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210-140
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c 210 - I 14- Q Well History File Identifier Organizing(done) ❑ Two-sided 11 111111 III II III ❑ Rescan Needed III 11111111 1 III III RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: 2ceyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 3/cQ I /s/ le Project Proofing IIIIIIIIIIIIIIIIII • BY: lap Date: • /s/ Scanning Preparation a x 30 = 100 + 1 9 = TOTAL PAGES —7-7-- BY: MD Date: (Count does not include cover shee _ /s/ u Production Scanning 111111111111111111 Stage 1 Page Count from Scanned File: Zr0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: AIM Date: 3/a f Lip /s/ rviF Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 111111 11111 II III ReScanned 1 111111 11111 1 1111 BY: Maria Date: /s/ Comments about this file: Quality Checked IIIllhIIIIII I11111 o C 0J o a � o i� lid y < Q z z `4 rn - z N CO H H f0) N ja W J U U U U 3 J N z = O Ce >� > o a W C) W W �I M _U a� O U > > W W a) a).5 O Q o II" C t W W Li- N co Et to N A E U fa_ R' CY 0 0 N N a '0f o to E g o) O O O O CO m o !, o '8 U �,_ O O O O O O m la.- W a ° tL z o wF- 2 0 F- ¢ �¢ it 2 2 2 2 Q 0 0 o 0 0 0 o O O 0 0 0 0 o ao •d o 0 0 0 0 0 0 0 0 0 0 < J U N V N N N N N N N N N N N P. a) N N N N N 0) Q) O) O) O) O) en R o N N N N N N N N N N N W• r J r NN N N N N 43 w E r r r r r r C • 7 O`w. c C C C c C c c c c cm c = = a a a a a a s a a a a/� W N yOUO O O O O O O O O O O :C111:1) LL c :°O g ' f0 «O ° O0) O0) N N C) O Ill 0)) C) 00)) off) d'p OO OO OO O O Oa�"'/� H UZ N NN N O ON N N N N N NI.I ZCC I C OfA ap0 a) a) f10o Wopo 1700 W apoCD N W r.3 Lo rrOO r rrrpWO O J > N Z d O 4) o `o , mol, I`- � I z y a a 1 to O I o 0 5 0 0 0 0 0 .c N c ; U U U 0 U U U U o N o ZJ a) ca I d a a) a)la N N (n N N N (n U N -' Cl) r r ci) J -J Q (Ni,z In II "'_ O oZ _ co 2O (N U Z CO Y N9 c O C Q t' W 0 074. Q O D p rn ▪ 0 w I- • a) ce ZI CZ > w w w Q CZ oEo ..> > > w> N IB— C QdU 0 O ,n Nw i a > > E I J m , N a) N a' U))U )) 1V Z j Q U)) !� cc cc c c 2 I C C C C C it m O m C) y d l 0 O O O O J J o o • o jl c E L v o o E rn a 101 > > > > a s v v v v o CND I Z c c c c c CC Ce 2 2 2 2 1 j 0 w, � j E v. O I ` ... y £ c8') (l C O Q z t C --'5 7 N N < ''. w o W O Z U) (n NCL O y 0 Q c o a y c OLL o c E m E I5 a 1• N � re o_) J a y Z 'U • N ? a w J o1 N \ \ \ \K ,, \\ U Z m t _ • O W a a -y °)`.� a 0 0 0 0 0 a O o 0 0 0 d J s. FT- W J J J J a W J J J J L__J o Q II T O N Nrl c0 O Z CIII r> 0 l o O O N C Z d J Q J 1 w cn O I ✓• N 11 O a)a, Iv luI LU U) I Et re C O g a, 7 Z Om M U } 11 L11 z Ce re w v La ill V a Q-J I a) ,, '� a a Z Z' F_- Q a, 7 y O J a. _ co 0 coE ° o ci . 7:7.; iii 1 a co• _ E V0 1 J -J ;I iiooNN N I— Oo ,Iirs.:,I Q a Z E O d U E co Z a, 3 0 ' I rn 11 CO I Z O Oj HI CcN_ p zJ >CI LC) a, I;U P• '� �' C rN O N U yco e- i U 0 ? ' E •G a O m 0- co 1 E E a ¢ 0 Q a U U PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: December 27, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Reports X Other- Logs ❑ Agreement DETAIL QTY DESCRIPTION 4 End of Well Reports ODSN-16 (API: 50-703-20620-0000) ODSN-16L1 (API: 50-703-20620-6000) 16 Well Logs ODSN-17 (API: 50-703-20622-0000) ODSN-17L1 (API: 50-703-20622-6000) 4-Engineering Logs, 4-Gas Ratio Logs, 4- Formation Evaluation Logs (2"& 5") We request that all data be treated as confidential informati W\ , -� ) -o--,• 2 ? Received by: 6,5 Data , :71,M�;¢A Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax d r O-O 4 •6-7--3. 