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209-120
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-703-20605-00-00Well Name/No. OOOGURUK KUP ODSK-42Completion StatusP&ACompletion Date12/10/2009Permit to Drill2091200Operator Pioneer Natural Resources Alaska IncMD10625TVD6705Current StatusP&A9/8/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalList of Logs Obtained:LWD, MWD, GR, DIR, EWR, PWD, ALD, CTN, CCLNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScale12/14/2009177 10625 Open MD DGR, EWR, ALD, CTN, BATLogColInduction/Resistivity2512/14/2009177 10625 Open TVD DGR, EWR, ALD, CTN, BATLogColInduction/Resistivity2512/14/2009177 10625 Open MD DGR, EWR, ALD, CTNLogColInduction/Resistivity212/14/2009177 10625 Open TVD DGR, EWR, ALD, CTNLogColInduction/Resistivity212/14/2009177 10625 Open MD DGR, EWR, ALD, CTNLogColInduction/Resistivity512/14/2009177 10625 Open TVD DGR, EWR, ALD, CTNLogColInduction/Resistivity53/25/20100 0 End of Well Rep, Op Overview, Morn Reps, Drilling Rep, Survey Rep, Days vs DepthRptReport: Final Well Re3/25/2010153 9758 Case MD Engineering logLogColMud Log23/25/2010153 9758 Case MD Engineering logLogColMud Log23/25/2010153 9758 Case MD Gas RatioLogColMud Log23/25/2010153 9758 Case MD Combo LogLogColMud Log23/25/2010153 9758 Case MD Combo LogLogColMud Log5C12/14/2009150 10625 Open EWR logs in DLIS, LAS, PDS, EMF and CGM19125EDLasInduction/ResistivityC12/14/2009150 10062 Open BAT Waveforms MWD19126EDLasInduction/ResistivityC3/25/20100 0 End of Well Rep, Op Overview, Morn Reps, Drilling Rep, Survey Rep, Days vs Depth19490EDReport: Final Well Re12/8/20099600 106251401CuttingsTuesday, September 8, 2020AOGCCPage 1 of 2Supplied by OPSupplied by OP DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-703-20605-00-00Well Name/No. OOOGURUK KUP ODSK-42Completion StatusP&ACompletion Date12/10/2009Permit to Drill2091200Operator Pioneer Natural Resources Alaska IncMD10625TVD6705Current StatusP&A9/8/2020UICNoINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:12/10/2009Release Date:10/14/2009Tuesday, September 8, 2020AOGCCPage 2 of 2M. Guhl9/8/2020 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal PEAR 2 5 2090 nt old, arol Date: March 24, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Mahnken 700 G Street, Suite 600 333 W. 7"' Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 U1P7u ❑ Letter ❑ Ma s X Report X Other - logs ❑ Agreement DETAIL QTY DESCRIPTION ODSI6- 42Ai (API: 50-703-20605-0100) 1 Report 1 Report ODSK-42Ai End of Well report 8 Well Logs 8 Well Logs 2- 2" Combination Mud Log 2- 2" MD Engineering Log 2- 2" MD Gas Ratio Log 2- 5" MD Combination Mud Lo We request that all data be treated as confidential information. Thank you. Received by: Date: Please sign and return one co�tQ Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907343-2190 fax 907-343-2128 phone C�o9 -iad /4)L196 GwEO STATE OF ALASKA w ALASKA OIL AND GAS CONSFRVATION CnMMISRInN - - - - ----------- - L QMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Gas�W% LUG ❑ Other ❑ Abandoned Q Suspended❑ C 20AAC 25.105 20AAC 25.110 1b. Well Class: Development ❑ Exploratory❑ GINJ ❑ G ❑ WDSPL ❑ No. of Completions: _ One Service Q Stratigraphic Test ❑ 2. O : m 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.:; 12/10/2009 209-120 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number: Anchorage, AK 99501 11/1/2009 50-703-20605-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM 11/22/2009 ODSK-421 Top of Productive Horizon: 8. KS (ft above MSL): 56.2' 15. Field/Pool(s): N/A GL (ft above MSL): 13.5' Total Depth: Oooguruk - Kuparuk,Oil Pool 9. Plug Back Depth(MD+TVD): 2363' FSL, 2155' FEL, Sec. 13, T13N, R7E, UM 3179' MD / 2917 TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 469844.38 y- 6031028.13 Zone- ASP 4 102625 MD / 6705' TVD ADL 355036 TPI: x- N/A y- N/A Zone- 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 474103.87 y- 6025183.98 Zone- ASP4 N/A 417497 18. Directional Survey: Yes : No LJ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MDfTVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 839' MD / 830' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: LWD: MWD, GR, DIR, EWR, PWD, ALD, CTN, CCL N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16" 109# H-40 Surface 158' Surface 158' 24" Driven 10-3/4" 45.5# L-80 BTC Surface 3289' Surface 2980' 13-1/2" 458 sx PF V; 201 sx Class'G' 7-5/8" 29.7# L-80BTCSurface 9567' Surface 6014' 9-7/8" 163 sx Class'G' 3397' 4-1/2" 12.6# L-8521Y� 9398' 10,621' 5925' 6702' 6.3/4" 225 sx Class'G' 24. Open to production or injection? Yes❑ NoQ If Yes, list each 25. TUBING RECORD interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A Liner Top Pkr 9398' MD/5925TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. None DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3179' -_35 y0, 196 sx Class 'G' Cement Plug i so �- 7 s. 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 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 -.6. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ 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. None ` A IIS RBDMS JAN 21 2010al"_ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ZG 7u Submit original only •ro 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top 838' 838' and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1677' 1668' Top West Sak 2332' 2281' Top Tuffaceous Shales 3194' 2926' None Top Torok 7707' 5073' Base Torok 8263' 5351' Top HRZ 9059' 5752' Base HRZ 9304' 5876' Top Kuparuk 9595' 6029' LCU 9605' 6035' BCU 10,101' 6329' Top Nuiqsut 10,235' 6420' Base Nuigsut 10,407' 6542' Top Nechelik 10,417' 6549' Base Nechelik 10,536' 6636' Formation at total depth: 10,625' 6705' 31. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Franks, 343-2179 Printed Name: Ve �son Title: Sr. Staff Drilling Engineer Signature: .( Lo 4010 Phone: 343-2111 Date: 1/18/2010 Well Name: ODSK-42i Permit No.: 209-120 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 thedownhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water-Altemating-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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 PIONEER Operations Summary Report NATURAL RESOURCES Well Name: ODSK-42i Contractor: NABOBS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL & Start Date: 10/31/2009 End Date: Depth Man Footfflft m Wt Sten Date End Date (me) 1ft) Dem (1i Smmnary 10/31/2009 11/1/2009 0.0 9.00 LD VG rod lubricator from installing BPV on ODSN-45A. Prep rig for rig move (disconnect lines in Hutz area after blowing down same). Move ria to ODSK-42i and RU same (after squarin0 over well center & shimming level). NU VG staAing head & flowline riser system (A�iLc� Diverter System waiver on this well). Change handling tools from 4' to 5'. PU 5' DP and MU stands in mousehole - rack back same in derrick. Rig Accepted ODSK-42i ® 00:00 hrs 10/31/09. 11/112009 1102009 158.0 628.00 9.10 PU 5' DP in the mousehole and rack back same in derrick (total = 100 stands DP and 5 stands HWDP) racked back in derrick. PU BHA 91 and RIH with same - tagged ice/fill at 67'. Clean out 16' conductor f/67' 11158' (Spud ® 158' 0 08:45am). Drilling 13-1/2' surface hole f/158' 11195'. Rack back 2 stands of HWDP in derrick and PU MWD tools. Take Gyro survey at 76' and orient directional tools to kick off and TIH 11195'. Drill 13.1/2' surface hole f/195' 1/986(slide/rotate as required) and Gyro survey every stand to ensure Anti -collision & no close approach breaches of ODSK-41/ODSN-40 well bores. 11/2/2009 11/3/2009 986.0 1,358.00 9.10 Directional drill 13-1/2' surface hole section f/986' 112,058'. Take rotational azimuth check MWD surveys at 2,009'& 2,058'(4 surveys per s a ion a egtee intervals). Resume drilling 13-1/2' surface hole section 1/2,058't/2,249'. Circulate and reciprocate drill string f/2,249' 112,160' at 300 gpm with 400 psi while HES directional drillers and HES survey manager discuss Gyro vs MWD surveys. Change out Gyro tools and RIH 111,865' and Gyro -survey out the hole to verify that gyro was working correctly (2nd Gyro resulted in matching surveys from 1st run). HES survey manager confirmed EM MWD surveys were correct, resumed drilling 13.1/2' surface hole section f/2,249' 112,344'. 11/3!2009 11/4/2009 2,344.0 956.00 9.20 RD wireline sheaves for Gyro -surveys, after using second tool to confirm original run (HES Survey). Supervisor ensure EM qualified. Directional drilling 13-1/2' Surface Hole (/2,344' t/3,095'& pumped hi -vis weighted sweep at 3,000'J60% increase). Circulate sweep out the hole & continued Directional drilling f/3,095' 113,200'. Change out liner and piston on #2 mud pump while reciprocating drill string. Madd pass f/3,200' V2,915' w/ EM GR tool while working on mud pump at 2.5 fpm to aid town Geologists w/ Tops. Wash and ream (/2,915' 113,200'. Resume Directional drilling 12-1/2' hole �Aace wjbich was called hole section'TD' by town Geologists. Pump 60 bbl hi -vis weighted sweep and CBU hole clean with 2.5x. POOH 113,300' t(84'- pulled BHA up into the conductor pipe. TIH 1184' 111,583' - rolled over ledge at 1,527'. 11/4/2009 11/5/2009 3,300.0 0.00 9.30 Continue to RIH w/BHA #1 f/1,583' 113,300' w/ some tight spots encountered. Pump 50 BBL'S 2# over Hi -Vis sweep Surf - Surf & 3x CBU, while reciprocating String ® 100 rpm & 750gpm flow. Drop ESS Survey & allow to free fall while 1 Orrin flow check done (static). Pump into place when displacing 30 bbl dry job. POOH w/BHA #1 f/3,300' V631'md. Rack back HWDP & LD 8' Flex/Drlg Jar. Plug into MWD & down load. LD MWD & Motor. RU & run 10-3/4' 45.5ppf L-80 ERW BTC surface casing per program, (Check float - held OK). RIH w/ same 113,244' where PU & MU Vetco Gray casing hanger & landing it. Page 1/5 ReportPrinted: 1/13/2010 PIONEER Operations Summary Report NATURAL RESOURCES Depth Smit _N_WWiM LaM wd Stan Dam End Date owls) (ft) Dery (11VOW) summery 11/5/2009 11/6/2009 3,300.0 0.00 9.30 MU lendingit and land 10-3/4' casino on landino rina @ 3.289.2. Stage up to 11 BPM rate in half BPM increases. Circulate 1 casing volume & able to reciprocate casing 64. RD Franks Fill -Up Tool. Load Top Plug and Second Bottom Plug in cement head. Install First Bottom Plug in casing. RU HES cementing head and lines. Pump 10 bbis seawater at 3 bpm w/ 415 psi. Test Cement head and lines to 4000 psi. Pump 40 bbis 10.0 ppg Dual Spacer at 3.5 bpm w/ 135 psi. Released Second Bottom Plug. Pump 339 bbis 458 sxI Lead cement of 10.9 ppgTYoe Permafrost at 20.0 gps and 4.15 cf/sk at 5.5 bpm —w/850 psi. Pump 42.6 bbis (201 sx) Tai ent f 15.9 Premium 'G' d 2% Calcium Chloride, .2% CFR -3 at 5.23 gps and 1.19 /sk at 3.5 bpm w/ 800 psi. Released Top Plug and disp ac - with 10 bbis seawater. Switch to rig and displace cement w/ 304 bbls seawater at 10 bpm. Maximum pressure obsevered was 3400 psi at 160 bbis away. Stop reciprocating casing & reduced pump rate to 8 bpm at 2200 psi until 240 bbis away, 5 bpm at 1400 psi until 290 bbis away, 3 bpm at 1160 psi until plug bumped at 304 bbis. Increased pressure to 1800 psi, held 5 min. CIP at 06:24 hrs. w/ 102 bbis of good returned cement to Surface. Bled down pressure, checked floats, floats holding. RD Cement Head. ND Surface Drilling Riser and starting head. NU BOPE's. RU MPD Rotating Head . Assembly and circulating lines. Test Rotating Head Assembly and all lines to 250 psi low / 5000 psi high. Low test held 5 min. High test held 10 min. Both tests charted. Notified AOGCC North Slope representative for initial BOPE test on 11/04/09 at 1900 hrs. AOGCC representative Bob Noble waived witness of initial test on 11/05/09 at 1200 hrs. 1116/2009 1177/2009 3,300.0 0.00 8.80. Test MPD HPU & HCR valves to 500 psi low/ 5000 psi high. Low test held 5 min. High test heli 10 min. Both tests charted. Test Annular to 250 psi low / 2500 psi high. Test Upper 2-7/8" x 5' VBR's, Lower 5" Single Bore Rams, Blind Rams, Choke and Kill Line HCR's, Choke and Kill Line manual valves, Floor Safety Valve, Dart Valve, Upper and Lower IBOP (Upper IBOP failed), 14 Choke manifold valves to 250 psi low / 4500 psi high. All low and high tests held 5 min ea. All tests charted. Accumulator test, System Pressure 3000 psi, Atter Closer 2100 psi, Initial 200 psi recovery 22 sec's, Full recovery 1 min 27 sec's. Replace Upper IBOP on Top Drive. Retest to 250 psi low/ 4500 psi high. Both tests held 5 min and charted. Test 10-3/4' 45.54 L-80 BTC surface casing to 3500 psi. Held pressure 30 min. Charted same. RIH w/ BHA #2, 9-7/8' RS Geo -Pilot Assembly 1/3,165'. Cut Drilling Line. Displace seawater with 8.8 ppg LSND mud. 11/7/2009 11/8/2009 3,300.0 1,238.00 9.00 Dislace seawater with 8.8 LSND mud. Drill out 10.3/4" Shoe Track f/3,208' t/3,289'. Clean out 13-1/2" Rat Hole f/3,289' 113,300'. Drill 20' new 9-7/8' hole f/3,300' 113,320'. CSU & Perform LOT w/ 8.8 boa mud at 10-3/4' casin shoe 33 89' MD / 2 979' TVD Pressured up to 1291 psi, 17.13 ppg EMW. Drill 9.7/8' hole section (/3,320' 114,538', while maintaining a 10.5ppg ECD w/MPD. 11/8/2009 11/9/2009 4,538.0 1,438.00 9.10. Drill f/4,538' 114,783'. CBU, lowered ECD f/ 11.35 ppg V 11.15 ppg. Drill f/4,783' 115,976. 11/9/2009 11/10/2009 5,976.0 1,229.00 9.10 Drill f/5,976' 116,950'. RCD element failed, replaced same. Drill 1/6,950' 117,205'. 11/1012009 11/11/2009 7,205.0 1,002.00 9.40 Drill 9-7/8' hole section f/7 205' 117 862'. Lost 81 pump, due to electrical shut down, (mud from #2 inside otor Blower as#2 down for mechanical failure. POOH 8 aid's w/o difficulties & had R2 pump back running, CBU w/390gpm & reciprocate pipe. Rack back a std. every 1/2hr as precaution. Repaired pump S1 & RIH f/6,780' 117,862'md. Drill 9.7/8' hole section }/7,862' V8,207'md. 11/11/2009 11/12/2009 8,207.0 82.00 9.50 Drill f/8,207' 118,289'. C & C mud for Wiper Trip. Perform Wiper Trip 1/8,289' V5,555'. RCD element failed. Change out element. POOH f/5,555' V3,260'. Service Top Drive. RIH f/3,260' 118,207'. Ream down f/8,207' 118,274'. Hole packed off and lost circulation. Worked pipe f/8,274' 117,623' trying to establish circulation. Circulation established at 7,623' at 21 gpm. Increased pump rate at 114 bpm increments until 600 gpm established at 2900 psi with no losses. 11/1242009 11/13/2009 8,289.0 263.00 10.50 C & C mud. Wash down f/7,617' V8,245'. Circulate and weight up LSND mud to 10.5 ppg. Ream down 1/8,245' 118,289. Drill 118,289 118,421'. Lost partial returns. Circulate and bull mud volume, mix LCM Pill w/ fresh H2O. Drill f/8,421' 118,470'. Pump and spot4-CM Pill. Wait 1 hour. --- — Drill 1/8,470' V8,552' holding 12.3 EMW with MPD w/o losses. - - Page -tis---- ..---- Report Printed: 1/1342010 PIONEER Operations Summary Report NATURAL RESOURCES SW Faaihtetew Last NW algin 08 Ertl Data V*% #0 DM (W90) summary 11/13/2009 11/14/2009 8,552.0 1,023.00 10.50 Drill f/8,552' V9,349'. Piston swab on #2 pump failed. Replaced same. Drill V9.349' V9.575' 6 018' TVD to TO Intermediate Hole Section Circulate Hi -Vis sweep surface to surface. NOTE: During pump repairs performed scheduled weekly ROPE function test as per AOGCC regulations. 11/14/2009 11/15/2009 9,575.0 0.00 12.50 C & C mud. Perform wiper trip f/9,575' V8,005'. Replace RCD element. RIH f/8,005' V9,575'. Circulate Hole Clean. Perform Hole Condition Check Trip (/9,575' V8, 100'. Hole in good condition. RIH f/8,100' V9,575'. Displace old 10.5 ppg LSND mud with new 10.5 ppg LSND mud. Weight up 10.5 ppg mud to 12.5 ppg. Notified AOGCC of upcoming 7-5/8' ram test for Intermediate casing on 11/15/09. At 1940 hrs on 11/14/09 AOGCC representative John Crisp waived witness of ram test. 11/15/2009 11/16/2009 9,575.0 0.00 12.50 Finalize mud weight up to 12.5 ppg. Removed RCD element and installed Trip Nipple. Backream (/8,397' V8,130'. Pump out f/8,130' V7,826'. POOH on elevators f/7,8261/5,829'. 1111.612009 11/17/2009 9,575.0 0.00 12.50 POOH w/ BHA #2 and LD same. Install 7-5/8' Rams. Test Annular to 250 psi low / 2500 psi high, test Upper 7-5/8' Fixed Bore Rams to 250 psi low / 4500 psi high. All tests held 5 min each. All test charted. RU and RIH with 7-5/8'29.7# L-80 BTC -M Intermediate casing. j 11/17/2009 11/18/2009 9,575.0 0.00 12.50 RIH with 80 ioints of 7-5/6' 29.7# L80 ETC Mod Casing V3,287'. Circulate 7-5/8' x 10-3/4' Annulus. RIH with 154 joints of 7-5/8' 29.7# L80 BTC -Mod Casing 1/9,523'. Install Hanger and land 7-5/8' casing at 9,566.56'. Circulate casing volume. 1111MINI9 11/19/2009 9,575.0 0.00 10.50 Continue to increase the circulation rate from 147 gpm 0 800 psi to 420 gpm @ 3200 psi.. Circulated casing capacity with no returns. Establish circulation with cement pump and test lines to 4500 psi. Drop first plug and chase same with 55 bbis Dual -Space, and 34 bbls 183 sx Class G cement. Drop top plug and kick out same with 10 bbis sea water. wap over torig pumps and displace with 439 bbls 8 bpm, bumped plug with 1000 psi over. Increase pressure to 4500 psi for 30 min on chart - Good test. RD casing equipment and cement head. MU and RIH with 7-5/8' pack off. Pack off same and test to 5000 psi held 10 min -Good test. Change out topl and bottom rams. Clear floor of casing tools. Slip and cut 70' of drill line. Change out I -80P, saver sub, stabbing guide, and grabber dies from 4.1/2 IF to XT -39. 11/19/2009 11/20/2009 9,575.0 0.00 9.80 LD 14 joints of 5' HWDP, jars and 99 stands DP from the derrick using the mousehole. RD 5' handling tools and RU 4' handling tools. MU BOP test equipment. Attempt to test BOPS to 250 psi low 14500 psi high (AOGCC rep Chuck Sheeve waived witness of test 0 1830 hrs on 11/18/09) - discovered slow leak while testing - check all surface equipment but could not find leak. Changed out sensator on chart recorder - still had leak on tests. Found small leak on Vetco Gray quick connect well head flange. ND RCD equipment, Katch-Kan, and BOP stack. Lift BOP stack, inspect same and found a knicked spot on the sealing surface of the Vetco Gray quick connect flange on top of the riser. Vetco Gray representative dressed the flange with a die grinder and polish wheel and changed out ring gasket. NU BOPE to Vetco Gray drilling riser. Install test plug and fill stack with water. 11/20/2009 11/21/2009 9,575.0 0.00 9.80 Attempt to test BOPE to 250 psi low /4500 psi high - discovered leak on quick connect well head flange. RD test equipment. ND BOP stack - rack back same. NO and remove quick connect from riser. Dress gouges in seal area on quick connector with die grinder. Apply Halliburton Weld -A in gouged areas. Dress same after curing with polish wheel. NU quick connector. Install and NU BOP stack. Test Annular to 250 psi low 12500 psi high. Test all rams and valves to 250 psi low / 4500 psi high. All tests held 5 min as on chart. Accumulator test, System Pressure 3100 psi, After Closure 2000 psi, Initial 200 psi recovery 17 sec's. Full recovery 1 min 28 sec's. AOGCC representative Chuck Scheve on location to witness test. I Page 315 ReportPrinted: 1/13/2010 PIONEER Operations Summary Report NATURAL RESOURCES Page 4/5 Report Printed: 1/1320/0 1 Depth Start F00111iietem Ust MW amnDate End Date (#xB) (to Dens ("Vold) Symine 11/21/2009 11/22/2009 9,575.0 9.80 Test Annular to 250 psi low / 2500 psi high. Test Upper 2.7/8' x 5' VBR's with 4.5' tubing. AOGCC representative Chuck Scheve on location to witness test. RD test equipment. NU all MPD equipment and test same to 250 psi low / 4500 psi high. PU and MU BHA # 3. TIH f/401' V8,875'. TIH 1/8,875' 19,487' with LWD in recorded mode at 225 f /hr for cement bond log. Drill cement and float equipment 1/9,487' 1/9,564'. Circulate and condition mud to 9.8 ppg and catch pug ru er at shakers. 11/22/2009 11/23/2009 91575.0 11050.00 9.80 Remove trip nipple and install ACD head. Drill cement, float shoe and clean out tathole f/9,564' V9,575'. Drilling 1/9,575' 19,585'. Perform FIT at 9,575' and / 6,014' Nd with 9.8 (pg mud to 896 ' psi for EMW of 12.67 ppg. Drilling 1/9,585 V 10,625. rump 30 our hi -vis 25 10113131 LIUM sweep and circulate hole clean with 2x bottoms up strokes. POOH on elevators 1/10,625' V9,564', TIH V9,564'00,626. CBU at 10,625'. 'r0 11/23/2009 11/24/2009 10,625.0 0.00 11.50 Circulate and condition mud weight from 9.8 ppg to 11.5 ppg using 17.0 ppg spike fluid and sack barite. Adjust pump rate and WHP as to not exceed 12.0 ppg ECD. POOH 1/10,625' 1/9,082'. Pull RCD bearing and install trip nipple. Pump dry job and drop 2-3/6' rabbit with 200' tail. TOOH on elevators,/9,082' 1401' (BHA). LD BHA, clean and clear floor of same. RU 4.5' casing equipment and held pre job safety meeting with all involved personnel. MU reamer shoe, float collar, lending collar and circulate through same..Cpntinue RIH with 4.5' 521 HYD 12.6 # L-80 liner V1,222'. 