME BY NANUO. INC. AS OF JULY ` " 12TH, 2007. Pioneer Noturol Resouces JOB NAME :' Oooguruk Drill Site Conductors DRAWN BY: BL I CHECKED BY: MJD. LOCATION: Protrocted Section 11 / SCALE: N /A' Township 13 North Ronne 7 East DATE: 7- 12 -07. • Umiot Meridian NANUO JOB N0. SHEET DESCRIPTION: As -built Coordinates 05204 4 of 4 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER r CHECKLIST WELL NAME � / V T PTD# 2.47E — /Db, Development, ✓ Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: pC>6 !.0 v l.0 k POOL: k.. GCL 5 �C Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new welibore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after jCompanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool 000GURUK, NUIQSUT UNDEF OIL - 576150 Well Name: •O• RUK • • N -45 Program SER Well bore seg ❑ PTD#:2081000 Company PIONEER NATURAL RESOURCES ALASKA INC. Initial Class/Type SER / PEND GeoArea 973 Unit 11550 On /Off Shore Off Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface and top prod interval in ADL 355036, TO in_ADL_355037. 3 Unique well name and number Yes 4 Well located in a defined pool Yes Qooguruk- Nuiqsut Oil Pool, governed by CO 597. 5 Weil located proper distance from drilling unit boundary Yes Rule 3 of QC 597 specifies no restrictions as to well spacing except that no pay 6 Well _located proper distance from other wells Yes shall be opened in a well within 500' of an external property line where the owners 7 Sufficient acreage available in_drilling unit Yes and landowners are not the same on both sides of the line. The wellbore will 8 _If deviated, is_wellbore plat included Yes conform to this rule. 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes 11 Permit can be issued without co_nseryation order Yes Appr Date 12 Permit can be issued without adrninistrativeapproval Yes SFD 6/17/2008 13 Can permit be approved before 15 day wait Yes 14 Welllocated within area and_strata authorized by Injection Order # (put 10# in comments) (For Yes AIO 34 • 15 Ail wells within 1 /4_mile area of review identified (For service well only) Yes None (ODSN-40 1s 1550' to NE and parallel to the proposed 00SN -45 wellbore) 16 Pre- produced injector: duration_of pre production less than 3 months (Forservice well only) No Pioneer may pre - produce beyond normal clean-up. If so, they will notify the Commission. 17 Nonconven, gas _conforms to AS31,05.030(j_.1.A),(j2.A -D) NA Engineering 18 Conductor string_provided Yes 19 Surface_casingprotects all kno wn USDWs NA Surface location is offshore. No known USDWs. 20 CMT v_ol adequate to circulate_on conductor & surf csg Yes 21 CMT_ v_ol adequate to tie -in long string to surf csg No 22 CMT will cover_ali known_productive horizons _ No Open _hole completion planned, 23 Casing designs adequate for C,_T, B & permafrost Yes 24 Adequate tankage_ or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well. 25 lf_a re- drill, has_ a 10403 403 for abandonment been approved NA 26 Adequate wellbore separation_proposed Yes Proximity analyis performed. Traveling cylinder path calculated. 27 if diverter required, does it meet regulations NA PXD filed surface hole _inforrnaiton& seeks a diverter waiver. No issues identified drilling prior wells. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 9.8 EMW. Planned MW up to10.4 ppg. TEM 6/19/2008 29 BOPEs,_do they meet regulation Yes 49—T141 , 30 BOPE_press rating appropriate; test to_(put psig incornrnents) Yes MASP calculated at 2487 psi_ 4500 psi BOP testplanned. 31 Choke manifold complies w /API_ RP -53 (May $ 4) Yes 32 Work will occur without operation shutdown Yes 33 is presence of H2S gas probable No H2S has not been reported in offset wells. Rig equipped with sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only) Yes No wells in AQR. Geology 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated but sensors & alarms will be utilized. Scavenger chemicals will be onsite. 36 Data_presented on potential overpressure zones Yes Reservoir pressure expected to be about 9.8ppg EMW; will be drilled with up to 10.4 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA Mud weights up_to 12.0 ppg may used to stabilize_ problem_ shale zones. SFD 6/17/2008 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P •lic Joe Polya, Pioneer: to avoid faults, they have moved the Kuparuk intercept about 500' from that originally planned, but the Commissioner: Date: Commissioner: Date p.sioner Date ��`. move has been intentionally AWAY from the seismic amplitude anomalies. 10111°r ‘'./ie3 '-'eg 1