907-343-2128 phone aro - tin 0-05?-5- pro-66-9 -05?-5-aro-O6 0-oS1'9 _ co -cS4-r aa' b 0 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: November 10, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter o Maps ❑ Report X Other—logs, CDs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-17 (API: 50-703-20622-0000) ODSN-17L1 (API: 50-703-20622-6000) 2 CD-Roms LWD Final Processed Data (digital graphic logs, digital data) 8 Well Logs 8 Well logs DGR, EWR-Phase 4, CTN, ALD, Horizontal Presentation (1:600, 1:240) MD,TVD logs DGR, EWR-Phase 4, CTN, ALD, Invert/Revert Sections(1:600, 1:240) MD, TVD logs We request that all data be treated as confidential inforraftlignkvc Received by: 0-• Date: Please sign and return one copy to Pioneer Natural ResdiftetAilt., ATTN: Shannon Koh oto `�3 � ) 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 9 'o '&0399 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 Exploratory❑ GINJ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: _One Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Pioneer Natural Resources Alaska,Inc. Aband.: 10/23/2010 210-140 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 10/11/2010 50-703-20622-60-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2940'FSL, 1172'FEL,Sec. 11,T13N,R7E,UM 10/14/2010 ODSN-17L1 Top of Productive Horizon: 8.KB(ft above MSL): 56.2' 15.Field/Pool(s): 4100'FSL,3881'FEL,Sec. 15,T13N,R7E,UM GL(ft above MSL): 13.5' Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuiqsut Oil Pool 4491'FSL,4418'FEL,Sec.23,T13N,R7E,UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 469826.11 y-6031056.25 Zone-Asp 4 20,952'MD/6290'TVD ADL 355036/ADL 355037 TPI: x- 461824.64 y-6026973.57 Zone-Asp 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 466551.27 y-6022070.04 Zone-Asp 4 2007'MD/1960'TVD 417497 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/I-VD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 854'MD/831'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: ABI, DIR, RES,DGR,ALD,CTN, PWD 14,180'MD/6197'TVD 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven 11-3/4° 60# L-85 HYD Surface 4660' Surface 3285' 14-1/2" 600 sx PF'L;665 sx Class'G' 9-5/8" 40# L-821 52 YD 4497' 10,978' 3231' 5365' 11-3/4" 616 sx Class'G' 7" 26# L-8OBTC Surface 10,844' Surface 5320' 8-1/2" Tie-back 7" 26# L-80 HYD 10,830' 14,106' 5316' 6186' 8-1/2" 230 sx Class'G' 4- 6 66/ V;_, S 4-1/2" 12.6# L-802HYD 13,953' ✓ 20,940't' 6159' 6290' 6-1/8" Uncemented V' f�c- .l,zz.ic 24.Open to production or injection? YesU NoU If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 2-7/8",6.5#, 13,753' Hydrow II Pkr @ 2633' L-80, IBT-M MD/2465'TVD See Attachment, Pg.3 wrWr (.4,4 ' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ,..J G '' e DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED = + 2100' Freeze protect 11-3/4"x 7"annulus w/140 bbls diesel I. .