30' total with centralizers on eve 'oint. PU and MU WFT "PH R' hyd liner hanger, 'TSP' liner top packer,'PBR' tie back sleeve, liner running tool, bumper jars, and MU same as per WFT representative. TIH 1/1,222' V2,774' with 4.5' liner on 4' DP. 14/24/2009 11125/2009 10,625.0 " --: 0.00 10.20 TIH 1/2,774' V9,528' with 4.5' liner on 4' DP fill pipe every 20 stands. PU and MU cement head and lines on a single joint of DP and LD same on pipe skate. CBU at 7 5/8' casing shoe. TIH 1/9,528' V10,597' with 4.5' liner. PU and MU cement head and lines, and RIH }/10,597' 110,625'. Drop 1.75' ball and pump down same at 1 bpm with 530 psi, seat ball at 766 strokes, pressure up to 2000 psi to set liner hanger. Pressure up to 3500 psi to shear ball seat, establish circulation and increase pump rate to 213 gpm with 2000 psi. Top of liner set at 9,398.21' and liner shoe set at 10,621'. Swap over to Halliburton and test lines to 4500 psi. Cement with 5s bbis Duals acer at12.5 followed b 47 bbis 225 sx Class G tail cementat 15 h wn pump and slush lines with seawater, drop wiper plug, and chase with 30 bbis 11.5 ppg - viscosified brine. Tum displacement over to rig pumps and displace with 11.5 ppg wbm at 5 bpm at 2000 psi, pumped max displacement of 84.4 bbis and the plug did not bump. Bleed off pressure to check floats - floats holding. Set packer with 55k down wt. Slack off and shear set packer with 60k down wt., pick up, repeat 60K slack off to verity liner in place. Set 40K down on liner top, test inner annulus to 4500 psi held 10 min - Good test. CBU at liner top to circulate out excess cement. Break off single with cement head and lines and lay down same. Break down WFT cement head and found wiper dart had not left the cement head. Circulate while consulting town drilling engineer. Pump 30 bbis hi -vis spacer and displace well to 10.2 ppg brine. 11/25/2009 11/26/2009 10,625.0 0.00 10.20 Finish displacing well over to 10.2 ppg brine. TOH on elevators 1/9,17111202'. LD liner running tool. RU 4.5' handling tools, MU wireline entry sub an Rlc( H with 501oints of 4.5' L-80 12.6# HYD 521 tubing to/2.015% MU Vetco Gray 4.5' tubing hanger, land tubing, test top -an-d-55 obi hanger seals on chart to 5000 psi for 10 min -Good test. Install BPV in tubing hanger. ND MPD equipment. Change out bottom pipe rams from 4' to 4.5'. ND BOP stack and rack back same on stump. Install and NU Vetco Gray Production tree and test voids to 5000 psi for 10 min on chart - Good test. Install test dart in tubing hanger and attempt to test tree to 5000 psi - unsuccessful. Change out test dart and retest to 5000 psi for 10 min on chart - Good test. 440VC ot-i W,a.4 y 12/5/2009 12/6/2009 10,825,0 0.00 1020 Freeze protect ODSN-36 to 2,000'. Drop Ball and Rod. Pump down Tubing and set Pkr w/ 3,500 psi. Held pressure 30 min. Pressure up IA to 3,500 psi to test Pkr. Held pressure 30 min. Both tests charted. Pull Rod and Ball and RHCM Pulg Body with slickline. Secure well. Move rig from ODSN-36 to OSDK 42i. RU E -Line unit. Displace diesel freeze protect with 10.2 ppg brine. RIH w/ RCBL on E -Line. Tagged obstruction at 9,000'. POOH w/ £-Line. 1 NOTE: AOGCC representative Jeff Jones waived witness of initial BORE test to be held for ODSK-42i on 12106/09. Died no for operations on ODSK-42i at 00:01, 12105/09. Page 4/5 Report Printed: 1/1320/0 1 PIONEER Operations Summary Report NATURAL RESOURCES Depth Spn FoWAAhme Last MW Stan Date 12/6/2009 EM Date 12/7/2009 MKe) 10,625.0 (M) 0.00 D" W901) 10.10 stmentary RD E-Line. Set BPV and ND Production Tree and Tubing Bonnet Assy. Install VG Blanking Test Plug. Test Annular to 250 psi low / 2500 psi high. Test Upper 2-7/8' x 5" VBR's, Lower 4.1/2" Single Bore Rams, Blind Rams, Choke and Kill Line HCR's, Choke and Kill Line Manual valves, Floor Safety Valve, Dart valve, Upper and Lower IBOP, 14 Choke Manifold valves to 250 psi low / 4500 psi high. All low and high tests held 5 min ea. All tests charted. Accumulator test, System Pressure 3100 psi, After Closer 2200 psi, Initial 200 psi recovery 23 sec's, Full recovery 1 min 29 sec's. MU Landing Jt and POOH w/ 4.1/2" circulating string RU E-Line and RIH w/ CCU6.59' Gauge Ring/Junk Basket. Tagged obstruction at 3,360', unable to work by. POOH w/ 6.59" Gauge Ring. RIH w/ 6.15" GR/JB. Tagged at 9,000'. POOH w/ 6.15" GR. Recovered 1.1/2 gal cement chips. Rerun 6.15' GR/JB. /•Zrvo 7 72/7/2009 12/8/2009 3,440.0 - 0.00 10.10 -3 Perform 2nd and 3rd runs w/6.15' GR/JB/CCL.tSet 1st 7-5/8` Bridge Plug at 8,950'. Test tat ri PI t 8d5B'. Test 2nd Bridge Plug to 3000 psi. Change lower rams from 4.1/2" 10 4", Test Annular to 250 psi low /2500 psi high. Test Upper 2-7/8' x 5" VBR's and Lower 4' Single Bore rams to 250 psi low 14500 psi high. All tests held 5 min each and charted. Install Wear Ring. RIH w/ Baker/Hughes 7-5/8' Casing Cutter BHA 1/3,438'. 12/8/2009 12/9/2009 3,440.0 0.00 9.20 Cut 7-5/8' Casing at 3 440'. Displace 10.2 ppg brine in 7.5/8' Casing with 9.2 ppg LSND mud. Close Annular and displace diesel freeze protect from 7-5/8" x 10-/3/4" Annulus with 9.2 ppg LSND mud. POOH with Casing Cutter BHA. Change Upper Rams f/ 4" V 7-5/8". Test Annular to 250 psi low / 2500 psi high. Test Upper 7.5/8" Rams to 250 psi low / 4500 psi high. All tests had 5 min and charted. MU Baker/Hughes 7-5/8" Spear. Spear 7-5/8" Casing below VG Hanger. Pull Hanger free w/ 200k PUW. Circulate 2 x BU, MW In 9.2 ppg, MW Out 9.2 ppg. Pull Hanger and LD same. POOH w/ 7-5/8'29.7# L-80 BTC-M Casing. Change Upper Rams from 7-5/8' to 2-7/8' x 5' VBR's. Test Annular to 250 psi low psi high. Test Upper 2-7/8" x 5' VBR's and Lower 4" Single Bore Rams to 250 psi low/4500 psi high. All tests held 5 min and charted. RU 2.7/8' Tubing Tongs and handling equipment. Page 515 ReportPrinted: 1113/2010 PIONEER NATURAL RESOURCES Operations Summary Report Category: DEVELOPMENT DRILL Start Date: 12/5/2009 End Date: 12/6/2009 la nw[vua u.0 9.20 RIH w/ 549' of 2.7/8' Tbg Cement Stinger on 4' DP. CPU. Set Balanced Cement PPI! _ w/35 bbl 196 sx 17.0 Class 'G' 0.25% CaC12 .75°,6 CFR -3 cement 1/3`' V-3,11 9'. POOH 113,058'. CBU 2x. POOH and LD Cement Stinger. Change Lower Rams f/ 4' - V 5'. C/O 4' Upper and Lower IBOP's, Gripper Dies and Stabbing Guide on Top Drive to 5'. Perform DP management, PU 180 Jts 5' DP and stand back 90 Jts in derrick. NOTE: At 05:00 hrs notified AOGCC and gave them 24 m notice for SOPE test to be performed on 12/10/09. At 10:00 hrs on 12/09/09 AOGCC representative Jeff Jones waived witness of test. M 1/2009 3,289.0 10.00 9.30 Perform OF Maintenance 112,600'. Flush DP. Cut Drilling Line and service Top Drive. Wash down and Tag Cement at 3,179'w/ 19k. POOH stand back DP in derrick. Test Annular to 250 psi low 12500 psi high. Test Upper 2.7/8' x 5' VBR's, Lower 5' Single Bore Rams, Blind Rams, Choke and Kill Line NCR's, Choke and Kill Line Manual valves, floor Safety valve, Dan valve, Upper and Lower IBOP, 14 Choke Manifold valves to 250 psi low/ 4500 psi high. All low and high tests held 5 min ea. All tests charted. Accumulator test, System Pressure 3050 psi, After Closer 2200 psi, Initial 200 psi recovery 23 sec's, Full recovery 1 min 34 sec's. RIH w/ 9.7/8' ASS Geo-Ptlot BHA #6 V3,179'. Clean out cement stringers 1/3,179 V3220', tagged hard cement w/ 25k bit weight. Drill Cement 113,220' V3,299'. NOTE: Witness of ROPE test waived by AOGCC representative Jeff Jones at 1000 hrs on 12/9/09. r Page 1/3 Report Printed: 1/14/2010 ODSK-42i Kuparuk Injection — Abandonment Well Head: 9 5113", 5K, VatcoGray Conductor pipe @ 158' MD it plug top @ 3179' MD %<" 45.5 ppf Surface Casing 3289' MD / 2980' TVD i/8" 29.7 ppf casing stub / 3441' MD plug at 3450' MD -,� plug at 8950' MD 12.6 ppf Liner top (with packer) 9398' MD / 5925' TVD 3" 29.7 ppf Intermediate Casing 9567' MD / 6014' TVD 9595' MD 0,235' MD 12.6 ppf Liner bottom 10,621' MD / 6702' TVD PIONEER Date: Revision By: Comments ODSK-42i Injector Well Schematic Version 3.0 11/30/09 VTJ Proposed Completion 01/11/10 KLC Abandonment NATURAL RESOURCES 6 Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Ooogumk Drill Site Well: ODSK421 Wellbore: ODSK42i Design: ODSK42i KupG Halliburton Company Definitive Survey Report Local Co-ordinate Reference: Well ODSK42i - Slot ODS -42 TVD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) MD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM 2003.16 Single User Db ,reject Oooguruk Development Lisp System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor Well ODSK-42i - Slot ODS -42 ODSK-42i KupG Well Position +N/ -S 0.00 ft Northing: 6,031,028.13 it Latitude: 70° 29'45.027 N +E/ -W 0.00 it Easting: 469,844.38 ft Longitude: 150° 14'47.689 W Position Uncertainty 0.00 it Wellhead Elevation: it Ground Level: 13.5011 Wellbore ODSK42i Magnetics Model Name Sample Date Declination Dip Angle Field Strength i (`) (`) (nT) IGRF200510 10/27/2009 - 22.07 _80.81 57,752 Design ODSK-42i KupG Audit Notes: Map I Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction +N/ -S (ft) (ft) (ft) (1) DLS 42.70 0.00 0.00 143.41 Survey Program Date 1271/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 50.00 1,484.00 ODSK42i Gyro (ODSK42i) SR -Gyro -SS Fixed:v2:surface readout gyro single shot 11/2/2009 1: 1,575.40 10,611.85 ODSK-42i MWD (ODSK421) MWD+IFR2+MS+sag Fixed:v2:IIFR dec 8 3 -axis correction + sag 11/2/2009 1: Survey 12/1/2009 2:06:09PM Page 2 COMPASS 2003.16 Build 71 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (% (1 Ift) (n) (ft) (ft) (ft) (ft) (-/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,028.13 469,844.38 0.00 0.00 UNDEFINED 50.00 0.14 45.30 50.00 -6.20 0.01 0.01 6,031,028.14 469,844.39 1.92 0.00 SR-Gyro-SS(1) 100.00 0.18 167.40 100.00 43.80 -0.03 0.07 6,031,028.10 469,844.45 0.56 0.06 SR-GyroSS(1) 171.00 0.64 262.06 171.00 114.80 -0.19 -0.30 6,031,027.94 469,844.08 0.96 -0.03 SR -Gyro -SS (1) 258.00 0.82 265.08 257.99 201.79 -0.31 -1.40 6,031,027.82 469,842.98 0.21 -0.59 SR -Gyro -SS (1) 348.00 0.89 241.49 347.98 291.78 -0.70 .2.66 6,031,027.44 469,841.72 0.40 -1.02 SR -Gyro -SS (1) 441.00 1.39 221.79 440.96 384.76 -1.89 4.05 6,031,026.26 469,840.33 0.68 -0.90 SR -Gyro -SS (1) 531.00 2.12 195.00 530.92 474.72 4.31 -5.20 6,031,023.84 469,839.16 1.20 0.36 SR -Gyro -SS (1) 625.00 1.79 190.29 624.87 568.67 -7.43 -5.92 6,031,020.72 469,838.43 0.39 2.44 SR -Gyro -SS (1) 721.00 1.66 160.05 720.82 664.62 -10.21 -5.71 6,031,017.94 469,838.63 0.95 4.80 SR -Gyro -SS (1) 815.00 2.41 149.29 814.76 768.56 -13.19 4.24 6,031,014.96 469,840.09 0.89 8.07 SR-GyroSS(1) 912.00 2.46 152.06 911.68 855.48 -16.79 -2.22 6,031,011.35 469,842.09 0.13 12.16 SR -Gyro -SS (1) 1,007.00 3.23 165.85 1,006.56 950.36 -21.18 -0.61 6,031,006.95 469,843.69 1.08 16.64 SR -Gyro -SS (1) 12/1/2009 2:06:09PM Page 2 COMPASS 2003.16 Build 71 Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK-421- Slot ODS42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) Site: Oooguruk Drill She MD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) Well: ODSK-42i North Reference: True Wellbore: ODSK-42i Survey Calculation Method: Minimum Curvature Design: ODSK-42i KupG Database: EDM 2003.16 Single User Db Survey Map Map Vertical j MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (tt) (0) (") (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,101.00 4.99 179.14 1,100.32 1,044.12 -27.84 0.10 6,031,000.29 469,844.37 2.12 22.41 SR -Gyro -SS (1) 1,196.00 5.85 176.72 1,194.89 1,138.69 -36.80 0.44 6,030,991.33 469,844.67 0.94 29.81 SR -Gyro -SS (1) i 1,292.00 7.26 175.88 1,290.26 1,234.06 47.74 1.15 6,030,980.39 469,845.34 1.47 39.02 SR -Gyro -SS (1) 1,386.00 8.58 172.24 1,383.36 1,327.16 -60.61 2.53 6,030,967.52 469,846.66 1.50 50.17 SR -Gyro -SS (1) 1,484.00 10.82 170.95 1,479.95 1,423.75 -76.94 4.96 6,030,951.18 469,849.03 2.30 64.74 SR -Gyro -SS (1) 1,575.43 12.73 168.73 1,569.46 1,513.26 -95.30 8.28 6,030,932.81 469,852.27 2.15 81.45 MWD+IFR2+MS+sag (2) 1,618.69 12.79 171.58 1,611.65 1,555.45 -104.71 9.91 6,030,923.39 469,853.87 1.46 89.98 MWD+IFR2+MS+sag(2) . 1,712.47 15.65 162.09 1,702.56 1,646.36 -127.02 15.33 6,030,901.06 469,859.19 3.92 111.12 MWD+IFR2+MS+sag (2) 1,806.04 16.60 158.10 1,792.45 1,736.25 -151.43 24.19 6,030,876.62 469,867.96 1.56 136.01 MWD+IFR2+MS+sag (2) 1,906.59 18.70 155.57 1,888.26 1,832.06 -179.44 36.22 6,030,848.56 469,879.87 2.22 165.66 MWD+IFR2+MS+sag (2) 1,959.77 19.43 153.54 1,938.52 1,882.32 -195.12 43.69 6,030,832.86 469,887.27 1.85 182.70 MWD+IFR2+MS+sag(2) 1,999.47 20.97 152.67 1,975.78 1,919.58 -207.34 49.89 6,03D,820.61 469,893.42 3.95 196.22 MWD+IFR2+MS+sag (2) 2,095.04 21.66 150.88 2,064.81 2,008.61 -237.94 66.32 6,030,789.94 469,909.73 0.99 230.58 MWD+IFR2+MS+mg(2) 2,191.30 23.69 151.46 2,153.63 2,097.43 -270.45 84.21 6,030,757.36 469,927.48 2.12 267.35 MWD+IFR2+MS+sag(2) 2,287.47 25.56 157.51 2.241.06 2,184.86 -306.60 101.38 6.030,721.15 469,944.51 3.26 306.61 MWD+IFR2+MS+sag (2) 2,347.37 26.64 158.20 2,294.85 2,238.65 -331.01 111.31 6,030,696.70 469,954.34 1.87 332.13 MWD+IFR2+MS+sag(2) 2,381.53 28.00 159.80 2,325.20 2,269.00 -345.65 116.92 6,030,682.04 469,959.89 4.52 347.23 MWD+IFR2+MS+sag (2) 2,474.31 30.49 162.69 2,406.15 2,349.96 -386.57 131.45 6,030,639.07 469,974.24 3.08 390.35 MWD+IFR2+MS+sag(2) 2,569.77 34.04 160.33 2,486.87 2,430.67 436.87 147.66 6,030,590.71 469,990.25 3.95 438.79 MWD+IFR2+MS+sag (2) 2,667.55 38.31 161.04 2,565.78 2,509.58 491.33 166.72 6,030,536.18 470,009.09 4.39 493.88 MWD+IFR2+MS+sag (2) 2,762.31 41.94 157.52 2,638.24 2,582.04 -548.39 188.39 6,030,479.03 470,030.52 4.52 552.61 MWD+IFR2+MS+sag(2) 2.857.29 44.80 155.75 2,707.26 2,651.08 -608.25 214.27 6,030,419.08 470,056.16 3.27 616.10 MWD+IFR2+MS+mg(2) 2,952.38 47.72 150.81 2,773.03 2,716.83 -669.53 245.21 6,030,357.67 470,D86.a4 4.85 683.75 MWD+IFR2+MS+sag (2) 1 3,047.36 49.19 148.11 2,836.03 2,779.83 -730.74 281.34 6,030,296.33 470,122.72 2.63 754.42 MWD+IFR2+MS+sag(2) 3,140.17 52.37 147.01 2,894.71 2,838.51 -791.40 319.91 6,030,235.52 470,161.05 3.55 826.13 MWD+IFR2+MS+sag (2) i 3,237.43 56.17 144.26 2,951.50 2,895.30 -856.53 364.50 6,030,170.22 470,205.37 4.53 905.00 MWD+IFR2+MS+sag(2) 3,326.94 57.83 142.22 3,000.25 2,944.05 -916.65 409.43 6,030,109.91 470,250.05 2.66 980.06 MWD+IFR2+MS+sag (2) 3,421.73 59.13 140.98 3,049.81 2,993.61 -979.97 459.63 6,030,046.40 470,299.98 1.77 1,060.82 MWD+IFR2+MS+sag (2) 3,517.01 61.55 141.41 3,096.96 3,040.76 -1,044.49 611.50 6,029,981.68 470,351.59 2.57 1,143.54 MWD+IFR2+MS+sag(2) 3,611.57 63.26 142.16 3,140.77 3,084.57 -1,110.33 563.34 6,029,915.64 470,403.15 1.92 1,227.30 MWD*IFR2+MS+sag (2) 3,708.10 63.79 142.60 3,183.82 3,127.62 -1,178.76 616.08 6,029,846.99 470,455.61 0.70 1,313.69 MWD+IFR2+MS+sag (2) 3,803.47 64.86 142.14 3,225.14 3,168.94 -1,246.83 668.56 6,029,778.72 470,507.81 1.20 1,399.63 MWD+1FR2+MS+sag (2) '., 3,897.92 63.65 141.02 3,266.17 3,209.97 -1,313.49 721.42 6,029,711.86 470,560.39 1.67 1,484.65 MWD+IFR2+MS+sag (2) 3,992.91 63.10 140.89 3,308.74 3,252.54 -1,379.44 774.91 6,029.645.70 470,613.61 0.59 1,569.49 MWD+IFR2+MS+sag (2) 4,086.79 62.72 141.21 3,351.49 3,295.29 -1,444.44 827.45 6,029,580.49 470,665.88 0.51 1,653.00 MWD+IFR2+MS+sag (2) 4,183.17 62.80 141.03 3,395.60 3,339.40 -1,511.15 881.24 6,029,513.57 470,719.39 0.19 1,738.62 MWD+IFR2+MS+sag (2) 4,278.68 62.87 140.92 3,439.21 3,383.01 -1,577.16 934.74 6,029,447.35 470,772.63 0.13 1,823.52 MWD+IFR2+MS+sag (2) 4,373.55 62.97 141.30 3,482.40 3,426.20 .1,642.91 987.78 6,029,381.39 470,825.39 0.37 1,907.92 MWD+IFR2+MS+sag (2) 4,467.74 63.16 141.62 3,525.06 3,468.86 .1,708.59 1,040.10 6,029,315.51 470,877.43 0.36 1,991.85 MWD+IFR2+MS+sag (2) 4,559.49 63.03 142.21 3,566.58 3,510.38 -1,772.99 1,090.56 6,029,250.91 470,927.63 0.59 2,073.64 MWD+IFR2+MS+sag(2) 121112009 2:06:09PM Page 3 COMPASS 2003.16 Build 71 Company: Project: Site: Well: Wellbore: Design: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site - ODSK-42i ODSK42i ODSK-42i KupG Halliburton Company Definitive Survey Report Local Co-ordinate Reference: Well ODSK-42i - Slot ODS -42 TVD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) MD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) North Reference: True Survey Calculation Method: Minimum Curvature Database: -- EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (0) (1) (ft) (ft) (ft) (fl,) (ft) (ft) (°1100') (ft) Survey Tool, Name _ 4,658.86 63.01 142.31 3,611.66 3,555.46 -1,843.02 1,144.77 6,029,180.67 470,981.55 0.09 2,162.17 MWD+IFR2+MS+sag (2) 4,754.07 62.66 142.16 3,655.13 3,598.93 .1,909.98 1,196.64 6,029,113.50 471,033.15 0.39 2,246.86 MWD+IFR2+MS+sag(2) 4,849.43 63.06 141.87 3,698.63 3,642.43 -1,976.86 1,248.87 6,029,046.41 471,085.10 0.50 2,331.70 MWD+IFR2+MS+sag(2) 4,944.50 63.08 141.72 3,741.69 3,685.49 -2,043.47 1,301.29 6,028,979.60 471,137.25 0.14 2,416.43 MWD+IFR2+MS+sag(2) 5,039.07 62.59 141.58 3,784.87 3,728.67 -2,109.45 1,353.50 6,028,913.41 471,189.18 0.53 2,500.52 MWD+IFR2+MS+sag (2) 5,134.85 62.26 141.90 3,829.20 3,773.00 -2,176.12 1,406.07 6,028,846.54 471,241.47 0.45 2,585.39 MWD+IFR2+MS+sag(2) 5,230.16 62.47 141.81 3,873.41 3,817.21 -2,242.52 1,458.22 6,028,779.93 471,293.35 0.24 2,669.79 MWD+IFR2+MS+sag (2) 5,325.31 61.55 141.44 3,918.07 3,861+87 .2,308.39 1,510.38 6,028,713.86 471,345.24 1.03 2,753.77 MWD+IFR2+MS+sag(2) 5,420.47 60.93 142.21 3,963.85 3,907.65 -2,373.97 1,561.94 6,028,648.08 471,396.53 0.96 2,837.16 MWD+1FR2+MS+sag(2) i 5,515.35 61.54 141.90 4,009.51 3,953.31 -2,439.56 1,613.09 6,028,582.29 471,447.40 0.70 2,920.31 MWD+IFR2+MS+sag(2) 1 I 5,610.35 61.82 142.34 4,054.58 3,998.38 -2,505.57 1,664.43 6,028,516.08 471,498.47 0.50 3,003.92 MWD+IFR2+MS+sag(2) 5,705.63 61.77 142.06 4,099.61 4,043.41 -2,571.91 1,715.90 6,028,449.53 471,549.66 0.26 3,087.86 MWD+IFR2+MS+sag(2) 5,801.28 61.76 142.24 4,144.86 4,088.66 -2,638.45 1,767.61 6,028,382.79 471,601.09 0.17 3,172.11 MWD+IFR2+MS+sag (2) 5,896.18 61.54 142.52 4,189.92 4,133.72 -2,704.61 1,818.59 6,028,316.44 471,651.80 0.35 3,255.62 MWD+IFR2+MS+sag(2) 5,990.79 61.76 142.39 4,234.85 4,178.65 -2,770.62 1,869.33 6,028,250.22 471,702.27 0.26 3,338.87 MWD+IFR2+MS+sag (2) 6,086.27 61.90 143.05 4,279.93 4,223.73 -2,837.60 1,920.31 6,028,183.05 471,752.97 0.63 3,423.03 MWD+1FR2+MS+sag (2) 6,181.15 61.84 142.56 4,324.66 4,268.46 -2,904.25 1,970.89 6,028,116.20 471,803.28 0.46 3,506.70 MWD+IFR2+MS+sag(2) 6,275.27 61.55 141.76 4,369.29 4,313.09 -2,969.69 2,021.72 6,028,050.56 471,853.64 0.81 3,589.55 MWD+IFR2+MS+seg (2) 6,369.48 61.34 141.72 4,414.32 4,358.12 -3,034.66 2,072.97 6,027,985.38 471,904.81 0.23 3,672.26 MWD+IFR2+MS+sag(2) 6,464.82 61.42 141.46 4,459.99 4,403.79 -3,100.24 2,124.96 6,027,919.60 471,956.54 0.25 3,755.91 MWD+IFR2+MS+sag(2) 6,559.43 61.33 141.92 4,505.31 4,449.11 -3,165.41 2,176.44 6,027,854.23 472,007.75 0.44 3,838.92 MWD+IFR2+MS+sag (2) i 6,655.70 61.61 141.58 4,551.29 4,495.09 -3,231.83 2,228.81 6,027,787.61 472,059.84 0.43 3,923.46 MWD+IFR2+MS+sag (2) 1 6,751.48 61.67 141.55 4,596.79 4,540.59 -3,297.85 2,281.20 6,027,721.38 472,111.96 0.07 4,007.70 MWD+IFR2+MS+sag (2) 6,846.21 60.79 140.73 4,642.38 4,586.18 -3,362.51 2,333.30 6,027,656.52 472,163.79 1.20 4,090.67 MWD+IFR2+MS+sag (2) 6,941.57 59.97 140.17 4,689.52 4,633.32 -3,426.43 2,386.08 6,027,592.39 472,216.30 1.00 4,173.46 MWD+IFR2+MS+sag(2) 7,036.46 59.78 140.47 4,737.14 4,680.94 -3,489.59 2,438.48 6,027,529.02 472,268.45 0.34 4,255.41 MWD+IFR2+MS+sag(2) 7,131.75 59.43 140.18 4,785.35 4,729.15 -3,552.86 2,490.96 6,027,465.55 472,320.66 0.45 4,337.49 MWD+IFR2+MS+sag(2) 7,226.13 59.51 139.93 4,833.30 4,777.10 -3,615.18 2,543.15 6,027,403.02 472,372.60 0.24 4,418.64 MWD+IFR2+MS+sag (2) 7,321.78 59.93 140.39 4,881.53 4,825.33 -3,678.61 2,596.07 6,027,339.39 472,425.25 0.60 4,501.11 MWD+IFR2+MS+sag(2) 7,417.05 60.15 140.92 4,929.10 4,872.90 -3,742.44 2,648.40 6,027,275.35 472,477.31 0.53 4,583.55 MWD+IFR2+MS+sag(2) 7,511.71 60.15 140.96 4,976.22 4,920.02 -3,806.19 2,700.13 6,027,211.40 472,528.78 0.04 4,665.58 MWD+IFR2+MS+sag(2) 7,606.99 60.21 141.11 5,023.60 4,967.40 -3,870.46 2,752.12 6,027,146.92 472,580.50 0.15 4,748.17 MWD+IFR2+MS+sag(2) 7,701.90 60.76 141.16 5,070.36 5,014.16 -3,934.77 2,803.94 6,027,082.41 472,632.06 0.58 4,830.70 MWD+IFR2+MS+sag (2) 7,797.14 60.44 141.61 5,117.11 5,060.91 -3,999.60 2,855.73 6,027,017.37 472,683.58 0.53 4,913.62 MWD+IFR2+MS+sag(2) 7,892.89 60.07 142.23 5,164.62 5,108.42 -0,065.04 2,907.00 6,026,951.73 472,734.58 0.68 4,996.73 MWD+IFR2+MS+sag(2) 7,988.41 59.77 141.77 5,212.49 5,156.29 -4,130.18 2,957.89 6,026,886.40 472,785.20 0.52 5,079.36 MWD+IFR2*MS+sag (2) 8,083.24 59.52 141.87 5,260.41 5,204.21 4,194.50 3,008.47 6,026,821.88 472,835.51 0.28 5,161.16 MWD+IFR2+MS+sag(2) 8,177.99 59.92 141.93 5,308.19 5.251.99 -4,258.89 3,058.96 6,026,757.29 472,885.73 0.43 5,242.95 MWD+IFR2+MS+sag (2) 8,272.68 59.56 140.96 5,355.91 5,299.71 -4,322.85 3,109.93 6,026,693.13 472,936.44 0.96 5,324.69 MWD+IFR2+MS+sag (2) 8,368.43 59.87 140.88 5,404.19 5,347.99 4,387.03 3,162.05 6,026,628.74 472,988.30 0.33 5,407.29 MWD+IFR2+MS+sag(2) 12/1/2009 2:06.,09PM Page 4 COMPASS 2003.16 Build 71 Halliburton Company 4 Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK42i - Slot ODS -42 Project: Oooguruk Development TVD Reference: 42.7 + 13.5'@ 56.20f1(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5'@ 56.20ft (Nabors 19AC) Well: ODSK-42i North Reference: True Wellbore: ODSK42i Survey Calculation Method: Minimum Curvature Design: ODSK-421 KupG Database: EDM 2003.16 Single User Db Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (ft) (1) (0) Ift) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 8,463.64 59.96 141.09 5,451.92 5,395.72 4,451.04 3,213.92 6,026,564.53 473,039.90 0.21 5,489.60 MWD+IFR2+MS+sag (2) 8,558.79 59.58 140.98 5,499.83 5,443.63 -4,514.96 3,265.61 6,026,500.40 473,091.33 0.41 5,571.74 MWD+IFR2+MS+sag (2) 8,654.04 59.86 141.15 5,547.85 5,491.65 4,578.95 3,317.31 6,026,436.22 473,142.76 0.33 5,653.93 MWD+1FR2+MS+sag(2) 8,749.89 59.71 140.97 5,596.09 5,539.89 4,643.37 3,369.36 6,026,371.59 473094.55 0.23 5,736.69 MWD+IFR2+MS+sag (2) 8,844.91 59.36 141.28 5,644.27 5,588.07 4,707.13 3,420.77 6,026,307.63 473,245.69 0.46 5,818.52 MWD+IFR2+MS+sag (2) 8,940.88 60.06 141.26 5,692.67 5,636.47 4,771.78 3,472.61 6,026,242.78 473,297.27 0.73 5,901.33 MWD+IFR2+MS+sag(2) 9,031.66 59.79 140.71 5,738.16 5,681.96 4,832.82 3,522.07 6,026,181.55 473,346.47 0.60 5,979.82 MWD+IFR2+MS+sag(2) 9,125.12 59.72 140.61 5,785.24 5,729.04 4,895.26 3,573.25 6,026,118.90 473,397.39 0.12 6,060.47 MWD+IFR2+MS+sag (2) 9,224.20 59.22 141.02 5,835.57 5,779.37 -4,961.41 3,627.17 6,026,052.54 473,451.04 0.62 6,145.72 MWD+IFR2+MS+sag(2) 9,319.98 5925 141.34 5,884.57 5,828.37 -5,025.53 3,676.76 6,025,988.22 473,502.36 '0.29 6,227.96 MWD+IFR2+MS+sag (2) 9,415.35 58.44 141.58 5,933.91 5,877.71 -5,089.37 3,729.62 6,025,924.18 473,552.95 0.88 6,309.53 MWD+IFR2+MS+sag(2) 9,510.56 58.35 139.63 5,963.80 5,927.60 -5,152.03 3,781.07 6,025,861.32 473,604.15 1.75 6,390.51 MWD+1FR2+MS+sag(2) 9,546.62 57,67 139.60 6,002.91 5,946.71 -5,175.32 3,800.89 6,025,837.94 473,623.87 1.89 6,421.03 MWD+IFR2+MS+sag(2) 9,646.81 57.09 139.69 6,056.92 6,000.72 -5,239.63 3,855.53 6;025,773.42 473,678.25 0.58 6,505.23 MWD+IFR2+MS+sag(2) 9,744.20 55.56 140.62 6,110.92 6,054.72 -5,301.85 3,907.46 6,025,711.00 473,729.92 1.76 6,586.15 MWD+IFR2+MS+sag(2) 9,839.76 53.79 141.67 6,166.17 6,109.97 -5,362.55 3,956.38 6,025,650.10 473,778.58 2.06 6,664.05 MWD+IFR2+MS+sag(2) 9,890.03 52.88 141.82 6,196.19 6,139.99 -5,394.22 3,981.34 6,025,618.34 473,803.42 1.83 6,704.35 MWD+1FR2+MS+sag(2) 9,936.57 51.98 142.53 6,224.56 6,166.36 -5,423.35 4,003.97 6,025,589.12 473,825.92 2.28 6,741.23 MWD+IFR2+MS+sag (2) 10,031.95 50.14 143.14 6,284.51 6,228.31 .5,482.47 4,048.79 6,025,529.83 473,870.49 1.99 6,815.41 MWD+IFR2+MS+sag(2) 10,129.34 48.15 144.44 6,348.21 6,292.01 -5,541.89 4,092.31 6,025,470.23 473,913.77 2.28 6,889.07 MWD+IFR2+MS+sag (2) 10,226.73 45.89 145.13 6,414.61 6,358.41 -5,600.09 4,133.40 6,025,411.87 473,954.62 2.38 6,960.29 MWD+IFR2+MS+sag (2) 10,321.38 45.10 145.06 6,480.95 6,424.75 .5,655.45 4,172.02 6,025,356.36 473,993.02 0.84 7,027.76 MWD+IFR2+MS+Sag (2) 10,416.67 43.96 145.94 6,550.31 6,494.11 5,711.67 4,210.67 6,025,299.99 474,031.43 1.33 7,095.94 MWD+IFR2+MS+sag(2) 10,514.22 42.01 148.41 6,620.21 6,564.01 .5,766.39 4,246.00 6,025,245.13 474,066.53 2.70 7,160.94 MWD+IFR2+MS+sag(2) 10,611.85 38.97 148.32 6,694.45 6,636.25 -5,820.36 4,279.24 6,025,191.03 474,099.56 3.11 7,224.09 MWD+1FR2+MS+sag(2) 10,625.00 38.97 148.32 6,704.67 6,646.47 -5,827.40 4,283.59 6,025,183.98 474,103.87 0.00 7,232.33 PROJECTED to TO 121112009 2:06:09PM Page 5 COMPASS 2003.16 Build 71 SEAN PARNELL, GOVERNOR 6 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM USSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99051©G Re: Oooguruk, Kuparuk Oil, ODSK-42i Sundry Number: 309-401 Dear Mr. Johnson: 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, M Cathy 1 . Foerster Commissioner DATED this day of December, 2009 Encl. PIONEER NATURAL RESOURCES DECEIVED DEC 0 1 2009 November 30, 2009 4bska Oil & Gas Cons. Commission Anchorage State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Abandonment ODSK-421, PTD 209-120 Surface Location: 2912' FSL, 11 54'FEL, Sec 11, T13N, R7E, UM X = 469844.38, Y = 6031028.13, ASP4 i Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for the abandonment of ODSK-42i. As described in a recent operational shutdown application for ODSK-42i, LWD logs indicated less Kuparuk sand than expected, and the sand quality was much lower than expected, so the well will not be an effective injector. The existing lower completion will be abandoned, a bridge plug will be installed in the intermediate casing, and casing will be cut and pulled. A cement plug will be place above the bridge plug and the well will be sidetracked to a new location. The included application covers operations up to the spotting of the abandonment plug. Please see the attached form 10-403, operations program and schematic. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Report of Sundry Well Operations Vern Johnson, Senior Staff Drilling Engineer 20 AAC 25.070(3) 907.343.2111 vern.iohnson(a)pxd.com If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sin rely, l Z/r l e) Z ern Johnson Senior Staff Drilling Engineer Attachments: Form 10-403 cc: ODSK-42i Well File ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIVIV APPLICATION FOR SUNDRY APPROVALS 90 AArt 9R 9Rn DEC 0 1 2009 Alaska Oil & G7,- 1. x 1. Type of Request: Abandon ❑� Suspend ❑ Operational shutdown ❑ Perforate ❑ Re-enter Suspended Well 4,14, R Alter casing Q ' Repair well ❑ Plug Perforations ❑ Stimulate[—] Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service O 209.120 3. Address: 6. API Number: 700 G Street, Suite 600, Anchorage, AK 99051 50-703-20605-00 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 0 ODSK-42i 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 ' Odoguruk - Kuparuk Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (h): Total Depth TVD (it): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,625' 6705' 10,618' 1 6699' 1 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3251' 10-3/4" 3289' 2980' 5210 2470 Intermediate 9529' 7-5/8" 9567' 6014' 6890 4790 Production 1223' 4-1/2" 9398' - 10,621' 5925'- 6702' 8430 7500 Liner Perforation Depth MD (h): Pertoration Depth TVD (h): Tubing Size: Tubing Grade: Tubing MD (h): N/A N/A 4-1/2", 12.611 L-80, HYD 521 2015' Packers and SSSV Type: Packers and SSSV MD (it) and TVD (N): TSP Liner Top Packer 9398' MD / 5925' TVD 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/5/2009 Oil ❑ Gas ❑ WINJp,m GINJ ❑ WDSPL ❑ Plugged 21 . WAG 1-1Abandonedv'f 16. Verbal Approval: Date: Commission Representative: o� t_ GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan, 343-2186 Printed Name Vern Johnson Title Sr. Staff Drilling Engineer Signature IL///Z Phone 343-2111 Date 12/1/2009 4 LZ Prepared By: Kathy Cam mor, 343-2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity [✓� BOP Test Pr Mechanical Integrity Test ❑ Location Clearance ❑ Other: 'a4"� 00 PSS -St - *2 sS)o psi 14r rLk AA --res�— Subsequent Form Required: /0.'407 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /z —4-09 A RMI � � 1 "?"'bRIGINAL Form 10-403 Revised 7/2009 Submit in Duplicate D0, tv Pioneer Natural Resources Well Plan Summary Drilling Operations Rise Activity: Drill and Complete 1. MIRU Nabors 19AC over ODSK-42i. 2. Displace diesel freeze protect fluid to 10.2 ppg brine through the tree and inner annulus. 3. Set BPV and blanking plug. 4. Nipple down tree. 5. Nipple up and test BOP's to 250/4500 psi. 6. Recover BPV and blanking plug. 7. Rig up eline and pick up cement evaluation tool. _ �,� J- �.►� 8. Log 4-1/2" liner. -->> F,,.tl leiJw j .�u rc 1 ►` d''� �6ow.Q i,�`�' j ("` 9. Pick up a 7-5/8" bridge plug on a line and set it -50' above the liner top (-9350' MD). yL 10. Pick up a 7-5/8" bridge plug on a line and set it -250' below the surface casing shoe depth (3539' /Z•Z-o% MD). 11. Rig down eline. 12. Pick up a mechanical casing cutter and run in hole on 4" drillpipe. 13. Cut 7-5/8" casing at -3439' MD (150' from the surface casing shoe depth) . 14. Pull out of hole with cutter. 15. Spear casing and pull 7-5/8" casing from surface 16. Pick up a 500' tubing stinger and run in hole. 17. Attempt to enter the 7-5/8" casing stub. 18. Spot a balanced cement plug from 3539' MD to 3189' MD. 19. Pull out of hole and lay down cement stinger. 20. Pick up drilling BHA to kick off cement plug and redrill well to new targets (To be covered under a separate permit to drill application) No fev'e, de[r%eo� kettedf Pioneer Natural Resources ODSK-42i Abandonment procedure 017 C Ovw Last Revised: November 30, 2009 Page 1 of 2 ODSK-421 Kuparuk Injection — Proposed Abandonment Well Head: 95/8', 5K, VetcoGray 16" Conductor pipe @ 158' MD Cement plug top @ 3189' MD 10-%" 45.5 ppf surface casing 3289' MD / 2980' TVD 7-5/8" 29.7 ppf casing stub 3439' MD Bridge plug at 3539' MD plug at 9350' MD 4-1/2" 12.6 ppf Liner top (with packer 9398' MD / 5925' TVD Top Kuparuk 9597' MD 10092' MD ''%" 12.6 ppf Liner bottom 10621' MD / 6702' TVD PIONEER Date: Revision By: Comments ODSK-42i Injector Well Schematic Version 3.0 11/30/09 vri Proposed Completion NATURAL RESOURCES Pioneer Natural Resources Last Revised: November 30, 2009 ODSK-42i Abandonment procedure Page 2 of 2 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 02, 2009 3:33 PM To: 'Johnson, Vern' Subject: RE: ODSK42i abandonment procedure Vern, I agree with the below addition of testing the 7 5/8" rams and re -installing the 5" VBRs after pulling casing.. We also need to add a step (after step 9) to test the lower 7 5/8" bridge plug. I assume it will be to 4500 psi as you will be using it to change out and test BOPS when you change to 7 5/8" rams. As I recall the 4.5" liner will not test since the wiper dart was not launched and there is a pathway to the formation thru the liner shoe. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Wednesday, December 02, 2009 1:47 PM To: Schwartz, Guy L (DOA) Cc: OoogurukDrillingSupervisor; Franks, James Subject: ODSK-42i abandonment procedure Guy, FYI — It occurred to me today that the abandonment procedure sent yesterday for ODSK-42i does not include changing and testing 7-5/8" rams prior to pulling casing. We plan to change/test rams, pull casing, change back to 5" VBRs and test prior to drilling the kick off plug. Let me know if you have any questions. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 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. 12/2/2009 Page 1 of 2 Schwartz, Guy L (DOA) From: Franks, James [James. Franks@pxd.com] Sent: Friday, December 04, 2009 3:04 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Hazzard, Vance; OoogurukDrillingSupervisor Subject: ODSK-42i Cement Bond Log run (PTD 209-120) - 10-403 verbal approval Guy, In the 10-403 request for P&A of the ODSK-42i, we indicated that we would ND the tree and NU the BOP's prior to running the cement bond log. Our rig team has suggested, and we have accepted, a change in the plan to rig up a lubricator on the tree and run the cement bond log prior to ND of the tree. In doing it this way, we give ourselves a bit more time to react to any uncertainty with the bond log. Additionally, we inadvertently left off the part about pulling the 4-1/2" kill string from the well... Original Plan summary: 1. MIRU Nabors 19AC over ODSK-42i. 2. Displace diesel freeze protect fluid to 10.2 ppg brine through the tree and inner annulus. 3. Set BPV and blanking plug. 4. Nipple down tree. 5. Nipple up and test BOP's to 250/4500 psi. 6. Recover BPV and blanking plug. 7. Rig up eline and pick up cement evaluation tool. 8. Log 4-1/2" liner. 9. Pick up a 7-5/8" bridge plug on a line and set it -50' above the liner top (-9350' MD). 10. Pick up a 7-5/8" bridge plug on a line and set it -250' below the surface casing shoe depth (3539' MD). 11. Rig down aline. 12. Pick up a mechanical casing cutter and run in hole on 4" drillpipe. 13. Cut 7-5/8" casing at -3439' MD (150' from the surface casing shoe depth) 14. Pull out of hole with cutter. 15. Spear casing and pull 7-5/8" casing from surface 16. Pick up a 500' tubing stinger and run in hole. 17. Attempt to enter the 7-5/8" casing stub. 18. Spot a balanced cement plug from 3539' MD to 3189' MD. 19. Pull out of hole and lay down cement stinger. 20. Pick up drilling BHA to kick off cement plug and redrill well to new targets (To be covered under a separate permit to drill application) Revised Plan summary 1. MIRU Nabors 19AC over ODSK-42i. WA, YPTIOU Page 2 of 2 2. Displace diesel freeze protect fluid to 10.2 ppg brine through the tree and inner annulus. 3. Rig up eline and pick up cement evaluation tool. 4. Log 4-1/2" liner. 5. Set BPV and blanking plug. 6. Nipple down tree. 7. Nipple up and test BOP's to 250/4500 psi. 8. Recover BPV and blanking plug. 9. Pull 4-1/2" kill string 10. Pick up a 7-5/8" bridge plug on a line and set it -50' above the liner top (-9350' MD). 11. Pick up a 7-5/8" bridge plug on a line and set it -250' below the surface casing shoe depth (3539' MD). 12. Rig down eline. 13. Pick up a mechanical casing cutter and run in hole on 4" drillpipe. 14. Cut 7-5/8" casing at -3439' MD (150' from the surface casing shoe depth) 15. Pull out of hole with cutter. 16. Spear casing and pull 7-5/8" casing from surface 17. Pick up a 500' tubing stinger and run in hole. 18. Attempt to enter the 7-5/8" casing stub. 19. Spot a balanced cement plug from 3539' MD to 3189' MD. 20. Pull out of hole and lay down cement stinger. 21. Pick up drilling BHA to kick off cement plug and redrill well to new targets (To be covered under a separate permit to drill application) Thanks for all your help. james James Franks 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. 12/4/2009 H It s„j r A I I/ � IrI ALASKA OIL AVD GAS [LQATION COMMISSION Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99051 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK-42i Sundry Number: 309-396 Dear Mr. Johnson: SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 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, e Daniel T. Seamount, Jr. S.f Chair j DATED this ! day of December, 2009 Encl. PIONEER NATURAL RESOURCES November 25, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7'" Avenue, Suite #100 Anchorage, AK 99501 RECEIVED NOV 2 b [Uu9 Alaska Oil & Gas Cons. Commissio" Anchorage RE: Application for Operational Shutdown Extension ODSK-42i, PTD 209-120 Surface Location: 2912' FSL, 1154' FEL, Sec 11, T13N, R7E, LIM X = 469844.38, Y = 6031028.13, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for an operational shutdown on the ODSK-42i well. LWD logs indicated less Kuparuk sand than expected, and the sand quality was much lower than expected, so the well will not be an effective injector. After running and cementing a liner, a circulation string and tree will be installed and rig operations with Nabors 19AC will be temporarily shut down. An abandonment plan will be made for ODSN-42i, and plans will be made to sidetrack the well to a more viable location when the rig returns to the well. The abandonment and sidetrack operations will likely occur later in 2009. . Please see the attached form 10-403, and schematic. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Report of Sundry Well Operations 20 AAC 25.070(3) Vern Johnson, Senior Staff Drilling Engineer 907.343.2111 vern.iohnson(a oxd.com If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. 5 erely,� L Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10-403 cc: ODSK-42i Well File STATE OF ALASKA �� I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9D AAC 95 9Rn RECEIVED NOV 2 5 2009 Alaska Oil & Gas Cons Commission 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown Q Perforate❑ Re-enter SuspenclAA&&hil Atter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate[] Other ❑ Specify: Change approved program Q Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic ElService O 209-120 3. Address: 6. API Number: 700 G Street, Suite 600, Anchorage, AK 99051 50-703-20605-00 - 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 0 ODSK-421 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 Oooguruk - Kuparuk Oil Pool - 1 t. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (h): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,625' 6705' 10,618' 1 6699' 1 N/A N/A Length size MD TVD Burst Collapse 110' 16" 158' 158' N/A N/A 3251' 10-3/4' 3289' 2980' M 5210 2470 9529' 7-5/8" 9567' 6014' 6890 4790 1223' 4-1/2" 9398' - 10,621' 5925'- 6702' 8430 7500 Perforation Depth MD (h): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (h): N/A N/A 4-1/2", 12.6# L-80, HYD 521 - 2000' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (h): TSP Liner Top Packer 9398' MD / 5925' TVD 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q - 14. Estimated Date for 15. Well Status after proposed work: CommencingO 11/25/2009 Operations: Oil ❑ Gas ❑ WINJ Q GINJ ❑ WDSPL ❑ Plugged ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: (I/O,St Commission Representative: Tom Maunder GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan, 343-2186 Printed Name Vern Johnson Title Sr. Staff Drilling Engineer Signature Phone 343-2111 Date 11/25/2009 Prepared By: Kathy Cam mor, 343-2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3)7 y-3 y(� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: S",�4� 1403 +U Subsequent Form Required: 10-41044 APPROVED BY / f Approved by: COMMISSIONER THE COMMISSION w _ - - - It Date: Form 10-403 Revised 7/2009 / ORIGINAL Submit in Duplicate I ODSK-42i Kuparuk Injection - Well Status for Ops Shutdown VFHead: 9 5/8", 5K, VetcoGray Tree: 4-112", 5K, Horizontal 16" conductor I I I I I I ` I 1511'MD 1158' MDrkb 4-1/2", 12.6#, L-80, HYD 521 @ - 2000' 10-3/4", 45.5# L-80 BTC, 9.950" ID 3289' MDrkb / 2980' TVDrkb Top of Cement from LWD SBL - Estimated @ 8970' MDrkb / 5707' TVDrkb8970' MDrkb / 5707' MDrkb TSP Liner Top Packer 7-518., 28.7#, L-80, BTC -M, 6.875" ID 9398' MDrkb / 5925' MDrkb 9567' MDrkb / 6014' MDrkb No W;P-r pl"a W iU llles.p 'fa Sac,r+.a` r., Total Depth 110,625' MDrkb 4-'h°, 12.6#, L-80, TSHP/rCll, 3.958" ID /y-1-° 5 10,621' MDrkb / 6702' TVDrkD PIONEER Date: Revision By: Comments ODSK-42i Injector Well Schematic Status @ Ops Shutdown 9/13/2009 James Franks Proposed Completion NATURAL RESOURCES 11124/09 KLC Status at Ops Shutdown Pagel of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 25, 2009 2:27 PM To: 'Johnson, Vern' Cc: Schwartz, Guy L (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) Vern, Unfortunate on the dart not launching and the fluid loss. It would appear that the well is stable, otherwise you would not be able to trip. It is appropriate to have the KW brine in the hole as opposed to the seawater. The brine may be able to be used as the freeze protection fluid depending on the crystalizaiton/freeze point, however as you noted the well will be buttoned up prior to freeze protecting with diesel. I do not have Commissioners available to secure an oral approval. Your proposed plan is not dissimilar to what has been approved previously. I will make sure a copy of this message accompanies the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Wednesday, November 25, 2009 1:37 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) IrTil We should be moving off ODSK-42i late today. We will move to ODSN-37, then ODSN-36 for successive workovers. As discussed this morning, our liner cementing operations did not go as planned. When pumping cement, the drillpipe wiper dart did not leave the cement head, so we were not able get a positive test on the liner (Kuparuk to Nuiqsut). We did get a 10 min, 4500 psi test on the liner top packer (good test) prior to pulling the liner running tool, and the floats held after the cementjob. While clearing the liner top and circulating excess cement, we lost 45 bbl of mud. Due to problems on the liner cement job, we left 10.2 ppg brine above the liner top instead of seawater as previously planned. The plan forward is to run a freeze protect string with a tubing hanger, set a TWC, ND the BOPE, NU and test a tree, then move the rig. On the 10-403, should we check the "verbal approval" box? Let me know if you have any questions or need further information. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 11/25/2009 Page 2 of 2 907-575-9430 cell From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, November 24, 2009 8:32 AM To: Johnson, Vern Cc: Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) Vern, Thanks for the update.... Can you forward the OH logs when you can? Keep us abreast of your next move with the wellbore also. What well is on your schedule next? You mentioned some workovers I believe. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Monday, November 23, 2009 6:18 PM To: Schwartz, Guy L (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Campoamor, Kathy Subject: Temporary Shutdown ODSK-42i (PTD 209 -120) Guy, As discussed earlier today, it is planned to temporarily shut down rig operations on ODSK-42i. It is planned to run and cement a liner through the Kuparuk and Nuiqsut sands as originally planned, however due to poor quality Kuparuk sand, the upper completion will not be run. Instead a diesel circulation string, tubing hanger and tree will be run for freeze protection; then operations will be shut down while a sidetrack plan is generated. The completion fluid will be seawater. A 10-403 sundry application will be sent tomorrow to cover the shutdown. Let me know if have any questions or require further information. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 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. 11/25/2009 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: December 11, 2009 11 FROM TO Shannon Koh Pioneer Natural Resources 700 G Street, Suite 600 Anchorage, AK 99501 Attn: Christine Mahnken 333 W. 7t' Avenue, Suite 100 Anchorage, AK 99501 INI-OKMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report ❑ Agreement X Other -2 CDs, 6 Well Logs DETAIL QTY DESCRIPTION ODSK-42i (API: 50-703-20605-0000) 2 CDs 2CDs LWD Final Processed Data & BAT Bi -Modal Acoustic Processed Data 6 Well Logs 6 Well logs DGR, EWR-Phase 4, ALD, CTN (1:600,1:240) MD logs, TVD logs DGR, EWR-Phase 4, ALD, CTN, BAT Bi -Modal Acoustic 1:600/ 1:240) MD logs, TVD logs We request that alld t 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 907-343-2128 phone ILI Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 04, 2009 2:57 PM To: 'Johnson. Vern' Subject: RE: ODSK-42i log Pagel of 4 Vern, Based on getting full returns during the cement circulation and the fact that the Kuparuk sand is of marginal quality (siderite cement) if the WL conveyed Cement Bond log is not successful in reaching TD it may be omitted. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Friday, December 04, 2009 1:06 PM To: Schwartz, Guy L (DOA) Subject: RE: ODSK-42i log Guy We had full circulation while pumping cement, it was only after setting the liner top packer, picking up and circulating the hole clean that we had any losses. I am getting the Halliburton cementers to send in their reports to confirm in writing. There was no comment in the rig report or on phone discussions of losses until after the packer was set and excess cement was cleared over the liner top. Vern From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Friday, December 04, 2009 11:34 AM To: Johnson, Vern Subject: RE: ODSK-42i log Vern, Do have some documentation that states there was full returns during the cement phase. All I see below is that the well was circulated... no mention of full or partial returns. Guy Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] 12/4/2009 Page 2 of 4 Sent: Monday, November 30, 2009 2:16 PM To: Schwartz, Guy L (DOA) Subject: FW: ODSK-42i log Guy Here is the log for the 6-3/4" hole on ODSK-42i, they indicate that the Kuparuk interval is —6' ND thick at 9600' MD. Density measurements were high (2.85-2.9 g/cc) and there were no issues with mud loss while drilling the Kuparuk interval, indicating that the formation is very tight and cemented. We do not think there is any connectivity with the rest of the Kuparuk reservoir from this penetration, which is why we plan to sidetrack to a more viable location, and it is why we think it might not require cement isolation for abandonment. Also, see the attached ops summary from the liner cement job 11/24/09. Let me know if you have any questions. Vern 12/4/2009 Page 4 of 4 Sent: Monday, November 30, 2009 11:55 AM To: Johnson, Vern Subject: ODSK-42i log Vern: Here's the ODSK-42i log that you asked me to send you. Let me know if you have any questions or need something else. Paul Paul Daggett Pioneer Natural Resources 700 G Street, Suite 600 Anchorage, AK 99501 Ph: 907-343-2134 Mobile: 907-575-8627 Fax: 907-343-2190 E-mail:paul.daggett@pxd.com 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. 12/4/2009 Page 1 of 2 Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 25, 2009 2:27 PM To: Johnson, Vern Cc: Schwartz, Guy L (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) Vern, Unfortunate on the dart not launching and the fluid loss. It would appear that the well is stable, otherwise you would not be able to trip. It is appropriate to have the KW brine in the hole as opposed to the seawater. The brine may be able to be used as the freeze protection fluid depending on the crystalizaiton/freeze point, however as you noted the well will be buttoned up prior to freeze protecting with diesel. I do not have Commissioners available to secure an oral approval. Your proposed plan is not dissimilar to what has been approved previously. I will make sure a copy of this message accompanies the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Wednesday, November 25, 2009 1:37 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) Tom We should be moving off ODSK-42i late today. We will move to ODSN-37, then ODSN-36 for successive workovers. As discussed this morning, our liner cementing operations did not go as planned. When pumping cement, the drillpipe wiper dart did not leave the cement head, so we were not able get a positive test on the liner (Kuparuk to Nuiqsut). We did get a 10 min, 4500 psi test on the liner top packer (good test) prior to pulling the liner running tool, and the floats held after the cement job. While clearing the liner top and circulating excess cement, we lost 45 bbl of mud. Due to problems on the liner cement job, we left 10.2 ppg brine above the liner top instead of seawater as previously planned. The plan forward is to run a freeze protect string with a tubing hanger, set a TWC, ND the BOPE, NU and test a tree, then move the rig. On the 10-403, should we check the "verbal approval" box? Let me know if you have any questions or need further information. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 12/1/2009 Page 2 of 2 907-575-9430 cell From: Schwartz, Guy L (DOA)[mailto:guy.schwartz@alaska.gov] Sent: Tuesday, November 24, 2009 8:32 AM To: Johnson, Vern Cc: Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Temporary Shutdown ODSK-42i (PTD 209 -120) Vern, Thanks for the update.... Can you forward the OH logs when you can? Keep us abreast of your next move with the wellbore also. What well is on your schedule next? You mentioned some workovers I believe. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Monday, November 23, 2009 6:18 PM To: Schwartz, Guy L (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Campoamor, Kathy Subject: Temporary Shutdown ODSK-42i (PTD 209 -120) Guy, As discussed earlier today, it is planned to temporarily shutdown rig operations on ODSK-42i. Itis planned to run and cement a liner through the Kuparuk and Nuiqsut sands as originally planned, however due to poor quality Kuparuk sand, the upper completion will not be run. Instead a diesel circulation string, tubing hanger and tree will be run for freeze protection; then operations will be shut down while a sidetrack plan is generated. The completion fluid will be seawater. A 10-403 sundry application will be sent tomorrow to cover the shutdown. Let me know if have any questions or require further information. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 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. 12/1/2009 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 20, 2009 8:13 AM To: 'Johnson, Vern' Subject: RE: ODSK-42i (PTD 209-120) Vern, I agree with the below .... Let me know how the Kuparuk penetration mud losses go. I will have my cell phone with me this weekend ... call me anytime. Guy Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Thursday, November 19, 2009 5:08 PM To: Schwartz, Guy L (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Vaughan, Alex Subject: ODSK-421 (PTD 209-120) Guy, Per our discussion today, we will plan to perform an FIT after drilling 10' of new hole. We expect that this will provide a better measurement of the 7-5/8" intermediate casing shoe strength than we would have by drilling further and risk penetrating the under pressured Kuparuk reservoir. Also, we will plan to drill the Kuparuk sands with 9.8 ppg W BM and evaluate losses at that point. A decision will be made after drilling the Kuparuk with respect to mud weight for the Nuiqsut. Let me know if you have any questions or concerns. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 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. 11/20/2009 Schwartz, Guy L (DOA) From: Johnson, Vern [Vem.Johnson@pxd.com] Sent: Friday, October 23, 2009 1:07 PM To: Schwartz, Guy L (DOA) Cc: Franks, James Subject: RE: ODSN 39 Wireline operations question Page 1 of 2 FTID 2b'�?-!Z0 Guy - as discussed this AM, I checked, and we do have a valve on the tree that we can close in case we need to cut the line and shut in. Also, at a minimum, we will have aline wiper made up to keep diesel off the wireline as we pull out, and an outlet valve lined up to take diesel returns while we run in. Vern From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, October 21, 2009 7:46 AM To: Johnson, Vern Subject: RE: ODSN 39 Wireline operations question Vern, I don't see the need for full lubricator/grease head on the E -line portion. I would still at least have a packoff and a master -valve on the tree just in case. This is similar to the old KRU days of running the CBT/ GRYO before the completion rig shows up. I would not go in open ended though. Are you using Vector Magnetic's as a vendor? Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Wednesday, October 21, 2009 7:29 AM To: Schwartz, Guy L (DOA) Subject: ODSN 39 Wireline operations question Guy, Due to tight tolerances while directional drilling the surface hole on ODSK-42, we are preparing to use magnetic ranging services offered by Sperry Drilling Services. Magnetic ranging involves using an energized magnetic coil run on electric line in an adjacent well to reduce positional uncertainty while drilling. We are preparing to use ODSN-39 as the reference well while drilling surface hole on ODS5-42. ODSN-39 has surface casing set and tested, cemented to surface, with a tree and diesel freeze protect string in place. The float equipment has not been drilled, and the casing string is not exposed to any reservoir. Do we need to consider using wireline well control equipment (or variance) per 20 AAC 25.287? Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 10/23/2009 B1w.Ne: O00000wu kOde guNk 010 I MAE L4RAL RESOURCES ALASKA OIL AND GAS CONSERVATION COMIISSION Mr. James Franks Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G. Street, Suite 600 Anchorage, AK 99501 SEAN PARNELL, GOVERNOR 333W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Oooguruk, Kuparuk Oil Pool, ODSK-42i Pioneer Natural Resources Alaska, Inc. Permit No: 209-120 Surface Location: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 2198' FSL, 1989' FEL, Sec. 13, T13N, R7E, UM Dear Mr. Franks: 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, f/�//� Cath P. Foerster Commissioner DATED this A day of October, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED OCT U 7 &U9 Alaska Oil & sea cont C®161rr1i�llp la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ tc. Specify if well is proposed for: -•v. _ Drill Q . Redrilf ❑ Stratigraphic Test ❑ Service Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ 1 Re-entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 , ODSK421 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 10,673' ' TVD: 6492' ' Oooguruk - Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7, Property Designation: Surface: 2912' FSL, 1154' FEL, Sec. 11, T13N, R7E, UM ' ADL 355036 ` Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2727' FSL, 2413' FEL, Sec. 13, T13N, R7E, UM 417497 11/6/2009 ' Total Depth: 9. Acres in Property: 14. Distance to Nearest 2198' FSL, 1989' FEL, Sec. 13, T13N, R7E, UM 5760 / Property:_ 1989'-" 2YDD 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: ' / eet 15. Distance Nearest Well Open Surface: x-469844.38 - y-6031028.13 Zone -ASP 4- C1C� KB Elevation above GU WL Z,q f Y,'ft to Same Pool: 3625' away from b, - o ODSK-41 / 16. Deviated wells: WA Kickoff depth: 2L� fee,d.j 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle:/.(oma degrees Downhole: 3246• Surface: 2538 18. Casing Program: Specifications 0.9 o Top - Setting Depth - Bottom Cement Quantity, cJ. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven 13-1/2" 10-3/4" 45.5# L-80 BTC 3332' Surface Surface 3375' 3000' 459 sx PF'L'; 237 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC -M 9804' Surface Surface 9847' 6082' 161 sx Class 'G' 6-3/4" 4.1/2" 12.6# L-80 Hyd 521 976' 9697' 6010' 10,673' 6492' 210 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 (fl): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conduclor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat Q Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343-2186 Prepared 6u: Kathy Campoamor, 343-2183 Printed Name James Franks Title Sr. Staff Drilling Engineer Signature Phone 343-2179 Date 10/7/2009 Commission Use Only Permit to Drill (� �L:/� API Number: / Permit Apr al See cover letter for other Number: 50- Date: requirements. Conditions of approval : If box is checked, well mXnot be used to explore for, test, or produce coalbed Aethane, gas hydrates, or gas contained in shales: Other: AAI T E %le - / /!' J � / _- (� rQne.4Vr "---ii"' Tal v�L Samples req'd: Yes ❑ No [�( Mud log req'd: Yes ❑ No HsS Yes ❑ NoDirectional Yes measures: svy req'd: [�No El *1 :iil'fi►>h. G dpGf'�ddOtiTT ;kL 4c_ca U #�'�✓�� PSi. �hrr,r4,�ar (G,j"f'-Cif«.•. WiA 4yo 3.? C)iverf,e_r Wa_Lved Zd AAC-15.635 APPROVED BY THE COMMISSION DATE: 0- - I , COMMISSIONER 0, - /S25 it-p'cfi Form 10401 (Revised 1/2009) This permit Is valid for 24 monlh�o t1 h f �lE b ria(20 AAC 25.005i�g)). /Z. O � submit in Dupkarea PIONEER RECEIVED OCT 0 7 2009 NATURAL RESOURCES __ _�,.A,��A�I S_GOtIS.Comml�xion Pioneer Natural ResourcesAwaxo@. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277-2700 Fax: (907) 343-2190 October 7. 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK-42i Surface Location: 2912' FSL, 1154' FEL, Sec. 11, TI 3N, R7E, UM X = 469844.38, Y = 6031028.13, 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-Kuparuk 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 3375' MD / 3000' TVDrkb, where surface casing will be set. A 9-7/8" directional wellbore will be drilled to 9847' MD / 6082'TVDrkb. A 6-3/4" production hole section will be drilled for a final depth of approximately 10673' MD / 6492' TVDrkb. The proposed casing program will utilize 10-3/4" surface casing, 7-5/8" intermediate casing and a 4-1/2" production liner. The completion will utilize 3-1/2" tubing and the well will be perforated across the Oooguruk-Kuparuk for injection. PNRA plans to implement Managed Pressure Drilling technology (MPD) while drilling the production hole of ODSN-42i. PNRA does not intend on drilling with a mud weight lower than the pore pressure of the exposed formations. PNRA plans to use this technique while drilling the production interval as outlined below. From the Surface Shoe to below the Base of the Torok Sands o Use -9.2 to 10 ppg fluid while using MPD to control pressure from the surface to -10.5 ppg EMW at the bottom of the hole. • Open formations: 0 Torok Sands, -8.7 ppg Pore Pressure Alaska Oil & Gas Conservat Commission September 13, 2009 Page 2 of 3 • From the base of the Torok Sands to Production Hole TD o Use -10.0 to 11.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure • Nuigsut Sands, -9.7 ppg Pore Pressure In the future, PNRA may provide information requesting the permitting for annular disposal of drilling wastes on this well. ,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 Alaska Oil & Gas ConservaL_. i Commission September 13, 2009 Page 3 of 3 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. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) 2) Geologic Data and Logs (20 AAC 25.071) Vern Johnson, Senior Staff Drilling Engineer 907.343.2111 vern.iohnson(a)pxd.com Paul Daggett, Operations Geologist 907.343.2134 paul.daooett(a-)Pxd.com The anticipated spud date for this well is November 6, 2009, but we are sending in the permit request early to ensure we have a fallback in place should our current schedule change. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincerely, James Franks Senior Staff Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSK-42i Well File Oooguruk Well Plan Summary: Permit to Drill ODSK-421— Kuparuk Injection Well Surface Location: 2912' FSL, 1154' FEL, Sec 11, T13N, R7E, UM ASP 4 NAD27projection X = 469844.38 ' 1 Y = 6031028.13 Target: Ooo uruk-Ku aruk 2727' FSL, 2413' FEL, Sec 13, T13N, R7E, Umiat Objective: Ku aruk Well Type (exp, dev, etc): Development X = 473806.00 1 Y = 6025600.00 6082' TVDrkb Bottom Hole Location: 2198' FSL, 1989' FEL, Sec 13, T13N, R7E, Umiat X = 474262.46 1 Y = 6025019.65 6492' TVDrkb AFE Number: TBA Est. Start Date: November 6, 2009 Rig: Nabors 19AC Operating days: 32 days to Drill and Com late TD: 10673' MD / 6492 TVDrkb Objective: Ku aruk Well Type (exp, dev, etc): Development Well Design conventional, slimhole, etc): Slim hole — Injector— w 10a Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Well Control: 13-1/2" Surface Section: • Maximum anticipated BHP: 1316 psi @ 2943'TVDss (Based on seawater gradient of 0.4472 psi/ft) • Maximum surface pressure: 992 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 9-7/8" Intermediate Casing Hole Section: • Maximum anticipated BHP: 3070 psi @. 6025' TVDss (Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) ' • Maximum surface pressure: 2407 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-3/4" Production Liner Hole Section: • Maximum anticipated BHP: 3246 psi @ 6435' TVDss (Based on 9.7 ppg Oooguruk-Nuigsut pore pressure) ' • Maximum surface pressure: 2538 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: Planned BOP test pressure: Planned completion fluid: Pioneer Natural Resources ODSK-42i Permit To Drill 4500 psi @ surface 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. 