__. E . _ 4 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 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 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No Q Sidewall Cores Acquired? Yes❑ No 2 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. RECEIVED' None NOV 1 7 2010 iiaska i!&Gas ions.ecrafenkoo Anchorage Form 10-407 Revised 12/20095 NOV 19 �' CON,INUED ON REVERSE S I ina only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 838' 837' and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1692' 1668' Top West Sak 2408' 2300' Top Torok 9797' 4978' None Top HRZ 12,244' 5750' Top Kuparuk C 13,235' 6009' Top Nuiqsut 14,061' 6178' Formation at total depth: 20,952' 6290' 31. List of Attachments: Summary of Daily Drilling Operations,Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan,343-2186 Printed Name: Alex Vaughan Title: Operations Drilling Engineer 1P17- Signature: Phone: 343-2186 Date: 11/17/2010 Well Name:ODSN-17L1 Per it No.:210-140 Prepared By:Kathy Campoamor,343-2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 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 Natural Resources Alaska Inc. ODSN-17L1 Page 3 Form 10.407, Well Completion or Recompletion Report and Log Attachment - Box #24 /rp Z/o -No N-17 L1 Zones open to production or injection Casing Description:4-%", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/six 1/2" Holes @ depths listed below Top(MD)(ftKB) Btm(MD) (ftKB) Top(TVD)(ftKB) Btm(ND) (ftKB) 14,059 14,063 6,180 6,181 14,274 14,279 6,212 6,213 14,544 14,548 6,219 6,219 14,762 14,767 6,218 6,218 14,967 14,971 6,213 6,213 15,174 15,178 6,213 6,213 15,376 15,381 6,221 6,221 15,581 15,586 6,224 6,224 15,782 15,787 6,220 6,220 15,988 15,993 6,217 6,217 16,210 16,215 6,219 6,219 16,415 16,420 6,228 6,228 16,619 16,624 6,237 6,237 16,824 16,828 6,244 6,244 17,029 17,033 6,245 6,244 17,236 17,241 6,235 6,235 17,442 17,447 6,231 6,231 17,647 17,652 6,228 6,228 17,851 17,856 6,244 6,244 18,053 18,058 6,254 6,254 18,275 18,280 6,252 6,252 18,480 18,484 6,240 6,240 18,683 18,688 6,235 6,235 18,886 18,890 6,244 6,244 19,090 19,095 6,255 6,255 19,297 19,301 6,266 6,266 19,501 19,506 6,262 6,262 19,702 19,707 6,258 6,258 19,908 19,912 6,256 6,256 20,115 20,119 6,247 6,247 20,321 20,326 6,256 6,257 20,525 20,529 6,270 6,271 20,729 20,734 6,279 6,279 20,894 20,898 6,288 6,288 ti - Pioneer Natural Resources Alaska Inc. ODSN-17L1 Page 3 Form 10-407, Well Completion or Recompletion Report and Log Attachment - Box #24 24. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner II' Perforated Pups w/ 6-1/2" Holes © depths listed: MD TVD 7,265' - 7,270' 4142' - 4143' 8,077' - 8,081' 4411' - 4413' 8,946' - 8,951' 4695' - 4697' 9,563' - 9,568' 4902' - 4903' 9,964' - 9,968' 5032' - 5034' 10,574' - 10,579' 5232' - 5234' eDe1. oi .,10,977' - 10,982' 5364' - 5366' '" 11,182' - 11,186' 5430' - 5431' 11,782' - 11,786' 5621' - 5622' , = '` 1 11,988' - 11,992' 5679' - 5680' ±I =yJ 12,815' - 12,819' 5905' - 5906' '' 13,220' - 13,224' 6006' - 6007' 13,623' - 13 .27' •e•6' - 6096' 14,025' - 14,030' 6172' - 6173' 14,431' - 14,436' 6219' - 6219' 14,839' - 14,844' 6215' - 6215' 15,244' - 15,248' 6214' - 6214' 15,646' - 15,651' 6222' - 6222' 16,050' - 16,055' 6216' - 6216' 16,454' - 16,459' 6229' - 6229' 17,273' - 17,277' 6233' - 6233' 17,680' - 17,685' 6229' - 6229' 18,085' - 18,090' 6254' - 6254' 18,487' - 18,491' 