10.2 ppg Brine /6.8 ppg Diesel Last Revised: October 7, 2009 Page 1 of 9 z Diverter (see attached schematic) - Note: Requesting Diverter Exemption on a Well by Well Basis): 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 I Depth Test Type Minimum EMW 10-3/4" Surface Shoe I Rathole + 20' to 50' from shoe LOT 12.5 ppg 7-5/8" Intermediate Shoe I Rathole + 20' from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 13-1/2" hole Spud Mud Interval Densit (pp Viscosity (secs) YP PV 10 secel 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 Densit (pp Viscosit (secs) YP PV MBT API FL Initial to Base Torok 9.2-10.0 (-10.5 ppg via MPD 40-60 15-25 15-20 < 12 6-8 From Base Torok to TD 10.5 (-12.5 ppg via MPD) 40-60 15-25 20-30 < 15 3-5(8-10 HTHP Production Hole Mud Properties: 6-3/4" hole LSND Interval Density (pp)Viscosit (secs YP PV MBT API FL Initial to TD 10.5 (-12.5 ppg via MPD 40 - 60 15 - 25 20-30 < 15 3-5(8-10 HTHP Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-42i Permit To Drill Page 2 of 9 Hydraulics: Surface Hole: 13-1/2" Hole Interval Pump GPM Drill Pipe AV (fpm) Pump PSI ECD ppg- emw Motor Jet ("/32) Nozzles TFA (in Z) Surf to BPRF 750 5" 19.5# 115 2100 9.6 N/A 16,16,16,12 .7 BPRF to TD 750 5" 19.5# 115 1 2400 9.8 1 N/A 16,16,16,12 .7 Intermediate Hole: 9-7/8" Hole Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (int) Intial to TD GPM 1 4" 15.7# (fpm) PSI emw ("/32 5x14 .752 Surf Shoe to 650 5" 19.5# 209 2500 9.8 N/A 6x16 1.18 Base of Torok Brookian 2B 6039 4270 Top Torok Sand Base of Torok 650 5" 19.5# 209 3600 11.3 N/A 6x16 1.18 to TD Top HRZ 9227 5787 Base HRZ Production Hole: 6-3/4" Hole Interval Pump GPM Drill Pipe AV (fpm) Pump PSI ECD ppg- emw Motor Jet ("/32 Nozzles TFA (in) Intial to TD 1 650 1 4" 15.7# 1 230 4000 11.3 Blanked 5x14 .752 Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. (psi) EMW (Ppg) Comments Base of Permafrost 1677 1666 Top West Sak 2337 2278 1023 8.65 Base of fluvial sands Tuffaceous Shales 3246 2931 Surface Shoe 3376 3000 Brookian 2B 6039 4270 Top Torok Sand 7819 5117 2275 8.6 Base Torok Sand 8363 5376 Top HRZ 9227 5787 Base HRZ 9494 5914 Kalubik Marker 9710 6017 Intermediate Shoe 9847 6082 Top Kuparuk C 9857 6087 3090 9.8 Could be lower due to depletion — hydrocarbon Base Ku aruk (LCU) 9891 6103 BCU 10210 6255 Top Nuiqsut 10366 6329 3201 9.7 Hydrocarbon Base Nui sut 10584 6443 Nechelik 10605 6443 TD 10673 6492 Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-42i Permit To Drill Page 3 of 9 Loaaina Proaram: 13-1/2" Section: Casing / Tubing Drilling: Mud logging Conn. Dir/GR Open Hole: N/A Cased Hole: N/A 9-7/8" Section: Casing / Tubing Drilling: Mud logging Conn. Dir/GR/ Res / Dens / Neut / PWD Open Hole: N/A Cased Hole: BAT Sonic ✓ 6.3/4" Section: Casing / Tubing Drilling: Mud logging Conn. Dir / GR / Res / Dens / Neut / PW D Open Hole: N/A Cased Hole: Cement Bond Lo Casino Proaram- Hole Size Casing / Tubing Weight Grade Conn. Casing Length Csg/Tbg Top I MDrkb/TVDrkb Hole Btm MDrkb/TVDrkb 24" 16" 109# H-40 Welded 115' Surface 158'/ 158' 13.1/2" 10-3/4" 45.5# L-80 BTC 3332' Surface 3375'/ 3000' 9-7/8" 7-5/8" 29.7# L-80 BTC -M 9804' Surface 9847'/6082' 6-3/4" 4-1/2" 12.6# L-80 H dril 521 976' 9697' / 6010' 10673'/ 6492' Tubing 3-1/2" 9.3# L-80 TSHP/TCII 9804' Surface 9847' / 6082' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Yield (psi) Collapse (psi) Tensile Strength Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductorcasin 10-3/4" 45.5# L-80 8.835" 8.75" BTC 5210 2470 1063M 1063M 7-5/8" 29.7# L-80 6.875" 6.75 BTC -M 6890 4790 683 M 683 M 4-1/2" 1 12.6# L-80 3.958" 1 3.833" TSHP/TCII 1 8430 7500 289 M 289 M Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-42i Permit To Drill Page 4 of 9 Cement Calculations: 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, Lead 339 bbls / 459 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf/sk, 20.0 gps water req. Tail 150.3 bbls / 237 sx of 15.9 ppg Premium "G" + adds. 1.19 cf/sk, F Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar maybe run in the casing string and a staged cement job will be performed. 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. 60% excess, plus 85' shoe track 60% top of the Kuparuk water sx I Temo I BHST - 135°Fat 6068' TVDrkb, -110° F BHCT I UUUUIIUII L11JWF - 511191= SWUW -150' MD above the top of intermediate 44 bbls 1210 sx This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Iniection: 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, ODSDWI-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, 0DSDWI-44. Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-421 Permit To Drill Page 5 of 9 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Rig 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, ODSDWI-44, has been drilled and commissioned for disposal. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 13-1/2" Directional Drilling, MWD/LWD assembly. Drill surface hole to the casing point at -3,375'/ 3,000'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 - Notify AOGCC 48 hours in advance of test. 7. Close blind rams and test 10-3/4" casing to 3500 psi for 30 minutes -- chart and send to Operations Drilling Engineer. 8. MU 9-7/8" directional drilling, MWD/LWD. RIH and cleanout casing to landing collar. Displace well over to intermediate hole drilling fluid. 9. Drill through surface shoe + 20' of new hole and perform LOT to 12.5 ppg. 10. Drill 9-7/8" intermediate hole to casing point at -9,847' MD/ 6,082' TVDrkb. -10' TVD above the top of Kuparuk. 11. Change one set of pipe rams to 7-5/8" and test BOPE as required. 12. Run and cement the 7-5/8", 29.7# intermediate casing. 13. Bump the plug, release pressure and ensure floats are holding. 14. Change pipe rams to 4-1/2" and Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 15. MU 6-3/4" MWD/LWD motor drilling assembly with BAT Sonic (for cement bond log). RIH and cleanout to landing collar. 16. Pressure test the 7-5/8" casing to 4500 psi. 17. Drill through intermediate shoe + 20' of new hole and perform FIT to 12.5 ppg. 18. Drill 6-3/4" production liner to TD at -10,673' MD/ 6,492' TVDrkb. Note: evalu are currently no plans to produce the is for Note: Due to high potential of losses through the Kuparuk production hole drilling fluid is subject to change. AOGCC will be notified in this event. 19. RIH and cement the 4-1/2" production liner from 150' inside the intermediate casing to TD. 20. Displace production drilling fluid with 11.5 ppg mud 21. Pump production liner cement job. Displace with 9.8+ ppg brine. L i 22. Set 4-1/2" Liner hanger packer, unsling & circulate out excess cement. J� 23. Change pipe rams to 3-1/2" and Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 24. RIH with 3 1h" tubing. Locate liner top space out & land tubing hanger. Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-42i Permit To Drill Page 6 of 9 c�7 25. Test hanger seals to 5000 psi. 26. Install TWC. 27. ND BOPE, NU tree and test to 5,000 psi. 28. Pull TWC. 29. Circulate corrosion inhibited brine around the packer. 30. Drop ball and rod, set and test packer. 31. Pressure test 3-1/2" tubing to 4,500 psi. Pressure test 3 -1/2" to 7-5/8" annulus to 4,500 psi 32. Reverse circulate 2000' of freeze protection fluid down 3.1/2" tubing annulus through gas lift mandrel shear out valve. 33. RDMO to perform remaining completion. Post -Rig Activity: Complete 1. RU Slickline/Wireline Unit 2. Pull the ball and rod. 3. Pull the shear out valve from the upper GLM. 4. RIH with Slickline and set gas lift valve in upper GLM 5. Pull the RHC -m plug with Slickline 6. Perform a wireline cement bond log across production liner 7. RIH w/ wireline 6 spf, 6W phasing, perforation guns & fire across Kuparuk formation -34' MD. B. RD Slickline/Wireline Unit. Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-421 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 It 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: October 7, 2009 ODSK-421 Permit To Drill Page 8 of 9 ODSN-42i 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 for kick detection and lost circulation. 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. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • 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 fault seen in and below the Torok Sands. Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the D0132C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly 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 and ODSN-45 - close attention while drilling this interval is advised. Kick Tolerance/integrity Testing Kick Tolerance / Integrity Testing Summ ry Table Casing set/ Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press Intermediate 7912,5 EMW w/MPD ppg 3068 12.5 ppg (LOT) Production Infinite 11 ppg (12.5 EMW w/MPD) 3275 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 I Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. / Faults • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources Last Revised: October 7, 2009 ODSK-42i Permit To Drill Page 9 of 9 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-42i - Slot ODS -42 ODSK-42i KupG Plan: ODSK-42i KupG wp10.a Standard Proposal Report 24 September, 2009 HALLIBURTON Sperry Drilling Services PIONEE NATURAL RESOURCES NALUBURTON sae�er oea0.ee Project: Ooogurok Development Site: Ooogunik Drill Site Well: 0DSK-42i Wellbore: ODSK-42i KupG Plan: ODSK42i KupG wp10.a i DDI = 5.96 H WELL DETAILS ODSK42i Groaad Level: 13.5 +W -S +E/ -W Northing Luting Latin & La giw& SO 0.0 0.0 W31028.13 469841.38 7V29'45.027N ISV14'47.6NW ODS 42 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name WD +W -S +E/ -W Northing Easkng Shape KupG v8 T1 6067.2 -5412.6 3984.0 6025600.00 473806 00 Circle (Radius: 200.0) SURVEY PROGRAM Date: 2009-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 42.7 1400.0 ODSK-42i KupGwpl O.a SR -Gym -SS 1400.0 10672.9 ODSK42i KupGwplO.a MWD+IFR2+MS+sag AStart Dir 1.00/100' 100.0.00' MD, 500.0.00' TVD End Dir 300.00' MD, 300.00' TVD - - - - - - - Start Dir 1.00/100' 550.00' MD, 550.00' TVD - - - - - - -Start Dir 1.50/100'1050.09 MD, 1049.40' TVD End Dir 1659.80' MD, 1650.00' TVD Base of Permafrost \ Start Dir 3.0/100' 1762.90' MD, 1750.00' TVD Top West Sak Tuffaceous Shales End Dir 3375.80' MD, 3000.00' TVD e ro - : _ _ _ Start Dir 1.501100'3395.8V MD, 3010.00' ND II End Dir 3562.20' MD, 3091.40' TVD 103/4" Brook2B \ N Top Torok sand- _ _ \ REFERENCE IN'F'ORMA3'ION Coamout(NX)Ret Wall OOSK41i-SbI ODS42,T-NOM reraw ") Retre. :42,7 135'@S6.M(Nabors 19 AC) Meuum4 Depth lea . ..: 421"135' @ %.M (NaWrs19AC) CwcWetlon Meth A: hft a=Cun.t,e C'OMPANYDETAIS: WeBPlavamg-Pioneer-Ooog r], CalcdadeaMethod Mm®mt Mvaave Ems, System IscIm Saar Method Dsv.CyIhder N.dh Ener 9uface: EL tkd Conic W.ming Method: (fides Based Start Dir 3.0/100' 10380.40' MD, 6336.20' TVD Base Torok Sand - - - - - _ - _ End Dir 10572.90' MD, 6436.20' TVD Top HRL_ - - -- , ,' , � Total Depth Base HRZ________ 7518" at 10672.90' MD, 6492.40' TVD _- Kalubik Marker- _ Top KuparukC,, ,BCU r-----41/2" Base Kuparuk C (LCU) ` Top Nuiqsut ; Nechelik KupG v8 T7 Base Nuigsut ODSK-42i KupG wp10.a 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 143.41° (1500 Win) CASING DETAILS TVDPath TVDssPath TVD MD Name SECTION DETAILS 3000.0 3375.8 10 3/4" 10.750 6082.2 9846.6 7 5/8" Sec MD Inc Ad TVD +N/S +FJ -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 000 0.00 0.0 2 100.0 0.00 0.00 100.0 0.0 0.0 0.00 0.00 0.0 3 200.0 1.00 220.00 200.0 -0.7 -0.6 1.00 220.00 0.2 4 300.0 0.00 0.00 300.0 -1.3 .1.1 1.00 180.00 0.4 5 550.0 0.00 0.00 550.0 .1.3 .1.1 0.00 0.00 0.4 6 1050.0 5.00 170.00 1049.4 .22.8 2.7 1.00 170.00 19.9 7 1659.8 14.15 170.00 1650.0 -122.6 20.3 1.50 0.00 110.5 8 1762.9 14.15 170.00 1750.0 -147.4 24.6 0.00 Ool) 133.0 9 2304.2 30.00 160.00 2250.2 341.0 82.8 3.00 -18.09 323.1 10 3375.8 59.90 143.39 3000.0 .993.2 444.8 3.00 -21.43 1062.6 11 3395.8 59.90 143.39 3010.0 -1007.1 455.1 0.00 0.00 1079.9 12 3662.2 61.58 141.28 3091.4 -1122.0 $43.9 1.50 48.11 1225.1 9815.1 61.58 141.28 6067.2 -5412.6 3984.0 0.00 0.00 6720.7 KupG v8 T1 i3 4 10380A 61.58 141.28 6336.2 -5800.4 4295.0 0.00 0.00 7217.4 15 10572.9 55.81 141.28 6436.2 5928.7 4397.8 3.00 180.00 7381.8 16 10672.9 55.81 141.28 6492.4 -5993.2 4449.6 0.00 0.00 7464.4 Start Dir 3.0/100' 10380.40' MD, 6336.20' TVD Base Torok Sand - - - - - _ - _ End Dir 10572.90' MD, 6436.20' TVD Top HRL_ - - -- , ,' , � Total Depth Base HRZ________ 7518" at 10672.90' MD, 6492.40' TVD _- Kalubik Marker- _ Top KuparukC,, ,BCU r-----41/2" Base Kuparuk C (LCU) ` Top Nuiqsut ; Nechelik KupG v8 T7 Base Nuigsut ODSK-42i KupG wp10.a 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 143.41° (1500 Win) CASING DETAILS TVDPath TVDssPath TVD MD Name Size 3000.0 3375.8 10 3/4" 10.750 6082.2 9846.6 7 5/8" 7.625 6492.4 10672.9 41/2" 4.500 Start Dir 3.0/100' 10380.40' MD, 6336.20' TVD Base Torok Sand - - - - - _ - _ End Dir 10572.90' MD, 6436.20' TVD Top HRL_ - - -- , ,' , � Total Depth Base HRZ________ 7518" at 10672.90' MD, 6492.40' TVD _- Kalubik Marker- _ Top KuparukC,, ,BCU r-----41/2" Base Kuparuk C (LCU) ` Top Nuiqsut ; Nechelik KupG v8 T7 Base Nuigsut ODSK-42i KupG wp10.a 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 143.41° (1500 Win) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 1666.2 1610.0 1676.5 Base W Permafrost 2278.2 2222.0 2336.7 Top West Sak 2931.2 28750 3245.6 Tuffaceous Shales 42]0.2 4214.0 6039.2 Brook 2B 5117.2 5061.0 7818.9 Top Tarok sand 5376.2 5320.0 8363.2 Base Torok Sand 5787.2 Mile 9226.8 Top HRZ 5914.2 SSW 0 9493.6 Base HRZ 6017.2 5961.0 9710.1 Kalubik Marker 6087 .2 6031.0 9857.1 Top Kuparul,C 6103.2 W,17.0 9890.8 Base Kuparuk C (LCU) 6255.2 6199.0 10210.2 BCU 6329.2 6273.0 10365.6 Top Nuigsut 6443.2 6387.0 10585.3 Base Nuigsut 6454.2 6398.0 10604.9 Nechelik Start Dir 3.0/100' 10380.40' MD, 6336.20' TVD Base Torok Sand - - - - - _ - _ End Dir 10572.90' MD, 6436.20' TVD Top HRL_ - - -- , ,' , � Total Depth Base HRZ________ 7518" at 10672.90' MD, 6492.40' TVD _- Kalubik Marker- _ Top KuparukC,, ,BCU r-----41/2" Base Kuparuk C (LCU) ` Top Nuiqsut ; Nechelik KupG v8 T7 Base Nuigsut ODSK-42i KupG wp10.a 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 143.41° (1500 Win) PIONEER NATURAL F;FSOUE NALLIBURTON BPemy O�IIIIng Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODSK-42i Wellbore: ODSK-42i KupG Plan: ODSK-42i KupG wp10.a WELLDETAILS: ODSK42i Ground Level: 13.5 +N/ -S +E -W Northing Essar, Lotmork Lunghude slot 0.0 0.0 6031028.13 469841.38 70°29`45.027N 15W 14' 47.689 W ODS42 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name WD -NIS +EI -W Northing Easting Shape KupG v8 T1 6067.2 -5412.6 3984.0 6025600.00 473806.00 Circle (Radius: 200.0) k w mi pS0 0 REFERENCE INFORMATION C-rdfie.,(N/C) 8efereeee: Wel ODSK421-act W842 True Noun VeNrtl (TVD) Rehrto<e: 42 7+ 13.5' @ 56.2tt (Nabors 19AC) M. -d Depth Reh¢oee: 42 7.13.5' @ 56.20 (Nabors 19AC) Cwcwetlna Method Mlolmum Corverun CONIPANYDETARS: Weg PUvvmg-Pioneer-(louglwk Calculation Method: Mwmnm Ctvvwue Enursystenc ISCWSA scan Method: Trsv.Cyl'mder North Error Surface: Elliptical Conic Warning Method Rules Based SURVEY PROGRAM Date: 2009-09-23700:00:00 Validated: Yes Version: Depth From Depth To Suney/Plan Tool 42.7 1400.0 ODSK42i KupGwplO.a SR-Gyro-SS1400.0 10672.9 ODSK42i KupGwpl0e MWD+IFR2+MS+sag Surt Dir 1.07/100 100.0.00' MD, 500.0.0 TVD i 600 End Du 300.00 MD, 300.00' TVD SECTION DETAILS DDI=5.96 6082.2 9846.6 ;� -' Start Da I.W 100'550.W MD. 550.0' TVD 0 ________ Start Dvl.5WIW1050.WMD,1049A0'TVD Inc ' ---_-_-_----- End Du 1659.80 MD, 1650.00' TVD WD +N/ -S 1540 -600 Sue, Dv 3.01I0W 1762.90' MD, 1750.00' TVD VSec Target End Dir 3375.80 MD, 3000.W TVD -1200 t -_-_ Sart Dr 1.5WIW 3395.80 MD, 3010.00' TVD 0.00 103/4" sc-'- 0.0 ��0 End Dir 3562.20 MD, 3091.40 TVD k w mi pS0 0 REFERENCE INFORMATION C-rdfie.,(N/C) 8efereeee: Wel ODSK421-act W842 True Noun VeNrtl (TVD) Rehrto<e: 42 7+ 13.5' @ 56.2tt (Nabors 19AC) M. -d Depth Reh¢oee: 42 7.13.5' @ 56.20 (Nabors 19AC) Cwcwetlna Method Mlolmum Corverun CONIPANYDETARS: Weg PUvvmg-Pioneer-(louglwk Calculation Method: Mwmnm Ctvvwue Enursystenc ISCWSA scan Method: Trsv.Cyl'mder North Error Surface: Elliptical Conic Warning Method Rules Based SURVEY PROGRAM Date: 2009-09-23700:00:00 Validated: Yes Version: Depth From Depth To Suney/Plan Tool 42.7 1400.0 ODSK42i KupGwplO.a SR-Gyro-SS1400.0 10672.9 ODSK42i KupGwpl0e MWD+IFR2+MS+sag yS� DD PNy 95 San Dir 3.0/IW 10380.40' MD, 6336.20 TVD End Da 10572.90' MD, 6436.20 TVD KupG 8 X518" .Tool Depth at 10672.90' MD, 6492.40' TVD 412' ODSK42i KupG "10n West( -)/East(+) (1500 Nin) CASING DETAILS WD MD Name Six --. SECTION DETAILS 103/4" 10.75, 6082.2 9846.6 7 S1W 7.625 Sec MD Inc Aa WD +N/ -S +EI -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 100.0 0.90 0.00 100.0 0.0 0.0 0.00 0.00 0.0 3 200.0 1.00 220.00 200.0 -0.7 -0.6 1.00 220.00 0.2 4 300.0 0.00 Oki) 300.0 -1.3 -1.1 1.00 180.00 0.4 5 550.0 0.00 0.00 550.0 -1.3 4A 0.00 0.00 0.4 61050.0 5.00 170.00 1049.4 -22Z 2.7 1.00 170.00 19.9 7 1659.814.15 170.00 1650.0 -122.6 20.3 1.50 0.00 110.5 8 1762.9 14.15 170.00 1750.0 -147.4 24.6 0.00 0.00 133.0 9 2304.2 30.00 160.00 2250.2 -341.0 82.8 3.00 .18.09 323.1 10 3375.8 59.90 143.39 3000.0 .993.2 444.8 3.00 .21.43 1062.6 11 3395.8 59.90 143.39 3010.0 -1007.1 455.1 0.00 0.00 1079.9 12 3562.2 61.58 141.28 3091.4 -1122.0 543.9 1.50 48.11 1225.1 13 9815.1 61.58 141.28 6067.2 5412.6 3984.0 0.00 0.00 6720.7 KupG v8 T1 14 10380.4 61.58 141.28 6336.2 -5800.4 4295.0 0.00 0.00 7217.4 15 10572.9 55.81 141.28 6436.2 -5928.7 4397.8 3.00 180.00 7381.8 16 10672.9 55.81 141.28 6492.4 -5993.2 4449.6 0.00 0.00 7464.4 yS� DD PNy 95 San Dir 3.0/IW 10380.40' MD, 6336.20 TVD End Da 10572.90' MD, 6436.20 TVD KupG 8 X518" .Tool Depth at 10672.90' MD, 6492.40' TVD 412' ODSK42i KupG "10n West( -)/East(+) (1500 Nin) CASING DETAILS WD MD Name Six --. 3000.0 3375.8 103/4" 10.75, 6082.2 9846.6 7 S1W 7.625 6492.4 10672.9 410 4.500 HALLIBURTON Database: EDM Alaska Company: Well Planning - Pioneer- Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODSK-42i Wellbore: ODSK-42i KupG Design: ODSK-42i KupG wp10.a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Pioneer Natural Resources Standard Proposal Report Well ODSK-421 - Slot ODS -42 42.7 + 13.5'@ 56.2ft (Nabors 19AC) 42.7 + 13.V@ 56.2ft (Nabors 19AC) True Minimum Curvature 2roject Oooguruk Development Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Dap Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Model Name 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 ? (nT) Well ODSK-42i - Slot ODS -42 3/6/2007 Well Position +N/ -S 0.0 ft Northing: 6,031,028.13 ft Latitude: 70°29'45.027N +E/ -W 0.0 ft Easting: 469,844.38 It Longitude: 150°14'47.689W Position Uncertainty 0.0 ft Wellhead Elevation: It Ground Level: 13.5 ft Wellbore ODSK-42i KupG Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 3/6/2007 23.24 80.81 57,643 Design ODSK-42i KupG wp10.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (ft) (ft) (ft) (?) 42.7 0.0 0.0 143.41 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?It 00ft) (?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 0.00 0.00 0.00 0.00 200.0 1.00 220.00 200.0 143.8 -0.7 -0.6 1.00 1.00 0.00 220.00 300.0 0.00 0.00 300.0 2438 -1.3 -1.1 1.00 -1.00 0.00 180.00 550.0 0.00 0.00 550.0 4938 -1.3 -1.1 0.00 0.00 0.00 0.00 1,050.0 5.00 170.00 1,049.4 9932 -22.8 2.7 1.00 1.00 0.00 170.00 1,659.8 14.15 170.00 1,650.0 1,593.8 -122.6 20.3 1.50 1.50 0.00 0.00 1,762.9 14.15 170.00 1,750.0 1,693.8 -147.4 24.6 0.00 0.00 0.00 0.00 2,304.2 30.00 160.00 2,250.2 2,194.0 -341.0 82.8 3.00 2.93 -1.85 -18.09 3,375.8 59.90 143.39 3,000.0 2,943.8 -993.2 444.8 3.00 2.79 -1.55 -21.43 3,395.8 59.90 143.39 3,010.0 2.9538 -1,007.1 455.1 0.00 0.00 0.00 0.00 3,562.2 61.58 141.28 3,091.4 3,035.2 -1,122.0 543.9 1.50 1.01 -1.27 -48.11 9,815.1 61.58 141.28 6,067.2 6,011.0 -5,412.6 3,984.0 0.00 0.00 0.00 0.00 10,380.4 61.58 141.28 6,336.2 6,280.0 -5,800.4 4,295.0 0.00 0.00 0.00 0.00 10,572.9 55.81 141.28 6,436.2 6,380.0 -5,928.7 4,397.8 3.00 -3.00 0.00 180.00 10,672.9 55.81 141.28 6,492.4 6,436.2 -5,993.2 4,449.6 0.00 0.00 0.00 0.00 9/24/2009 9:02:02AM Page 2 COMPASS 2003.16 Build 42B HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer- Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODSK-42i Wellbore: ODSK-42i KupG Design: ODSK-42i KupG wp10.a Planned Survey Measured 42.7 + 13.5'@ 56.2ft (Nabors 19AC) MD Reference: Vertical North Reference: Depth Inclination Azimuth Depth TVDss (ft) (?) (?) (ft) ft 42.7 0.00 0.00 42.7 -13.5 100.0 0.00 0.00 100.0 43.8 Start Dir 1.00/100'100.0.00' MD, 500.0.00' TVD 200.0 1.00 220.00 200.0 143.8 300.0 0.00 0.00 300.0 243.8 End Dir 300.00' MD, 300.00' TVD 6,031,026.80 400.0 0.00 0.00 400.0 343.8 500.0 0.00 0.00 500.0 443.8 550.0 0.00 0.00 550.0 493.8 Start Dir 1.001100' 550.00' MD, 550.00' TVD 469,843.25 600.0 0.50 170.00 600.0 543.8 700.0 1.50 170.00 700.0 643.8 800.0 2.50 170.00 799.9 743.7 900.0 3.50 170.00 899.8 843.6 1,000.0 4.50 170.00 999.5 943.3 1,050.0 5.00 170.00 1,049.4 993.2 Start Dir 1.50/100' 1050.00' MD, 1049.40' TVD 1,100.0 5.75 170.00 1,099.1 1,042.9 1,200.0 7.25 170.00 1,198.5 1,142.3 1,300.0 8.75 170.00 1,297.5 1,241.3 1,400.0 10.25 170.00 1,396.1 1,339.9 1,500.0 11.75 170.00 1,494.3 1,436.1 1,600.0 13.25 170.00 1,591.9 1,535.7 1,659.8 14.15 170.00 1,650.0 1,593.8 End Dir 1659.80' MD, 1650.00' TVD 17.8 1,676.5 14.15 170.00 1,666.2 1,610.0 Base of Permafrost 6,030,905.48 469,864.14 1.50 1,700.0 14.15 170.00 1,689.0 1,632.8 1,762.9 14.15 170.00 1,750.0 1,693.8 Start Dir 3.0/100' 1762.90' MD, 1750.00' TVD 1,800.0 15.21 168.68 1,785.9 1,729.7 1,900.0 18.10 165.89 1,881.7 1,825.5 2,000.0 21.02 163.85 1,975.9 1,919.7 2,100.0 23.96 162.29 2,068.3 2,012.1 2,200.0 26.91 161.05 2,158.6 2,102.4 2,300.0 29.88 160.04 2,246.5 2,190.3 2,304.2 30.00 160.00 2,250.2 2,194.0 2,336.7 30.91 159.51 2,278.2 2,222.0 Top West Bak 321.14 -341.0 82.8 2,400.0 32.67 158.51 2,332.0 2,275.8 2,500.0 35.46 156.96 2,414.8 2,358.6 2,600.0 38.25 155.41 2,494.8 2,438.6 2,700.0 41.04 153.86 2,571.8 2,515.6 2,800.0 43.83 152.31 2,645.6 2,589.4 2,900.0 46.62 150.76 2,716.0 2,659.8 Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODSK-42i - Slot ODS -42 TVD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) MD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) North Reference: True Survey Calculation Method: Minimum Curvature -387.6 100.4 Map Map 2.90 371.07 +N/3 +E/ -W Northing Easting DLS Vert Section (ft) IN (ft) (ft) -13.50 483.83 0.0 0.0 6,031,028.13 469,844.38 0.00 0.00 0.0 0.0 6,031,028.13 469,844.38 0.00 0.00 -0.7 -0.6 6,031,027.46 469,843.82 1.00 0.20 -1.3 -1.1 6,031,026.80 469,843.25 1.00 0.40 -1.3 -1.1 6,031,026.80 469,843.25 0.00 0.40 -1.3 -1.1 6,031,026.80 469,843.25 0.00 0.40 -1.3 -1.1 6,031,026.80 469,843.25 0.00 0.40 -1.6 -1.1 6,031,026.58 469,843.29 1.00 0.60 -3.3 -0.8 6,031,024.86 469,843.58 1.00 2.16 -6.7 -0.2 6,031,021.42 469,844.18 1.00 5.28 -11.9 0.7 6,031,016.27 469,845.06 1.00 9.96 -18.7 1.9 6,031,009.39 469,846.25 1.00 16.20 -22.8 2.7 6,031,005.31 469,846.95 1.00 19.90 -27.4 3.5 6,031,000.70 469,847.74 1.50 24.09 -38.6 5.4 6,030,989.54 469,849.66 1.50 34.21 -52.3 7.9 6,030,975.83 469,852.03 1.50 46.66 -68.5 10.7 6,030,959.57 469,854.83 1.50 61.42 -87.3 14.0 6,030,940.77 469,858.06 1.50 78.48 -108.6 17.8 6,030,919.44 469,861.73 1.50 97.83 -122.6 20.3 6,030,905.48 469,864.14 1.50 110.49 -126.6 21.0 6,030,901.47 469,864.83 0.00 114.14 -132.3 22.0 6,030,895.80 469,865.80 0.00 119.28 -147.4 24.6 6,030,880.65 469,868.41 0.00 133.03 -156.6 26.4 6,030,871.41 469,870.11 3.00 141.48 -184.6 32.7 6,030,843.45 469,876.36 3.00 167.70 -216.9 41.5 6,030,811.12 469,885.01 3.00 198.87 -253.4 52.7 6,030,774.50 469,896.03 3.00 234.90 -294.2 66.2 6,030,733.69 469,909.40 3.00 275.69 -339.0 82.1 6,030,688.80 469,925.07 3.00 321.14 -341.0 82.8 6,030,686.84 469,925.78 3.00 323.13 -356.5 88.5 6,030,671.35 469,931.42 2.90 338.95 -387.6 100.4 6,030,640.18 469,943.24 2.90 371.07 -439.4 121.7 6,030,588.27 469,964.25 2.92 425.34 -494.3 145.9 6,030,533.31 469,988.25 2.94 483.83 -551.9 173.2 6,030,475.55 470,015.35 2.96 546.41 -612.1 203.8 6,030,415.28 470,045.64 2.98 612.92 -674.5 237.6 6,030,352.74 470,079.22 3.00 683.19 9/24/2009 9.'02:02AM Page 3 COMPASS 2003.16 Build 42B HALLIBURTON Database: EDM Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well; ODSK-42i Wellbore: ODSK-42i KupG Design: ODSK-42i KupG wp10.a Planned Survey Measured 42.7 + 13.5'@ 56.2ft (Nabors 19AC) MD Reference: Vertical North Reference: Depth Inclination Azimuth Depth TVDss (ft) (?) (?) (ft) ft 3,000.0 49.41 149.21 2,782.9 2,726.7 3,100.0 52.20 147.66 2,846.1 2,789.9 3,200.0 54.99 146.11 2,905.4 2,849.2 3,245.6 56.27 145.41 2,931.2 2,875.0 Tuffaceous Shales 3.06 914.56 -903.4 3,300.0 57.78 144.56 2,960.8 2,904.6 3,375.8 59.90 143.39 3,000.0 2,943.8 End Dir 3375.80' MD, 3000.00' TVD -10 3/4" 444.8 3,395.8 59.90 143.39 3,010.0 2,953.8 Start Dir 1.501100'3395.80' MD, 3010.00' TVD 3,400.0 59.94 143.34 3,012.1 2,955.9 3,500.0 60.95 142.06 3,061.5 3,005.3 3,562.2 61.58 141.28 3,091.4 3,035.2 End Dir 3562.20' MD, 3091.40' TVD 470,383.62 3,600.0 61.58 141.28 3,109.4 3,053.2 3,700.0 61.58 141.28 3,157.0 3,100.8 3,800.0 61.58 141.28 3,204.5 3,148.3 3,900.0 61.58 141.28 3,252.1 3,195.9 4,000.0 61.58 141.28 3,299.7 3,243.5 4,100.0 61.58 141.28 3,347.3 3,291.1 4,200.0 61.58 141.28 3,394.9 3,338.7 4,300.0 61.58 141.28 3,442.5 3,386.3 4,400.0 61.58 141.28 3,490.1 3,433.9 4,500.0 61.58 141.28 3,537.7 3,481.5 4,600.0 61.58 141.28 3,585.3 3,529.1 4,700.0 61.58 141.28 3,632.9 3,576.7 4,800.0 61.58 141.28 3,680.5 3,624.3 4,900.0 61.58 141.28 3,728.0 3,671.8 5,000.0 61.58 141.28 3,775.6 3,719.4 5,100.0 61.58 141.28 3,823.2 3,767.0 5,200.0 61.58 141.28 3,870.8 3,814.6 5,300.0 61.58 141.28 3,918.4 3,862.2 5,400.0 61.58 141.28 3,966.0 3,909.8 5,500.0 61.58 141.28 4,013.6 3,957.4 5,600.0 61.58 141.26 4,061.2 4,005.0 5,700.0 61.58 141.28 4,108.8 4,052.6 5,800.0 61.58 141.28 4,156.4 4,100.2 5,900.0 61.58 141.28 4,204.0 4,147.8 6,000.0 61.58 141.28 4,251.5 4,195.3 6,039.2 61.58 141.28 4,270.2 4,214.0 Brook 2B 471,553.69 0.00 3,103.95 -2,657.5 6,100.0 61.58 141.28 4,299.1 4,242.9 6,200.0 61.58 141.28 4,346.7 4,290.5 6,300.0 61.58 141.28 4,394.3 4,338.1 6,400.0 61.58 141.28 4,441.9 4,385.7 Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODSK-42i-Slot ODS42 TVD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) MD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) North Reference: True Survey Calculation Method: Minimum Curvature -2,863.4 1,940.1 Map Map 0.00 3,455.50 +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (ft) (ft) (ft) 2,726.72 3,631.28 -738.9 274.8 6,030,288.24 470,116.14 3.02 757.03 -804.9 315.3 6,030,222.06 470,156.43 3.04 834.23 -872.3 359.3 6,030,154.48 470,200.12 3.06 914.56 -903.4 380.5 6,030,123.26 470,221.18 3.07 952.19 -940.8 406.7 6,030,085.81 470,247.20 3.07 997.78 -993.2 444.8 6,030,033.22 470,285.11 3.09 1,062.62 -1,007.1 455.1 6,030,019.27 470,295.39 0.00 1,079.94 -1,010.0 457.3 6,030,016.35 470,297.54 1.51 1,083.57 -1,079.2 510.0 6,029,946.95 470,349.97 1.50 1,170.55 -1,122.0 543.9 6,029,904.04 470,383.62 1.50 1,225.06 -1,147.9 564.7 6,029,878.02 470,404.31 0.00 1,258.29 -1,216.6 619.7 6,029,809.19 470,459.05 0.00 1,346.17 -1,285.2 674.7 6,029,740.35 470,513.78 0.00 1,434.06 -1,353.8 729.7 6,029,671.52 470,568.51 0.00 1,521.95 -1,422.4 784.7 6,029,602.69 470,623.24 0.00 1,609.84 -1,491.0 839.7 6,029,533.86 470,677.98 0.00 1,697.73 -1,559.6 894.8 6,029,465.03 470,732.71 0.00 1,785.62 -1,628.3 949.8 6,029,396.19 470,787.44 0.00 1,873.51 -1,696.9 1,004.8 6,029,327.36 470,842.17 0.00 1,961.39 -1,765.5 1,059.8 6,029,258.53 470,896.90 0.00 2,049.28 -1,834.1 1,114.8 6,029,189.70 470,951.64 0.00 2,137.17 -1,902.7 1,169.8 6,029,120.86 471,006.37 0.00 2,225.06 -1,971.3 1,224.9 6,029,052.03 471,061.10 0.00 2,312.95 -2,040.0 1,279.9 6,028,983.20 471,115.83 0.00 2,400.84 -2,108.6 1,334.9 6,028,914.37 471,170.57 0.00 2,488.73 -2,177.2 1,389.9 6,028,845.53 471,225.30 0.00 2,576.61 -2,245.8 1,444.9 6,028,776.70 471,280.03 0.00 2,664.50 -2,314.4 1,499.9 6,028,707.87 471,334.76 0.00 2,752.39 -2,383.0 1,555.0 6,028,639.04 471,389.50 0.00 2,840.28 -2,451.7 1,610.0 6,028,570.20 471,444.23 0.00 2,928.17 -2,520.3 1,665.0 6,028,501.37 471,498.96 0.00 3,016.06 -2,588.9 1,720.0 6,028,432.54 471,553.69 0.00 3,103.95 -2,657.5 1,775.0 6,028,363.71 471,608.43 0.00 3,191.83 -2,726.1 1,830.0 6,028,294.87 471,663.16 0.00 3,279.72 -2,794.7 1,885.1 6,028,226.04 471,717.89 0.00 3,367.61 -2,821.6 1,906.6 6,028,199.07 471,739.34 0.00 3,402.05 -2,863.4 1,940.1 6,028,157.21 471,772.62 0.00 3,455.50 -2,932.0 1,995.1 6,028,088.38 471,827.36 0.00 3,543.39 -3,000.6 2,050.1 6,028,019.54 471,882.09 0.00 3,631.28 -3,069.2 2,105.1 6,027,950.71 471,936.82 0.00 3,719.17 9/24/2009 9:02:02AM Page 4 COMPASS 2003.16 Build 42B k- 'ALLIBURTON1 Database: EDM Alaska Company: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Site: Oooguruk Drill Site Well: ODSK-42i Wellbore: ODSK-42i KupG Design: ODSK-42i KupG wp10.a Planned Survey Measured Depth Inclination Azimuth (ft) (?) (?) 6,500.0 61.58 141.28 6,600.0 61.58 141.28 6,700.0 61.58 141.28 6,800.0 61.58 141.28 6,900.0 61.58 141.28 7,000.0 61.58 141.28 7,100.0 61.58 141.28 7,200.0 61.58 141.28 7,300.0 61.58 141.28 7,400.0 61.58 141.28 7,500.0 61.58 141.28 7,600.0 61.58 141.28 7,700.0 61.58 141.28 7,800.0 61.58 141.28 7,818.9 61.58 141.28 Top Torok sand 7,900.0 61.58 141.28 8,000.0 61.58 141.28 8,100.0 61.58 141.28 8,200.0 61.58 141.28 8,300.0 61.58 141.28 8,363.2 61.58 141.28 Base Torok Sand 8,400.0 61.58 141.28 8,500.0 61.58 141.28 8,600.0 61.58 141.28 8,700.0 61.58 141.28 8,800.0 61.58 141.28 8,900.0 61.58 141.28 9,000.0 61.58 141.28 9,100.0 61.58 141.28 9,200.0 61.58 141.28 9,226.8 61.58 141.28 Top HRZ 9,300.0 61.58 141.28 9,400.0 61.58 141.28 9,493.6 61.58 141.28 Base HRZ 9,500.0 61.58 141.28 91600.0 61.58 141.28 9,700.0 61.58 141.28 9,710.1 61.58 141.28 Kalubik Marker 91800.0 61.58 141.28 Pioneer Natural Resources Standard Proposal Report Local Co-ordinate Reference: Well ODSK-42i - Slot ODS -42 TVD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) MD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) North Reference: True Survey Calculation Method: Minimum Curvature Vertical 5,861.0 -5,196.3 3,810.6 Map Map 0.00 Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section IN ft (ft) (ft) (ft) (ft) 4,433.30 473,742.99 4,489.5 4,433.3 -3,137.8 2,160.1 6,027,881.88 471,991.55 0.00 3,807.06 4,537.1 4,480.9 -3,206.4 2,215.2 6,027,813.05 472,046.29 0.00 3,894.94 4,584.7 4,528.5 -3,275.1 2,270.2 6,027,744.21 472,101.02 0.00 3,982.83 4,632.3 4,576.1 -3,343.7 2,325.2 6,027,675.38 472,155.75 0.00 4,070.72 4,679.9 4,623.7 -3,412.3 2,380.2 6,027,606.55 472,210.48 0.00 4,158.61 4,727.5 4,671.3 -3,480.9 2,435.2 6,027,537.72 472,265.22 0.00 4,246.50 4,775.0 4,718.8 -3,549.5 2,490.2 6,027,468.88 472,319.95 0.00 4,334.39 4,822.6 4,766.4 -3,618.1 2,545.3 6,027,400.05 472,374.68 0.00 4,422.28 4,870.2 4,814.0 -3,686.8 2,600.3 6,027,331.22 472,429.41 0.00 4,510.16 4,917.8 4,861.6 -3,755.4 2,655.3 6,027,262.39 472,484.15 0.00 4,598.05 4,965.4 4,909.2 -3,824.0 2,710.3 6,027,193.55 472,538.88 0.00 4,685.94 5,013.0 4,956.8 -3,892.6 2,765.3 6,027,124.72 472,593.61 0.00 4,773.83 5,060.6 5,004.4 -3,961.2 2,820.3 6,027,055.89 472,648.34 0.00 4,861.72 5,108.2 5,052.0 -4,029.8 2,875.4 6,026,987.06 472,703.08 0.00 4,949.61 5,117.2 5,061.0 -4,042.8 2,885.8 6,026,974.02 472,713.44 0.00 4,966.25 5,155.8 5,099.6 -4,098.5 2,930.4 6,026,918.22 472,757.81 0.00 5,037.50 5,203.4 5,147.2 -4,167.1 2,985.4 6,026,849.39 472,812.54 0.00 5,125.38 5,251.0 5,194.8 -4,235.7 3,040.4 6,026,780.56 472,867.27 0.00 5,213.27 5,298.5 5,242.3 -4,304.3 3,095.4 6,026,711.73 472,922.00 0.00 5,301.16 5,346.1 5,289.9 -4,372.9 3,150.4 6,026,642.89 472,976.74 0.00 5,389.05 5,376.2 5,320.0 -4,416.3 3,185.2 6,026,599.42 473,011.31 0.00 5,444.56 5,393.7 5,337.5 -4,441.6 3,205.5 6,026,574.06 473,031.47 0.00 5,476.94 5,441.3 5,385.1 -4,510.2 3,260.5 6,026,505.23 473,086.20 0.00 5,564.83 5,488.9 5,432.7 -4,578.8 3,315.5 6,026,436.40 473,140.93 0.00 5,652.72 5,536.5 5,480.3 -4,647.4 3,370.5 6,026,367.57 473,195.67 0.00 5,740.61 5,584.1 5,527.9 -4,716.0 3,425.5 6,026,298.73 473,250.40 0.00 5,828.49 5,631.7 5,575.5 -4,784.6 3,480.5 6,026,229.90 473,305.13 0.00 5,916.38 5,679.3 5,623.1 -4,853.3 3,535.6 6,026,161.07 473,359.86 0.00 6,004.27 5,726.9 5,670.7 -4,921.9 3,590.6 6,026,092.24 473,414.60 0.00 6,092.16 5,774.5 5,718.3 -4,990.5 3,645.6 6,026,023.40 473,469.33 0.00 6,180.05 5,787.2 5,731.0 -5,008.9 3,660.3 6,026,004.97 473,483.98 0.00 6,203.58 5,822.0 5,765.8 -5,059.1 3,700.6 6,025,954.57 473,524.06 0.00 6,267.94 5,869.6 5,813.4 -5,127.7 3,755.6 6,025,885.74 473,578.79 0.00 6,355.83 5,914.2 5,858.0 -5,192.0 3,807.1 6,025,821.29 473,630.04 0.00 6,438.12 5,917.2 5,861.0 -5,196.3 3,810.6 6,025,816.91 473,633.53 0.00 6,443.71 5,964.8 5,908.6 -5,265.0 3,865.7 6,025,748.07 473,688.26 0.00 6,531.60 6,012.4 5,956.2 -5,333.6 3,920.7 6,025,679.24 473,742.99 0.00 6,619.49 6,017.2 5,961.0 -5,340.5 3,926.2 6,025,672.32 473,748.50 0.00 6,628.33 6,060.0 6,003.8 -5,402.2 3,975.7 6,025,610.41 473,797.72 0.00 6,707.38 9/24/2009 9.•02:02AM Page 5 COMPASS 2003.16 Build 42B HALLIBURTON Pioneer Natural Resources Standard Proposal Report Database: EDM _Alaska Local Co-ordinate Reference: Well ODSK-421- Slot ODS -42 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-42i Survey Calculation Method: Minimum Curvature Wellbore: ODSK-42i KupG +E/ -W Northing (ft) (ft) (ft) -5,412.6 Design: ODSK-42i KupG wp10.a 6,025,600.00 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting (ft) (?) (?) (ft) ft IN (ft) (ft) (ft) 9,815.1 61.58 141.28 6,067.2 6,011.0 -5,412.6 3,984.0 6,025,600.00 473,806.00 KupG v8 T1 9,846.6 61.58 141.28 6,082.2 6,026.0 -5,434.2 4,001.4 6,025,578.30 473,823.25 7 5/8" 9,857.1 61.58 141.28 6,087.2 6,031.0 -5,441.4 4,007.1 6,025,571.07 473,829.00 Top Kuparuk C 9,890.8 61.58 141.28 6,103.2 6,047.0 -5,464.5 4,025.6 6,025,547.93 473,847.40 Base Kuparuk C (LCU) 9,900.0 61.58 141.28 6,107.6 6,051.4 -5,470.8 4,030.7 6,025,541.58 473,852.46 10,000.0 61.58 141.28 6,155.2 6,099.0 -5,539.4 4,085.7 6,025,472.74 473,907.19 10,100.0 61.58 141.28 6,202.8 6,146.6 -5,608.0 4,140.7 6,025,403.91 473,961.92 10,200.0 61.58 141.28 6,250.4 6,194.2 -5,676.7 4,195.8 6,025,335.08 474,016.65 10,210.2 61.58 141.28 6,255.2 6,199.0 -5,683.6 4,201.3 6,025,328.09 474,022.21 BCU 10,300.0 61.58 141.28 6,298.0 6,241.8 -5,745.3 4,250.8 6,025,266.25 474,071.39 10,365.6 61.58 141.28 6,329.2 6,273.0 -5,790.3 4,286.9 6,025,221.06 474,107.32 Top Nuiqsut 10,380.4 61.58 141.28 6,336.2 6,280.0 -5,800.4 - 4,295.0 6,025,210.90 474,115.39 Start Dir 3.01100' 10380.40' MD, 6336.20' TVD 10,400.0 60.99 141.28 6,345.6 6,289.4 -5,813.8 4,305.8 6,025,197.45 474,126.09 10,500.0 57.99 141.28 6,396.4 6,340.2 -5,881.1 4,359.7 6,025,130.03 474,179.70 10,572.9 55.81 141.28 6,436.2 6,380.0 -5,928.7 4,397.8 6,025,082.24 474,217.70 End Dir 10572.90' MD, 6436.20' TVD 10,585.3 55.81 141.28 6,443.2 6,387.0 -5,936.7 4,404.3 6,025,074.18 474,224.10 Base Nulqsut 10,600.0 55.81 141.28 6,451.4 6,395.2 -5,946.2 4,411.9 6,025,064.70 474,231.65 10,604.9 55.81 141.28 6,454.2 6,398.0 -5,949.4 4,414.4 6,025,061.51 474,234.18 Nechelik 10,672.8 55.81 141.28 6,492.4 6,436.2 -5,993.2 4,449.5 6,025,017.57 474,269.12 Total Depth at 10672.90' MD, 6492.40' TVD -10,672.9 55.81 141.28 6,492.4 • 6,436.2 -5,993.2 4,449.6 6,025,017.51 474,269.17 Targets Target Name • hit/miss target Dip Angle Dip Dir. TVD • Shape (?) (?) (ft) KupG v8 T1 0.00 0.00 6,067.2 - plan hits target - Circle (radius 200.0) DLS Vert Section 6,011.00 0.00 6,720.67 0.00 0.00 WIN 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.01 3.00 3.00 0.00 0.00 0.00 0.00 0.00 +NIS +E/ -W Northing (ft) (ft) (ft) -5,412.6 3,984.0 6,025,600.00 6,748.37 6,757.60 6,787.15 6,795.27 6,883.16 6,971.05 7,058.93 7,067.86 7,146.82 7,204.52 7,217.49 7,234.66 7,320.75 7,381.77 7,392.06 7,404.17 7,408.23 7,464.35 7,464.42 Easting (ft) 473,806.00 912412009 9:02:02AM Page 6 COMPASS 2003.16 Build 42B HALLIBURTON Database: EDM -Alaska Company: Well Planning - Pioneer - Oooguruk Project: Ooogumk Development Site: Oooguruk Drill Site Well: ODSK-42i Wellbore: ODSK-42i KupG Design: ODSK-42i KupG wp10.a Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Pioneer Natural Resources Standard Proposal Report Well ODSK-42i - Slot ODS -42 42.7 + 13.5'@ 56.2ft (Nabors 19AC) 42.7 + 13.5'@ 56.211(Nabors 19AC) True Minimum Curvature Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,375.8 3,000.0 10 3/4" 10.750 13.500 9,846.6 6,082.2 7 5/8" 7.625 9.875 10,672.9 6,492.4 41/2" 4.500 6.750 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (7) (7) 9,493.6 5,914.2 Base HRZ 0.00 7,818.9 5,117.2 Top Torok sand 0.00 10,365.6 6,329.2 Top Nuiqsut 0.00 10,210.2 6,255.2 BCU 0.00 9,710.1 6,017.2 Kalubik Marker 0.00 9,226.8 5,787.2 Top HRZ 0.00 9,890.8 6,103.2 Base Kuparuk C (LCU) 0.00 3,245.6 2,931.2 Tuffaceous Shales 0.00 2,336.7 2,278.2 Top West Sak 0.00 8,363.2 5,376.2 Base Torok Sand 0.00 9,857.1 6,087.2 Top Kuparuk C 0.00 1,676.5 1,666.2 Base of Permafrost 0.00 6,039.2 4,270.2 Brook 2B 0.00 10,604.9 6,454.2 Nechelik 0.00 10,585.3 6,443.2 Base Nuiqsut 0.00 Plan Annotations Measured Depth (ft) 100.0 300.0 550.0 1,050.0 1,659.8 1,762.9 3,375.8 3,395.8 3,562.2 10,380.4 10,572.9 10,672.8 Vertical Depth (ft) 100.0 300.0 550.0 1,049.4 1,650.0 1,750.0 3,000.0 3,010.0 3,091.4 6,336.2 6,436.2 6,492.4 Local Coordinates +N/ -S +E/ -W (ft) (ft) 0.0 -1.3 -1.3 -22.8 -122.6 -147.4 -993.2 -1,007.1 -1,122.0 -5,800.4 -5,928.7 -5,993.2 0.0 2.7 20.3 24.6 444.8 455.1 543.9 4,295.0 4,397.8 4,449.5 Comment Start Dir 1.00/100' 100.0.00' MD, 500.0.00' TVD End Dir 300.00' MD, 300.00' TVD Start Dir 1.00/100' 550.00' MD, 550.00' TVD Start Dir 1.50/100' 1050.00' MD, 1049.40' TVD End Dir 1659.80' MD, 1650.00' TVD Start Dir 3.0/100' 1762.90' MD, 1750.00' TVD End Dir 3375.80' MD, 3000.00' TVD Start Dir 1.50/100' 3395.80' MD, 3010.00' TVD End Dir 3562.20' MD, 3091.40' TVD Start Dir 3.0/100' 10380.40' MD, 6336.20' TVD End Dir 10572.90' MD, 6436.20' TVD Total Depth at 10672.90' MD, 6492.40' TVD 9/24/2009 9:02.,02AM Page 7 COMPASS 2003.16 Build 42B Well Planning Oooguruk Development Oooguruk Drill Site ODSK-42i ODSK-42i KupG ODSK-42i KupG wp10.a - Pioneer - Oooguruk Sperry Drilling Services Clearance Summary Anticollision Report 24 September, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-42i - ODSK-42i KupG - ODSK-42i KupG wp10.a Well Coordinates: 6,031,028.13 N, 469,844.38 E (70" 29'45.03" N, 150" 14'47.69" W) Datum Height: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) Scan Range: 42.7 to 750.0 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42B Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services ODSN-lli IS11 oos�. OD 42 MO 1 i ODSN-9i 159 ODSK-13 KupH b 1 � _ ODSN-7i IS7 pB t 30 ODSK-33 Ku ODSN-31 PN —.— ODSN-34i II �ODSN-341 W2-20 Dhspo ODSN-37 ODSN-3( 2]0 00 -381 Ku ODSN-39i IN11 ODSDWi-040isposa Major Risk 14SN-00 PN12 ODSn-485VV9 / Range!) ODSK-01 Minor Riski/2 RangeO- SW11 wp07 - 7, ODSN-46IN11 210 11 180 150 Travelling Cylinder Azimuth (TFO+AZI) J?J vs Centre to Centre Separation 150 Win] REFERENCE INFORMATON Cowdinats(NIE)Reference; WoII ODSK-42i- Shot ODSAZ True North Vertical (TVD) Reference: 42]+13.5' @56.26 (Nabors 19AC) Section (Val Reference: Slot- ODS42(0.01,1, ODE) Measured Depth Reference: 42.7+13.5' @56.26 (Nabors 19AC) Calculation Method: Minimum Curvature NAD 27 ASP Zone 4 : WELL DETAILS: ODSK-021 Ground Level: 13S +WS +EI -W Northing Essting Latittude Longitude 0.0 0.0 6031028.13 409644.38 70-29'45.0271,1 150-14-47.6139W ANTI -COLLISION SETTINGS SURVEY PROGRAM MD, interval: 25.0 Depth Range From: Date: 2009409-231100:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 42.7 1400.0 ODSK42i KupG wplO.a SR -Gyro -SS 1400.0 10672.9 ODSK421 KupG wplO.a MWD+IM+MS+sag ODSN-lli IS11 oos�. OD 42 MO 1 i ODSN-9i 159 ODSK-13 KupH b 1 � _ ODSN-7i IS7 pB t 30 ODSK-33 Ku ODSN-31 PN —.— ODSN-34i II �ODSN-341 W2-20 Dhspo ODSN-37 ODSN-3( 2]0 00 -381 Ku ODSN-39i IN11 ODSDWi-040isposa Major Risk 14SN-00 PN12 ODSn-485VV9 / Range!) ODSK-01 Minor Riski/2 RangeO- SW11 wp07 - 7, ODSN-46IN11 210 11 180 150 Travelling Cylinder Azimuth (TFO+AZI) J?J vs Centre to Centre Separation 150 Win] REFERENCE INFORMATON Cowdinats(NIE)Reference; WoII ODSK-42i- Shot ODSAZ True North Vertical (TVD) Reference: 42]+13.5' @56.26 (Nabors 19AC) Section (Val Reference: Slot- ODS42(0.01,1, ODE) Measured Depth Reference: 42.7+13.5' @56.26 (Nabors 19AC) Calculation Method: Minimum Curvature NAD 27 ASP Zone 4 : WELL DETAILS: ODSK-021 Ground Level: 13S +WS +EI -W Northing Essting Latittude Longitude 0.0 0.0 6031028.13 409644.38 70-29'45.0271,1 150-14-47.6139W From Color To 43 250 250 500 500 — 750 750 1000 100012W 1250 1500 1500 1750 1750 — 2000 2000 2250 2250 2500 25M 27W 2750 3000 3000 3250 3250 — 3500 3500 37W 3760 4000 4000 5000 5000 woo me 7000 7000 8000 8000 -- - ' 9000 9000 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 -- - 15000 15000 — 16000 16000 — 17000 17000 18000 18000 19000 19000 200M 20000 25000 ODSK-381 KupC Range O-750 Major Risk ODSN-39i IN11 Rarye O - 7Se Major Risk 90 Travelling Cylinder Azimuth (TFO+A7n I?j vs Centre to Centre Separation 120 Win] Well Planning -Pioneer-Ooogumk ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.0 Depth Range From: 42.7 To 750.0 Results Limited By: Centre Distance: 1263.0 Reference: Plan: ODSK42i KupG wp10.a (ODSK-42ilODSK421 KupG) Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 10011000 of reference From Color To 43 250 250 500 500 — 750 750 1000 100012W 1250 1500 1500 1750 1750 — 2000 2000 2250 2250 2500 25M 27W 2750 3000 3000 3250 3250 — 3500 3500 37W 3760 4000 4000 5000 5000 woo me 7000 7000 8000 8000 -- - ' 9000 9000 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 -- - 15000 15000 — 16000 16000 — 17000 17000 18000 18000 19000 19000 200M 20000 25000 ODSK-381 KupC Range O-750 Major Risk ODSN-39i IN11 Rarye O - 7Se Major Risk 90 Travelling Cylinder Azimuth (TFO+A7n I?j vs Centre to Centre Separation 120 Win] Well Planning -Pioneer-Ooogumk Calculation Method: Minimum Curvature Error System: ISCWSA Seen Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based slat ODS42 Me D HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK42i - ODSK-421 KupG - ODSK-421 KupG wp10.a Scan Range: 42.7 to 750.0 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Well Planning - Pioneer - Oooguruk Oooguruk Development Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSDW1-44-ODSDWI-44 Disposal -ODSDWI-44[ 275.1 24.0 275.1 19.3 275.0 5.202 Centre Distance Pass - Major Risk ODSDW1-44-ODSDWI-44 Disposal -ODSDWI-44C 700.0 26.7 700.0 15.2 700.0 2.313 Clearance Factor Pass - Major Risk ODSDW2-20 - ODSDW2-20 Disposal - ODSDW2-20 C 525.0 40.2 525.0 30.8 525.0 4.271 Centre Distance Pass - Major Risk ODSDW2-20 - ODSDW2-20 Disposal - ODSDW2.20 C 699.6 40.9 699.6 28.6 700.0 3.316 Clearance Factor Pass - Major Risk ODSK-13i - ODSK-13 KupHi - ODSK-13 KupHi wp03 100.0 48.0 100.0 46.2 100.0 26.859 Centre Distance Pass - Major Risk ODSK-13i - ODSK-13 KupHi - ODSK-13 KupHi wp03 475.0 50.8 475.0 42.4 475.0 6.033 Clearance Factor Pass - Major Risk ODSK-14 -ODSK-14 KupB 1 - ODSK-14 KupB 1 wpO' 100.0 43.1 100.0 41.3 100.0 24.144 Centre Distance Pass - Major Risk ODSK-14 - ODSK-14 KupB 1 - ODSK-14 KupB 1 wpO, 475.0 45.9 475.0 37.5 475.0 5.457 Clearance Factor Pass - Major Risk ODSK-33 - ODSK-33 KupA - ODSK-33 KupA 697.3 73.0 697.3 61.0 700.0 6.127 Clearance Factor Pass - Major Risk ODSK-33 - ODSK-33 KupA PB1 - ODSK-33 KupA PB, 697.3 73.0 697.3 61.0 700.0 6.127 Clearance Factor Pass - Major Risk ODSK-35 - ODSK-35 KupB - ODSK-35 KupB Surveys 124.7 59.8 124.7 57.6 125.0 26.622 Centre Distance Pass - Major Risk ODSK-35 - ODSK-35 KupB - ODSK-35 KupB Surveys 624.5 63.4 624.5 52.7 625.0 5.928 Clearance Factor Pass - Major Risk ODSK-38i - ODSK-38i KupD - ODSK-38i KupD Survey 573.6 25.9 573.6 15.9 575.0 2.581 Centre Distance Pass - Major Risk ODSK-38i - ODSK-381 KupD - ODSK-38i KupD Survey 673.4 26.5 673.4 15.0 675.0 2.293 Clearance Factor Pass - Major Risk ODSK-41 - ODSK-41 KupF - ODSK-41 KupF Surveys 423.7 5.4 423.7 3.0 425.0 2.251 Centre Distance Pass - Minor Risk 1/10 ODSK-41 - ODSK-41 KupF - ODSK-41 KupF Surveys 448.7 5.5 448.7 3.0 450.0 2.212 Clearance Factor Pass - Minor Risk 1/10 ODSK-41 - ODSK-41 KupF PB1 - ODSK-41 KupF PB1 423.7 5.4 423.7 3.0 425.0 2.251 Centre Distance Pass - Minor Risk 1/10 ODSK-41 - ODSK-41 KupF PB1 - ODSK-41 KupF PSI 448.7 5.5 448.7 3.0 450.0 2.212 Clearance Factor Pass - Minor Risk 1/10 ODSN-1 - ODSN-1 - ODSN-1 NE3 wp01 100.0 144.8 100.0 142.9 100.0 77.268 Centre Distance Pass - Major Risk ODSN-1 - ODSN-1 - ODSN-1 NE3 wp01 400.0 147.4 400.0 140.2 400.0 20.531 Clearance Factor Pass - Major Risk ODSN-10 - ODSN-10 PS12 - ODSN-10 PS12 wp10 100.0 74.6 100.0 72.8 100.0 39.822 Centre Distance Pass - Major Risk ODSN-10 - ODSN-10 PS12 - ODSN-10 PS12 wp10 599.4 77.0 599.4 66.3 600.0 7.176 Clearance Factor Pass - Major Risk ODSN-111- ODSN-11i IS11 - ODSN-11i IS11 wp11 tes 100.0 68.4 100.0 66.5 100.0 36.506 Centre Distance Pass - Major Risk ODSN-11i - ODSN-11i ISI 1 - ODSN-11i IS11 wp11 tee 549.9 71.9 549.9 62.0 550.0 7.281 Clearance Factor Pass - Major Risk ODSN-12 - ODSN-12 PS10 - ODSN-12 PS10 wp12 100.0 62.4 100.0 60.6 100.0 34.926 Centre Distance Pass - Major Risk ODSN-12 - ODSN-12 PS10 - ODSN-12 PS10 wp12 574.7 64.8 574.7 54.6 575.0 6.343 Clearance Factor Pass - Major Risk ODSN-151 - ODSN-151 IS13 - ODSN-15i IS13 wp08 100.0 38.9 100.0 37.1 100.0 20.782 Centre Distance Pass - Major Risk ODSN-15i - ODSN-15i IS13 - ODSN-15i IS13 wp08 450.0 41.3 450.0 33.3 450.0 5.135 Clearance Factor Pass - Major Risk 24 September, 2009 - 9:22 Page 2 of 8 COMPASS HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp1O.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-421 -ODSK-42i KupG - ODSK-42i KupG wp10.a Scan Range: 42.7 to 750.0 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Well Planning - Pioneer - Oooguruk Oooguruk Development 24 September, 2009 - 9.22 Page 3 of 8 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN-16 - ODSN-16 PS14 - ODSN-16 PS14 wp09 100.0 35.6 100.0 33.8 100.0 19.021 Centre Distance Pass - Major Risk ODSN-16 - ODSN-16 PS14 - ODSN-16 PS14 wp09 574.9 36.9 574.9 26.6 575.0 3.564 Clearance Factor Pass - Major Risk ODSN-171- ODSN-17i IS15 - ODSN-17i IS15 wp08 100.0 33.5 100.0 31.7 100.0 17.896 Centre Distance Pass - Major Risk ODSN-17i - ODSN-17i IS15 - ODSN-17i IS15 wp08 550.0 35.4 550.0 25.5 550.0 3.597 Clearance Factor Pass - Major Risk ODSN-18 - ODSN-18 PS16 - ODSN-18 PS16 wp08 100.0 32.8 100.0 30.9 100.0 17.487 Centre Distance Pass - Major Risk ODSN-18 - ODSN-18 PS16 - ODSN-18 PS16 wp08 425.0 34.2 425.0 26.6 425.0 4.506 Clearance Factor Pass - Major Risk ODSN-2 - ODSN-2 PS1 - ODSN-2 PS1 wpO8 100.0 138.0 100.0 136.1 100.0 73.633 Centre Distance Pass - Major Risk ODSN-2 - ODSN-2 PS1 - ODSN-2 PS1 wp08 500.0 140.6 500.0 131.5 500.0 15.579 Clearance Factor Pass - Major Risk ODSN-25 - ODSN-25 - ODSN-25 NE4 wp02 98.7 141.0 98.7 139.2 100.0 76.022 Centre Distance Pass - Major Risk ODSN-25 - ODSN-25 - ODSN-25 NE4 wp02 423.7 143.8 423.7 136.3 425.0 19.101 Clearance Factor Pass - Major Risk ODSN-26 - ODSN-26 PN1 - ODSN-26 PN1 wpO6 100.0 134.0 100.0 132.2 100.0 71.523 Centre Distance Pass - Major Risk ODSN-26 - ODSN-26 PN1 - ODSN-26 PN1 wpO6 500.0 136.6 500.0 127.6 500.0 15.163 Clearance Factor Pass - Major Risk ODSN-27i - ODSN-27i IN2 - ODSN-271 IN2 wp06 100.0 127.0 100.0 125.1 100.0 67.768 Centre Distance Pass - Major Risk ODSN-27i - ODSN-27i IN2 - ODSN-27i IN2 wp06 574.7 129.2 574.7 118.9 575.0 12.475 Clearance Factor Pass - Major Risk ODSN-28 - ODSN-28 PN3 - ODSN-28 PN3 wp07.a 100.0 120.0 100.0 118.2 100.0 64.055 Centre Distance Pass - Major Risk ODSN-28 - ODSN-28 PN3 - ODSN-28 PN3 wp07.a 450.0 123.0 450.0 115.1 450.0 15.462 Clearance Factor Pass - Major Risk ODSN-29i - ODSN-29i IN4 - ODSN-29i IN4 wp06 100.0 113.1 100.0 111.2 100.0 60.334 Centre Distance Pass - Major Risk ODSN-29i - ODSN-29i IN4 - ODSN-29i IN4 wp06 550.0 116.2 550.0 106.4 550.0 11.845 Clearance Factor Pass - Major Risk ODSN-30 - ODSN-30 PN5 - ODSN-30 PN5 wp05 100.0 106.0 100.0 104.2 100.0 56.586 Centre Distance Pass - Major Risk ODSN-30 - ODSN-30 PN5 - ODSN-30 PN5 wp05 599.5 108.3 599.5 97.6 600.0 10.129 Clearance Factor Pass - Major Risk ODSN-31 - ODSN-31 P131 PN6 - ODSN-31 PB1 PN6 S 124.6 88.0 124.6 85.7 125.0 37.689 Centre Distance Pass - Major Risk ODSN-31 - ODSN-31 PB1 PN6 - ODSN-31 P131 PN6 S 550.0 91.3 550.0 81.8 550.0 9.667 Clearance Factor Pass - Major Risk ODSN-31 - ODSN-31 PN6 - ODSN-31 PN6 Surveys 124.6 88.0 124.6 85.7 125.0 37.689 Centre Distance Pass - Major Risk ODSN-31 - ODSN-31 PN6 - ODSN-31 PN6 Surveys 550.0 91.3 550.0 81.8 550.0 9.667 Clearance Factor Pass - Major Risk ODSN-32i - ODSN-32i IN7 - ODSN-32i IN7 Surveys 574.6 79.2 574.6 69.0 575.0 7.780 Centre Distance Pass - Major Risk ODSN-32i - ODSN-32i IN7 - ODSN-32i IN7 Surveys 649.1 79.9 649.1 68.5 650.0 6.996 Clearance Factor Pass - Major Risk ODSN-321 - ODSN-32i IN7 PB1 - ODSN-32i IN7 PB1 574.6 79.2 574.6 69.0 575.0 7.780 Centre Distance Pass - Major Risk ODSN-32i - ODSN-32i IN7 PB1 - ODSN-32i IN7 PB1 649.1 79.9 649.1 68.5 650.0 6.996 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-34 IN9 - ODSN-34 IN9 Surveys 124.7 66.9 124.7 64.6 125.0 29.516 Centre Distance Pass - Major Risk ODSN-34i - ODSN-34 IN9 - ODSN-34 IN9 Surveys 674.0 68.6 674.0 57.2 675.0 6.035 Clearance Factor Pass - Major Risk 24 September, 2009 - 9.22 Page 3 of 8 COMPASS HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Well Planning - Pioneer - Oooguruk Oooguruk Development Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-42i - ODSK-421 KupG - ODSK 421 KupG wp10.a Scan Range: 42.7 to 750.0 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN-34i - ODSN-34i IN9 PB1 - ODSN-34i IN9 PB1 124.7 66.9 124.7 64.6 125.0 29.516 Centre Distance Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB1 - ODSN-34i IN9 PB1 674.0 68.6 674.0 57.2 675.0 6.035 Clearance Factor Pass - Major Risk ODSN-341- ODSN-34i IN9 PB2 - ODSN-341 IN9 PB2 124.7 66.9 124.7 64.6 125.0 29.516 Centre Distance Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB2 - ODSN-34i IN9 PB2 674.0 68.6 674.0 57.2 675.0 6.035 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB3 - ODSN-34i IN9 PB3 124.7 66.9 124.7 64.6 125.0 29.516 Centre Distance Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB3 - ODSN-34i IN9 PB3 674.0 68.6 674.0 57.2 675.0 6.035 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 - ODSN-36 PN10 Surveys 42.7 53.0 42.7 52.0 42.7 52.468 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 - ODSN-36 PN10 Surveys 499.8 56.3 499.8 46.1 500.0 6.835 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 PB1 PN10 42.7 53.0 42.7 52.0 42.7 52.468 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 PB1 PN10 499.8 56.3 499.8 48.1 500.0 6.835 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 PB2 - ODSN-36 PB2 PN10 42.7 53.0 42.7 52.0 42.7 52.468 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 PB2 - ODSN-36 PB2 PN10 499.8 56.3 499.8 48.1 500.0 6.835 Clearance Factor Pass - Major Risk ODSN-37 - ODSN-37 - ODSN-37 Surveys 124.8 34.9 124.8 32.6 125.0 15.061 Centre Distance Pass - Major Risk ODSN-37 - ODSN-37 - ODSN-37 Surveys 599.8 36.9 599.8 26.7 600.0 3.609 Clearance Factor Pass - Major Risk ODSN-39i - ODSN-391 IN11 - ODSN-39i IN11 524.9 18.9 524.9 9.5 525.0 2.005 Centre Distance Pass - Major Risk ODSN-39i - ODSN-39i IN11 - ODSN-39i IN11 574.8 19.4 574.8 9.1 575.0 1.887 Clearance Factor Pass - Major Risk ODSN-39i - ODSN-39i IN11 - ODSN-391 IN11 wp16 524.9 18.9 524.9 9.5 525.0 2.015 Centre Distance Pass - Major Risk ODSN-391- ODSN-39i IN11 - ODSN-39i IN11 wp16 574.8 19.4 574.8 9.2 575.0 1.895 Clearance Factor Pass - Major Risk ODSN-3i - ODSN-3i IS2 - ODSN-31 IS2 wp08 100.0 131.2 100.0 129.4 100.0 71.606 Centre Distance Pass - Major Risk ODSN-3i - ODSN-3i IS2 - ODSN-31 IS2 wp08 574.6 133.4 574.6 123.1 575.0 12.899 Clearance Factor Pass - Major Risk ODSN-4 - ODSN-4 PS3 - ODSN-4 PS3 wp07 100.0 124.5 100.0 122.6 100.0 66.425 Centre Distance Pass - Major Risk ODSN-4 - ODSN-4 PS3 - ODSN-4 PS3 wp07 450.0 127.6 450.0 119.5 450.0 15.717 Clearance Factor Pass - Major Risk ODSN-40 - ODSN-40 PN12 - ODSN-40 PN12 Surveys 448.6 12.8 448.6 9.6 450.0 3.945 Clearance Factor Pass - Minor Risk 1/200 ODSN-40 - ODSN-40 PN12 PB1 - ODSN-40 PN12 PB 448.6 12.8 448.6 9.6 450.0 3.945 Clearance Factor Pass - Minor Risk 1/200 ODSN-40 - ODSN-40 PN12 PB2 - ODSN-40 PN12 PB 448.6 12.8 448.6 9.6 450.0 3.945 Clearance Factor Pass - Minor Risk 1/200 ODSN-43 - ODSN-43 PN14 - ODSN-43 PN14 wp12 298.7 16.2 298.7 10.8 300.0 3.020 Centre Distance Pass - Major Risk ODSN-43 - ODSN-43 PN14 - ODSN-43 PN14 wp12 473.7 17.5 473.7 9.3 475.0 2.134 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-45A Moraine - ODSN-45A Moraine 275.1 31.3 275.1 26.3 275.0 6.275 Centre Distance Pass - Major Risk ODSN-45 - ODSN-45A Moraine - ODSN-45A Moraine 375.0 32.3 375.0 25.5 375.0 4.762 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-45A Moraine - ODSN-45A Surveys 275.1 31.3 275.1 26.3 275.0 6.275 Centre Distance Pass - Major Risk 24 September, 2009 - 9:22 Page 4 of 8 COMPASS HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-421 - ODSK-42i KupG - ODSK42i KupG wp10.a Scan Range: 42.7 to 750.0 ft. Measured Depth. Scan Radius is 1,263.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Well Planning - Pioneer - Oooguruk Oooguruk Development Survey tool orooranl From To Survey/Plan Survey Tool (ft) (ft) 42.7 1,400.0 ODSK-421 KupG wp10.a SR -Gyro -SS 1,400.0 10,672.9 ODSK-421 KupG wpl O.a MWD+IFR2+MS+sag 24 September, 2009 - 9:22 Page 5 of 8 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN-45 - ODSN-45A Moraine - ODSN-45A Surveys 375.0 32.3 375.0 25.5 375.0 4.762 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-451 IN13 PB1 - ODSN45i IN13 PB1 275.1 31.3 275.1 26.3 275.0 6.275 Centre Distance Pass - Major Risk ODSN45 - ODSN-45i IN13 P131 - ODSN-45i IN13 PB1 375.0 32.3 375.0 25.5 375.0 4.762 Clearance Factor Pass - Major Risk ODSN-46 - ODSN46 IN11 - ODSN-46 IN11 wp17 300.0 37.2 300.0 31.8 300.0 6.910 Centre Distance Pass - Major Risk ODSN-46 - ODSN46 IN11 - ODSN-46 IN11 wp17 425.0 38.2 425.0 30.8 425.0 5.162 Clearance Factor Pass - Major Risk ODSN-47 - ODSN-47 SWI 1 wp01 - ODSN-47 SW11 v 298.7 44.2 298.7 38.9 300.0 8.256 Centre Distance Pass - Major Risk ODSN-47 - ODSN-47 SW11 wp01 - ODSN-47 SW11 v 398.7 45.0 398.7 38.0 400.0 6.435 Clearance Factor Pass - Major Risk ODSN-48 - ODSn48 SW9 - ODSN-48 SW9 wp01 298.7 51.2 298.7 45.8 300.0 9.553 Centre Distance Pass - Major Risk ODSN-48 - ODSn-48 SW9 - ODSN-48 SW9 wp01 398.7 52.0 398.7 45.0 400.0 7.431 Clearance Factor Pass - Major Risk ODSN-5i - ODSN-51 IS4 - ODSN-5i IS4 wp08 100.0 117.7 100.0 115.8 100.0 62.809 Centre Distance Pass - Major Risk ODSN-5i - ODSN-51 IS4 - ODSN-5i IS4 wpO8 550.0 120.8 550.0 110.9 550.0 12.124 Clearance Factor Pass - Major Risk ODSN-6 - ODSN-6 PS5 - ODSN-6 PS5 wp09 100.0 111.0 100.0 109.1 100.0 59.242 Centre Distance Pass - Major Risk ODSN-6 - ODSN-6 PS5 - ODSN-6 PS5 wp09 475.0 114.4 475.0 105.8 475.0 13.346 Clearance Factor Pass - Major Risk ODSN-7i - ODSN-7i IS7 - ODSN-7i IS7 wp08 100.0 94.0 100.0 91.9 100.0 45.935 Centre Distance Pass - Major Risk ODSN-7i - ODSN-7i IS7 - ODSN-7i IS7 wpO8 697.9 97.3 697.9 79.2 700.0 5.395 Clearance Factor Pass - Major Risk ODSN-8 - ODSN-8 PS8 - ODSN-8 PS8 wp09 100.0 87.4 100.0 85.6 100.0 48.963 Centre Distance Pass - Major Risk ODSN-8 - ODSN-8 PS8 - ODSN-8 PS8 wpO9 550.0 90.4 550.0 80.5 550.0 9.158 Clearance Factor Pass - Major Risk ODSN-9i - ODSN-9i IS9 - ODSN-91 IS9 wp12 100.0 81.0 100.0 79.2 100.0 45.342 Centre Distance Pass - Major Risk ODSN-9i - ODSN-9i IS9 - ODSN-91 IS9 wp12 500.0 84.3 500.0 75.4 500.0 9.465 Clearance Factor Pass - Major Risk Survey tool orooranl From To Survey/Plan Survey Tool (ft) (ft) 42.7 1,400.0 ODSK-421 KupG wp10.a SR -Gyro -SS 1,400.0 10,672.9 ODSK-421 KupG wpl O.a MWD+IFR2+MS+sag 24 September, 2009 - 9:22 Page 5 of 8 COMPASS HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Well Planning - Pioneer - Oooguruk Oooguruk Development 24 September, 2009 - 9:22 Page 6 of 8 COMPASS Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-42i ODSK-42i KupG ODSK-42i KupG wp10.a Sperry Drilling Services Clearance Summary Anticollision Report 24 September, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-42i - ODSK42i KupG - ODSK42i KupG wp10.a Well Coordinates: 6,031,028.13 N, 469,844.38 E (70° 29'45.03" N, 150° 14'47.69" W) Datum Height: 42.7 + 13.5'@ 56.2ft (Nabors 19AC) Scan Range: 750.0 to 10,672.9 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42B Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURT®N Sperry Drilling Services SURVEYPROGRAM Date: 2009-09-23T00:00:00 Validated: Yer Version: Depth From Depth To Survey/Plan Tool 42.7 1400.0 ODSK-02i KupG wplO.a SR -Gyro -SS 1400.0 10672.9 ODSK42i KupG wplOA MWD+IFR2+MSisag �ODSN-1111S11W5K-331uupq 0(1819.12 P51 ODSK33 Ku ODSK-13 KupH s� Or, OOSDW2-20 dhipe , r WSDWI-4Disposa -�- ODSK-IWM 81 ------- n a \ 3 ODSN-15i 1573 1 1 ODSN-17i 1515 306.: 1 I 270 36 PN10 4000-5000 ODSN-45IN13 P81 -'RI � 210 WSN-0SA Mor4in � � ODSN-061N71 ODSN-47 SW11 wpg1 n ODSN-7i 157 r i ODSK-38i Kup r � l SKd1 Kup r r ODSN-32i IN7 PBI - 30 �� i � MDs1'i-32i IN i r r � CiiSN31 PN r it p 40bSN-31 PBI P 180 ODSN43PNI ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.0 Depth Range From: 750.0 To 10672.9 Results Limited By: Centre Distance: 1263.0 Reference: Plan: OOSK42i KupG wp10.a (ODSK-42i/ODSK-42i KUPG) Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 10011000 of reference From Color To MD 43 — 250 250 — 500 500 — 750 750 1000 thee 1250 1250 1500 ISM — 1750 1750 — 2000 20M 2250 2500 I S00 2750 2750 3000 3000 3250 3250 3500 3500 3750 3750 400D 4000 5000 5500 60DO 6000 7000 70M — 8000 5050 90DO 90M 10000 10000 — 11001) 11000 — 12DOD 12000 13000 13000 14000 14000 — 15000 15050 16050 16000 — 11000 17000 18000 18000 19000 19000 20000 20000 — 25000 240 ODSN-03 PN74 Range750-1000 Major Risk ODSK-38i KupD 0 Range 750-1250 30 Major Risk 30 20&6pox� _ 180 ODSN-3i IN11 Rang.79 50 -10 Major Risk 120 ODSN-40 PN12 Range 750-1250 Major Risk Travelling Cylinder Azimuth (TFOFAZI) I?l vs Centre to Centre Separation 120 Nin] Travelling Cylinder Azimuth (TFO+AZI) (?( vs Centre to Centre Separation 150 It/in( REFERENCEINFORMATION Well Planning- Pioneer. Oocgumk Co-orzinate(NIE) Reference: Well ODSK4 - Slot OD3.42, True North vertical(TVD)Reference:42.7+13.5@562N(Nabore lOAC) Calculation Method: Minimum Curvatura Section (VS) Reference: Slot -01)$42(0.011, 0.0E) Error System: ISCWSA Measured Depth Reference: 427+138@W.21t(Nabors I9AC) Scan Method: Tray. Winder North Calculation Method: MinlrmmCurvatum 67or Surface: Elliptical Conic Warning Method: Rules Based NAD27A9PZone4: WELLDEf Ek ODSK42i Gramel Level: 13.5 +MS +Fl -W Northing Fasting latittuele Longilude slot 0.0 0.0 5031028.13 489694.36 70129'45.027N 150° 14' 47.689 W 01)342 VNQ9 1415 M00 1760- -141� HALLIBURTON Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-42i - ODSK-421 KupG - ODSK-421 KupG wp10.a Scan Range: 750.0 to 10,672.9 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Well Planning - Pioneer - Oooguruk Oooguruk Development Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSDW7-44-ODSDWI-44 Disposal -ODSDWI-441 800.3 26.6 800.3 13.4 800.0 2.025 Centre Distance Pass - Major Risk ODSDW1-44-ODSDWI-44 Disposal -ODSDW1-441 950.0 27.6 950.0 12.0 950.0 1.769 Clearance Factor Pass - Major Risk ODSDW2-20 - ODSDW2-20 Disposal - ODSDW2-20 1 750.0 41.5 750.0 28.3 750.0 3.148 Centre Distance Pass - Major Risk ODSDW2-20 - ODSDW2-20 Disposal - ODSDW2-20 1 774.4 41.9 774.4 28.3 775.0 3.081 Clearance Factor Pass - Major Risk ODSK-13i - ODSK-13 KupHi - ODSK-13 KupHi wp03 771.7 68.5 771.7 55.0 775.0 5.071 Clearance Factor Pass - Major Risk ODSK-14 - ODSK-14 KupB 1 - ODSK-14 KupB 1 wp0' 771.9 63.9 771.9 50.5 775.0 4.743 Clearance Factor Pass - Major Risk ODSK-33 - ODSK-33 KupA - ODSK-33 KupA 845.2 71.7 845.2 57.2 850.0 4.945 Centre Distance Pass - Major Risk ODSK-33 - ODSK-33 KupA - ODSK-33 KupA 894.4 72.4 894.4 57.0 900.0 4.697 Clearance Factor Pass - Major Risk ODSK-33 - ODSK-33 KupA PB1 - ODSK-33 KupA PB' 845.2 71.7 845.2 57.2 850.0 4.945 Centre Distance Pass - Major Risk ODSK-33 - ODSK-33 KupA PB1 - ODSK-33 KupA PB' 694.4 72.4 894.4 57.0 900.0 4.697 Clearance Factor Pass - Major Risk ODSK-35 - ODSK-35 KupB - ODSK-35 KupB Surveys 773.4 66.2 773.4 53.2 775.0 5.096 Clearance Factor Pass - Major Risk ODSK-381 - ODSK-38i KupD - ODSK-38i KupD Survey 773.1 28.7 773.1 15.7 775.0 2.207 Clearance Factor Pass - Major Risk ODSK-41 - ODSK-41 KupF - ODSK-41 KupF Surveys 773.4 15.0 773.4 2.6 775.0 1.211 Clearance Factor Pass - Major Risk ODSK-41 - ODSK-41 KupF PB1 - ODSK-41 KupF PB1 773.4 15.0 773.4 2.6 775.0 1.211 Clearance Factor Pass - Major Risk ODSN-1 - ODSN-1 - ODSN-1 NE3 wp01 769.7 169.2 769.7 155.6 775.0 12.471 Clearance Factor Pass - Major Risk ODSN-10 - ODSN-10 PS12 - ODSN-10 PS12 wp10 771.9 83.3 771.9 69.8 775.0 6.163 Clearance Factor Pass - Major Risk ODSN-11i - ODSN-11 i IS11 - ODSN-11i IS11 wp11 te: 771.4 82.7 771.4 69.2 775.0 6.089 Clearance Factor Pass - Major Risk ODSN-12 - ODSN-12 PS10 - ODSN-12 PS10 wp12 772.1 72.7 772.1 59.2 775.0 5.413 Clearance Factor Pass - Major Risk ODSN-15i - ODSN-15i IS13 - ODSN-151 IS13 wp08 772.3 59.1 - 772.3 45.6 775.0 4.367 Clearance Factor Pass - Major Risk ODSN-16 - ODSN-16 PS14 - ODSN-16 PS14 wp09 773.2 46.0 773.2 32.5 775.0 3.402 Clearance Factor Pass - Major Risk ODSN-17i - ODSN-17i IS15 - ODSN-17i IS15 wp08 773.2 46.8 773.2 33.4 775.0 3.495 Clearance Factor Pass - Major Risk ODSN-18 - ODSN-18 PS16 - ODSN-18 PS16 wp08 772.9 54.5 772.9 41.0 775.0 4.047 Clearance Factor Pass - Major Risk ODSN-2 - ODSN-2 PS1 - ODSN-2 PS1 wp08 770.3 155.1 770.3 141.5 775.0 11.436 Clearance Factor Pass - Major Risk ODSN-25 - ODSN-25 - ODSN-25 NE4 wp02 769.9 160.5 769.9 147.1 775.0 12.015 Clearance Factor Pass - Major Risk ODSN-26 - ODSN-26 PN1 - ODSN-26 PN1 wp06 771.3 150.5 771.3 137.0 775.0 11.125 Clearance Factor Pass - Major Risk ODSN-27i - ODSN-27i IN2 - ODSN-27i IN2 wp06 771.8 137.7 771.8 124.2 775.0 10.193 Clearance Factor Pass - Major Risk ODSN-28 - ODSN-28 PN3 - ODSN-28 PN3 wp07.a 771.8 137.3 771.8 124.0 775.0 10.298 Clearance Factor Pass - Major Risk ODSN-29i - ODSN-29i IN4 - ODSN-29i IN4 wp06 772.1 126.0 772.1 112.7 775.0 9.471 Clearance Factor Pass - Major Risk 24 September, 2009 - 9.29 Page 2 of 6 COMPASS HALLIBURTION Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK-42i - ODSK-42i KupG - ODSK-42i KupG wp10.a Scan Range: 750.0 to 10,672.9 ft. Measured Depth. Scan Radius is 1,263.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Well Planning - Pioneer - Oooguruk Oooguruk Development Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN-30 - ODSN-30 PN5 - ODSN-30 PN5 wp05 772.5 113.6 772.5 100.3 775.0 8.571 Clearance Factor Pass - Major Risk ODSN-31 - ODSN-31 PB1 PN6 - ODSN-31 PB1 PN6 S 772.6 98.4 772.6 85.3 775.0 7.496 Clearance Factor Pass - Major Risk ODSN-31 - ODSN-31 PN6 - ODSN-31 PN6 Surveys 772.6 98.4 772.6 85.3 775.0 7.496 Clearance Factor Pass - Major Risk ODSN-32i - ODSN-32i IN7 - ODSN-32i IN7 Surveys 773.3 83.3 773.3 69.7 775.0 6.163 Clearance Factor Pass - Major Risk ODSN-32i - ODSN-32i IN7 PB1 - ODSN-321 IN7 PB1 773.3 83.3 773.3 69.7 775.0 6.163 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-34 IN9 - ODSN-34 IN9 Surveys 773.3 71.7 773.3 58.6 775.0 5.490 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB1 - ODSN-34i IN9 PB1 773.3 71.7 773.3 58.6 775.0 5.490 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-34i IN9 PB2 - ODSN-34i IN9 P132 773.3 71.7 773.3 58.6 775.0 5.490 Clearance Factor Pass - Major Risk ODSN-34i - ODSN-341 IN9 PB3 - ODSN-34i IN9 PB3 773.3 71.7 773.3 58.6 775.0 5.490 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 - ODSN-36 PN10 Surveys 773.1 69.2 773.1 56.7 775.0 5.543 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 - ODSN-36 PN10 Surveys 4,464.0 148.7 4,464.0 35.5 4,300.0 1.314 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 PB1 PN10 773.1 69.2 773.1 56.7 775.0 5.543 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 PB1 - ODSN-36 PB1 PN10 4,464.0 148.7 4,464.0 35.5 4,300.0 1.314 Clearance Factor Pass - Major Risk ODSN-36 - ODSN-36 PB2 - ODSN-36 PB2 PN10 773.1 69.2 773.1 56.7 775.0 5.543 Centre Distance Pass - Major Risk ODSN-36 - ODSN-36 PB2 .ODSN-36 P132 PN10 4,464.0 148.7 4,464.0 35.5 4,300.0 1.314 Clearance Factor Pass - Major Risk ODSN-37 - ODSN-37 - ODSN-37 Surveys 750.0 40.8 750.0 28.3 750.0 3.255 Clearance Factor Pass - Major Risk ODSN-39i - ODSN-39i INI1 - ODSN-39i IN11 750.0 28.0 750.0 15.2 750.0 2.193 Clearance Factor Pass - Major Risk ODSN-39i - ODSN-39i IN11 - ODSN-39i IN11 wp16 750.0 28.0 750.0 15.3 750.0 2.201 Clearance Factor Pass - Major Risk ODSN-3i - ODSN-31 IS2 - ODSN-3i IS2 wp08 770.7 142.8 770.7 129.2 775.0 10.512 Clearance Factor Pass - Major Risk ODSN-4 - ODSN-4 PS3 - ODSN-4 PS3 wp07 769.9 144.5 769.9 130.8 775.0 10.569 Clearance Factor Pass - Major Risk ODSN-40 - ODSN-40 PN12 - ODSN-40 PN12 Surveys 773.3 25.8 773.3 12.3 775.0 1.912 Clearance Factor Pass - Major Risk ODSN-40 - ODSN-40 PN12 PB1 - ODSN-40 PN12 PB 773.3 25.8 773.3 12.3 775.0 1.912 Clearance Factor Pass - Major Risk ODSN-40 - ODSN-40 PN12 PB2 - ODSN-40 PN12 PB 773.3 25.8 773.3 12.3 775.0 1.912 Clearance Factor Pass - Major Risk ODSN-43 - ODSN-43 PN14 - ODSN-43 PN14 wp12 750.0 27.0 750.0 14.4 750.0 2.148 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-45A Moraine - ODSN-45A Moraine 750.7 44.6 750.7 32.0 750.0 3.543 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-45A Moraine - ODSN-45A Surveys 750.7 44.6 750.7 32.0 750.0 3.543 Clearance Factor Pass - Major Risk ODSN-45 - ODSN-45i IN13 PBI - ODSN45i IN13 PB1 750.7 44.6 750.7 32.0 750.0 3.543 Clearance Factor Pass - Major Risk ODSN-46 - ODSN-46 IN11 - ODSN-46 IN11 wp17 750.8 49.5 750.8 36.9 750.0 3.942 Clearance Factor Pass - Major Risk ODSN-47 - ODSN-47 SWI1 wp01 - ODSN-47 SWI t v 750.0 59.7 750.0 47.1 750.0 4.758 Clearance Factor Pass - Major Risk ODSN-48 - ODSn-48 SW9 - ODSN-48 SW9 wp01 750.0 68.2 750.0 55.6 750.0 5.423 Clearance Factor Pass - Major Risk 24 September, 2009 - 9:29 Page 3 of 6 COMPASS HALLIBURTON Well Planning - Pioneer - Oooguruk Oooguruk Development Anticollision Report for ODSK-42i - ODSK-42i KupG wp10.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site-ODSK-42i - ODSK-42i KupG - ODSK-42i KupG wp10.a Scan Range: 750.0 to 10,672.9 ft. Measured Depth. Scan Radius is 1,263.0 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN-5i - ODSN-5i IS4 - ODSN-5i IS4 wp08 770.6 132.2 770.6 118.5 775.0 9.682 Clearance Factor Pass - Major Risk ODSN-6 - ODSN-6 PS5 - ODSN-6 PS5 wp09 769.9 131.3 769.9 117.6 775.0 9.592 Clearance Factor Pass - Major Risk ODSN-7i - ODSN-7i IS7 - ODSN-7i IS7 wp08 771.8 99.3 771.8 79.3 775.0 4.977 Clearance Factor Pass - Major Risk ODSN-8 - ODSN-8 PS8 - ODSN-8 PS8 wp09 771.3 101.3 771.3 87.8 775.0 7.480 Clearance Factor Pass - Major Risk ODSN-9i - ODSN-9i IS9 - ODSN-9i IS9 wp12 771.0 97.8 771.0 84.2 775.0 7.217 Clearance Factor Pass - Major Risk Survey tool Orooram From To Survey/Plan Survey Tool (ft) (ft) 42.7 1,400.0 ODSK-42i KupG wp10.a SR -Gyro -SS 1,400.0 10,672.9 ODSK-42i KupG wpl O.a MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 24 September, 2009 - 9:29 Page 4 of 6 COMPASS ODSK-42i Kuparuk Injection — Proposed Completion Well Head: 9 5/8", 5K, VetcoGray Tree: 3-112", 5K, Horizontal 16" Conductor -As I II I I I I ` 158' MDrkb / 158' NDrkb 3-1/2" ScSSSV, 2.813" ID @ 750' MDrkb / 750' NDrkb 10-3/4", 45.5# L-80 BTC, 9.95" ID 3434' MDrkb / 301 9'NDrkb 3-1/2" MMG GLM w/1 %s: Dummy Valve -3376' MDrkb / 3000' NDrkb 1 3-112", 9.3# L-80 TCII Top of Cement - Estimated @ 9200' MD / -5782' NDrkb 3-1/2" MMG GLM w/1 %: Dummy Valve @ -8620' MDrkb / 5510' NDrkb 9552' MDrkb _ �I / Radio Active Tag in Markel Joint @ 9562' MDrkb X Nipple, 2.813" ID w/RHC-M Plug 9572' and 9612'M Drkb Date: Revision By: Comments ODSK-42i Injector Well Schematic Version 2.0 9/23/2009 James Franks Proposed Completion 7-5/8" Ultra Pak TH Permani @ 9592' MDrkb XN Nipple, 2.725" ID Nogo @ 9652' MDrkb, 61 degrees 7-5/8", 29.7# L-80 BTC -M, 6.675" ID Liner Hanger/ Liner Top Packer/ 9847' MDrkb / 6082' NDrkb TBS @ 9697' MDrkb Perforations, E -Line post dg WLEG from 9857' MDrkb / 6087' NDrkb 9702' MDrkb to 9891 MDrkb' / 6103' NDrkb 6spf @ 60 degree phasing, 204 Total shots rn i U(9/ 10563 MDrkb 4-1/2", 12.6# L-80 IBT-M, 3.958" ID 10673'N 16492' TVDrkb R PIONEER9/30/2009 Date: Revision By: Comments ODSK-42i Injector Well Schematic Version 2.0 9/23/2009 James Franks Proposed Completion TWC Update for WP 10 NATURAL RESOURCES CHOKE MANIFOLD SCHEMATIC NABORS ALASKA RIG 19AC 3^ p%N lINf 3^ Tp sNg4R 3^ I. MCM TYPE C 3 1/8'-5000 PSI GATE VALVE 2. McEVOY TYPE C 2 9/16'-5000 PSI GATE VALVE 3. SWACO 2 1/16-10000 PSI REMOTE CHOKE 4. THORNHILL—CRAVER 3 1/8'-5000 PSI MANUAL CHOKE 5. FUWGED TEE 2 1/16' X 2 1/16' X 2 1/16'-5000 PSI 6. 5 WAY FLOW BLOCK 3 1/8' X 3 1/8' X 2 1/16' X 2 1/16' X 2 1/16'-5000 PSI 7. 5 WAY FLOW BLOCK 3 1/8' X 3 1/8' X 3 1/8' X 3 1/8' X 2 1/16'-5000 PSI 8. 4 WAY FLOW BLOCK 2 1/16' X 2 1/16' X 2 1/16' X 2 1/16'-5000 PSI 9. 2 1/16'-5000 PSI SENSOR BLOCK 10. 2 1/16'-10,000PS1 X 2 1/16'-5000 PSI SPOOL 11. 3 1/8' X 2 1/16'-5000 PSI SPOOL 12. 2 1/16' X 2 1/16'-5000 PSI SPOOL 13. 3 1/8'-5000 PSI X 2 1/16'-5000 PSI SPOOL 14. 2 1/16'-10,000 PSI X 2 1/16'-5000 PSI DOUBLE SND ADAPTOR 15. 2 1/16'-5000 PSI TARGET FLANGE 16. 3 1/8'-5000 PSI TARGET FLANGE 17. 3 1/8'-5000 PSI X 2 1/16'-5000 PSI DOUBLE SND ADAPTOR 18. 3 1/8' X 3 1/8 5000 PSI SPOOL 19. 3 WAY FLOW BLOCK 3 1/8' X 3 1/8' X 3 1/8'-5000 PSI 20. 5 WAY FLOW BLOCK 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16'-5000 PSI �17cNo�CE y�\\�� \ O 3 d ,6 fo.N.b. Alimil CHOKE MANIFOLD SCHEMATIC 3 1/8" 50001 HCR VALVE - „ 3" -CHOKE LINE_ 3 1/8” 5000/ GATE VALVE 3'-A" E NABORS ALASKA RIG 19AC BOP STACK CONFIGURATION HYDRIL 11 " 5k PSI _ GK ANNULAR BOP SCREWED BOM CONNECTION 47 3/4 LENGTH 11-50001 - FLANGED HYDRIL DOUBLE GATE PREVENTOR 55" LENGTH 3 1/8" 50001 HCR VALVE 3" 50001 GATE VALVE HYDRIL 11" 5k PSI HYDRAULIC RAM SINGLE GATE FLANGED CONNECTION 41 3/4 LENGTH j � I • I i i Nw... wG M tlx4= 6 Gt® WK W0. MIOLL. 4 \t 16• a6ERRR INE f Iff WIE i12 Y YiL WI( II. 7-1 I �� II_1/.• 6 &CO PSI M9(RA SWif 0 o I ftNobw AWw NNROR9 N m WC 19A 21-1/{• ONERIFA Vm n .o®Newer T.C. R® iC. REED T.C. X® � Legend I a O As—bulit Conductor s GRAPHIC SCALE 30 is a 30 M10 (mYYr) 10 �O Notes: Coordinates are listed on sheets 3 and 4 Alaska Nod 27. Zone 4 a 0 s e �k o M10 e 10 �O 0 ry, 10 o 0 o riry o o e ryry e o ryk ,b0 o 'h0 o Notes: Coordinates are listed on sheets 3 and 4 Alaska Nod 27. Zone 4 / a 0 s e �k o 0 10 �O 0 10 o 0 o ,`L o e ,a e / 0 ,b0 / a 0 s e 0 0 �O o q'` o o ,`L o e ,y4 / / a 0 o ,b1 o ,y0 o ,b9 o k0 o ro 0 O ,y4 o ,b0 JOB NAME: Oooguruk Drill Site LOCATION: Protracted Section It Township 13 North Range 7 East Cmiat Meridian DESCRIPTION: Conductor As -built Plan / 1 0 h o h o h e o ro 0 O ,y4 JOB NAME: Oooguruk Drill Site LOCATION: Protracted Section It Township 13 North Range 7 East Cmiat Meridian DESCRIPTION: Conductor As -built Plan / 0 o ryh o ,bry o ry1 o ,y4 o ,b0 'h0 JOB NAME: Oooguruk Drill Site LOCATION: Protracted Section It Township 13 North Range 7 East Cmiat Meridian DESCRIPTION: Conductor As -built Plan / O o ryh o ry6 o ry1 o ry0 o ry0 M° .e �R:rl L ii � 6M14'"nro,wa�. 7u r �l4' ?4A. Location Map 'PR oftsrm%. \P_� DRAWN BY: Bt. SCALE: I"-30' DATE: 7-12-07 NANUQ JOB NO. 05204 I of -Basis of Location DS -3H West Monument Coordinates N 6001016.61 E 498081.23 Ref. Lownsbury & Assoc.l Drawing No. NSK 6.01—d672 Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL ICHECKED 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 00 �� Ir I f � i .'%0islrict�Bvundr 1 - 'y I SE Corner o OOOGURUK SITE Protracted Section" 11 m aE o� " �� Coordinates > rt N 6028111.04 o r E 470989.01 �— Ref. AK BLM Harrison. Bay Tract! 1-24014 mss,,Record rowingl..— %, j ' %X» t v I nC' Offshore kerood=5.99 kilos w Near Shore Iurood-3.112 MR Ph13 v Pl 2020 to��ruk SReSC PI 7 to P:. P! 14 Q� .PI—�V i� PI 1613 -,PI-17 Tundra kerne ;XV DS 3N B.O.P. Roads to ldo 1 PI gPI t9 % s I T4 i 'e'�-i P, I _ wmio� Std 1 EN \;:�� _A,- iTAKED PI INFORMATION ONLY !, * -Basis of Location DS -3H West Monument Coordinates N 6001016.61 E 498081.23 Ref. Lownsbury & Assoc.l Drawing No. NSK 6.01—d672 Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL ICHECKED 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 Well No_ Alaska State Plar, -- __ _ Y X - Latitude (N) -- Longitude (W) Section - FSL Line et - FEL _ Pad Eiev. 16,031,151.32 469,920.45 70 2946 24150 150 14 45-464G8 3035 1077 13.50 6, 031,146 35 469,915.52 7 - 29 46 19252 150 14 45 60922 3030 1 q82 -- 13,59 3 6,031,141 39 469 910.59 70 29 46 14354 150 14 45 75375 3025 1087 9 3.50 4 6,031,136.46 469,905,67 7Q 29 46.09-485 150 14 45.89799 3020 1092 13.50 5 8,931,131.45 469,900.74 70 2946.04536 15014 46.04252 3015 _ 1097 _ 13.59 -- 6 6, 031,126.51 - 469, 895, $0 70 29 45.99650 150 14 46.18735 3010 1102 13.50 6,031,113.73 469,883. 18 70 29 45.870.39 150 14 46.55879 2997 11.15 13.50 8 5,031,108 73 469 878.21 70 29 45.82102 150. 14-4-617(1303 70303 2992 1120 _ '13.50 9 6,031,103.75 -- -- - - - 469, 873,26 70 2.9 45,7718-4 150 14 46.8481-4 2987 1125 13.50 0 6,031,098.79 469,868.36 70 29 45.72286 159 14 46.99179 2962 13.50 11 6,031,093.84 469,86139 70 29 45.67356 1501.447.13750 2977 1135 13.59 - - 12 6,031,088.87 -- - 469,858,47 70 29 45.62490 150 14 47 28174 29721W 13.50 1 6,0- 076.06 469,845,s1 70 29 45.4$840 150 14 47.65288 - 29.60 - -- 1152 - 13.50 14 6,031,071.09 469,840.57 70 2.9 45.44932 150-14-47.7977-0 _29-5-5-11-57-13.6-0 15 6,031,066.15 469,835.96 7029 45.40053 _f50_14_47-.94106__295_0___. 501447.941652950 1162 13.50 10 6, 031, 061,18 469, 831,04 70 29 45.35145 150 14 48.08588 2948 1167 13.50 17 6,031,056.25 469,826,11 702945,30277150-114-4- $,23042 1172 13.50 _2949 1$ 6,031,051.27 469,821,18 70 29 4525359 1,50144 .5 37495 2935 1177 13,50 19 Call,03$,52469,808,50 70 29 45.12768 130 14 48 74668 2922 1189 13:54 --- - 2Q 6_,0__3_1_,033.50___ - 46--9,803.59 70 - - 29 45 07811 150 14 48.89061 2917 1194 13,50 21 6,031,028.53 469,798 62 7029-99-. 45.02903 150 14 49 03632 2912 1113,50 22 - 6, 031, 023.58 469, 793, 67 76 29 44.98014 150 14 49,18144 2907 1204. 13.50 23 6, 031, 018.57 469, 788.76 70 2944 03067 15014 49. 32837 2992 1299 13.57 [24-1-0,031,013.60 469,7$3-84 7029 44 88159 150 14 47 46060 2893 121 13.50 OF A0111 •• 9 Philip G. Davis No.411" .?0;T3St0 Notes: 1, Devotions are based on BP Mean sea Level. 2, coordinates are based on Alaska Stats Plane• Nad 27, Zone 4. 31 All conductors are within Protracted Section 11. JOE NAME: QQQguruk Dr=ill Site CQnductors LOCATION, P=rotracted section 11 iawnship 13 North Range 7 East Umiat Meridian Pioneer Noturol Resouces DRAWN BY; BL SCALE: N/A CHECKED DY; MJQ DATE; 7=12=07 1 DESCRIPTION: As -built Coordinates 05.204 1 3 of 4 Well No. Alaska State Plar Y X Latitude (N) Longitude (VA Section FSL Line Offset FEL Pad Elev. 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, 928.86 70 29 45.86887 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 33 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 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 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 13.50 41 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 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 45 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 29 44.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 s�Q�' •°°...�,°'• ,°rf• Q® Phr 1 °•�0 wj 4 T • • �� ®°, ,9 iI�G:Do�ie vy 4NO.411" : �a� d IfFyF°.sow 1 °pgoF •"•" `rte° o SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY SUPERVISION AND THAT I BELIEVE THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS SUBMITTED TO ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors LOCATION: Protracted Section 11 Township 13 North Range 7 East Umict Meridian DRAWN BY: BL CHECKED BY: MJD, SCALE: N/A DATE: 7-12-07 NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 Pagel of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 13, 2009 8:40 AM To: 'Franks, James' Subject: RE: ODSK-42 (PTD 209-120) James, Thanks for the spider plot. It is OK for what 1 use it for. A similar plot with any PTD is great if you can come up with one. As for pressure testing the liner lap..... there really is no need to do that as you mentioned. Assuming the liner cementing goes as planned (lap is fully cemented) lets forego that step. Oh.. James you didn't forget the variance for the diverter. I read the cover letter again and your request is there!I Sorry about that. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Franks, James [mailto:James.Franks@pxd.com] Sent: Monday, October 12, 2009 4:32 PM To: Schwartz, Guy L (DOA) Subject: RE: ODSK-42 (PTD 209-120) Guy, Here are 2 plots, one in letter size and one in plotter size, to show the layout of the wells as looking at them from above (or below I suppose (D ). Let me know if this addresses what you are looking for. Now that we are getting more wells into the pattern, should we include this plot with the PTD package? Thanks! james James Franks Pioneer Natural Resources Alaska 907.343.2179 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 12, 2009 10:50 AM To: Franks, James Subject: RE: ODSK-42 (PTD 209-120) James, Thanks ... forward the spider map when you can. I have one more question... I assume you will be testing 4.5" liner lap . I didn't see that in the outline of steps. 10/13/2009 Page 2 of,,,), Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Franks, James [mailto:James.Franks@pxd.com] Sent: Friday, October 09, 2009 5:45 PM To: Schwartz, Guy L (DOA) Cc: Vaughan, Alex; Johnson, Vern; Hazzard, Vance; Delmonico, Joe Subject: RE: ODSK-42 (PTD 209-120) Guy In the current pattern of wells, in the injection interval (Kuparuk) the closest well is the ODSK-41 well as indicated on the permit request. In fact, this injector is being placed to hopefully support that producer. I will find a picture illustrating this and get it to you. The Nuiqsut delineation tail leg will be cased off, cemented and a bond log performed to ensure isolation between the Nuiqsut and the Kuparuk. We are not planning to use this wellbore as an injector for the Nuiqsut, but there will be wells in the reservoir in the future around this penetration. Thank you very much for catching that we left off the diverter waiver request while drilling the surface hole. I offer no excuses for this omission. We certainly would like to have a diverter waiver for the surface hole of this well based on the logs the AOGCC has on file and historically there has been no indication of shallow gas or hydrates in our development pattern. Thanks for your help. Please let me know if you would like to see a new letter with the diverter waiver request added. Have a nice weekend. james James Franks Pioneer Natural Resources Alaska 907.343.2179 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, October 09, 2009 4:41 PM To: Franks, James Subject: ODSK-42 (PTD 209-120) James, I am reviewing the PTD for ODSK-42. I didn't see any mention of a AOR (area of review) for this injector. Lets talk on Monday about this. I don't have a spider map of wells in the package either so can't tell where the '% mile area around this well will intersect other wellbores. Also, do you guys have a waiver for no diverter on surface hole?? Talk to you Monday, Guy Schwartz Senior Petroleum Engineer AOGCC 10/13/2009 6050000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 5950000 4%u1I1I1I11 5850000 400000 500000 600000 700000 PIONEER P -MOoopuruk Oevebpmnd 9W: Ooopuak d9l Sih �\ 1 1800 ff. TRANSMITTAL LETTER CHECKLIST WELLNAME C,CZ'� r�t� VL �►�� �`� PTD# l2 Development Service Exploratory Stratigraphic Test Non -Conventional Well //// FIELD��x� ru / POOL: L/u�� [—G C �— s� X r 6tl� 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 wellbore segment of existing well Permit No. API No. 50- _ (If last two digits in 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 / iniect 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 (Company 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 OOOGURUK, KUPARUK OIL - 576100 PTD#:2091200 Company PIONEER NATURAL RESOURCES ALASKA INC_ _. Initial Class/Type Well Name: OOOGURUK KUP ODSK-42 Program SER Well bore seg ❑ SER / 1 WINJ GeoArea 973. Unit 11550 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well in ADL 355036 3 Unique well name and number Yes 4 Well located in a defined pool Yes Oooguruk-Kuparuk Oil Pool - governed by CO 596 and AID 33. 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate. bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 10/8/2009 14 Well located within area and strata authorized by Injection Order # (put 104 in comments) (For Yes AID 33 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre -produced injector: duration of pre -production less than 3 months. (For service well only) Yes 17 Nonconven. gas conforms to AS31.05.030Q.1.A),0.2.A-D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No USDW .. AID 34 Conclusion 3 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons Yes 4 1/2" Liner to be cemented across Kuparuk and Nuigsul. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re -drill, has a 10403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity ananlysis performed. Close approach to ODSK-41 at 420' and 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in area. 20 AAC 25.035(h)(2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum fm pressure is 3246 psi (9.7ppg) Dirlling with 10.5 ppg mud 4 ht P D GLS 10/12/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2538 psi Testing BOP to 4500. psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S not reported at Oooguruk Drill Site. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) ° AOR performed. No wells with 1/4 mi except producer ODSK-41 in (Kuparuk producer) 35 Permit can be issued w/o hydrogen sulfide measures Yes iz. z„�1one anticipated, but H2S monitors will be. used. Scavenger chemicals will be available. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 9.8 ppg EMW; will be drilled using 10.5 ppg mud and Appr Date 37 Seismic analysis of shallow gas zones NA managed pressure drilling techniques. SFD 10/8/2009 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering P blic Commissioner: Date: Com issione . Date Com - Date