6239' - 6239' 18,889' - 18,894' 6243' - 6244' 19,256' - 19,261' 6264' - 6264' 19,501' - 19,506' 6262' - 6262' 19,702' - 19,707' 6258' - 6258' 19,907' - 19,912' 6256' - 6255' 20,114' - 20,119' 6247' - 6246' 20,321' - 20,326' 6256' - 6256' 20,525' - 20,529' 6270' - 6270' 20,729' - 20,733' 6279' - 6279' 20,894' - 20,898' 6287' - 6287' r ,aerations Summary Report - Stat0 PIONEER NATURAL RFSOURCFS Well Name: ODSN-17 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 8/25/2010 End Date: 10/23/2010 .. Start Depth Foot/Meters Dens Last Start Rate 'End Date =", (ftK6) , {tt) Mcid{tb/gal) /. !../i,s�ailtt�3�y .• i!y��` 8/25/2010 8/26/2010 158.0 92.00 9.20 Accept rig at 00:00 hrs,and RU same for spud on ODSN-17.Install starting head and NU drilling riser.Change out saver sub to 4.5 I.F. RU all 5"handling tools.PU 5"DP making up stands and rack back same in derrick.Racked back 43 stands 5"D.P.Racked back 5 stands 5"HWDP with jars.Stage BHA tools on rig floor and RU Gyro survey tools.PU 14-1/2"bit#1,mud motor,X-O subs,and ABI tool.Ream f/56't/158'to clean out 16"conductor.Drill 14-1/2"hole f/158't/250'. POOH f/250't/36'.TIH making up BHA#1 as per directional driller f/36'1/172'.Wash down f/172' t/250'without rotary. 8/26/2010 812712010 250 0 144; 9 20 Directional drill 14-112"hole f/250't/267'Noticed 4/70*dij itiyrp tool fates . line."Reseat Gyro survey 2 more times with same 0sult PQ0 ft'o and ch « :It10411-- gg.,44:4;' Good surveys. Rerun Gyro again with same result P)OH ,surfaoech'eckl ;'. o;; F nentation.Found scribe tnark to be offs brstjamately 70*.TIl*surface t/267'.Directirana i42holef/267t87T 8/27/2010 8/28/2010 1,677.0 1,223.00 9.40 CBU at 1,677'while rigging down Gyro equipment.POOH f/1,677'1/1,201'.PU and make up EM repeater assembly f/1,201'1/1,232'.TIH f/1,232't/1,677'.Directional drill 14-1/2"hole f/1,677' t/2,469'.Pump 50 bbl hi-vis sweep and CBU 1.5x at 2,469'.POOH f/2,469'1/1,613'.TIH f/1,613' 1/2,279'.Reciprocate pipe while working on hammer mill.TIH f/2,279't/2,469'.Directional drill 14- 1/2"hole f/2,469'1/2,900'. 8/28/2010 8/29/2010': '9,50Directional drill 14-1/2"hole f/2,900413516',CBU"at'3;518'.POOH f/3 516't/2,469' •` ®� and top drive.TIH f/2,469't13,516.Directional drill 14-112 hol ff3,516 1/4 4F,3'f,� 8/29/2010 8/30/2010 4,423.0 247.00 9.50 Directional drill 14-1/2"hole f/4,423'1/4,670'.Circulate the hole clean with 2-50 bbl hi-vis sweeps.POOH f/4,670'1/170'.TIH f/170'1/4,670'.Circulate the hole clean with 2-45 bbl hi-vis sweeps.POOH f/4,670'1/1,327'.Lay down EM repeater assembly.POOH f/1,201'1/172'.Lay down 14-1/2"BHA f/172'1/surface.RU 11-3/4"casing equipment.Gave 48 hr notice to AOGCC of upcoming BOP test. 8/30/2010 8/31/201 41670,t1 940 RU 11414*:'acing equipment.Held pre lob safety meeting for rtatrting casing'wlth'all involved s personnel.RIH with 11-3/4"L-80 60#Hyd 521 casing f/surface `7'Repair hydraulic line on _ Casing;tongs.RIH with 11-3/4"L-80;60#Hyd 521 casing.f2,247 up toplMU landing-jaint and land casing f/4,615't/4,659.8'.RU'cementhrlines,Sage uprIgpum py4, to 12 bpm and circulate hole clean.Attempt to switch'Aver,to• 0,7pr,cement job hydrauliei ' ztn cement mixer not working.Circulate at 5 bpm white waiting • Rump truck, 8/31/2010 9/1/2010 4,670.0 9.30 Circulate at 5 bpm while waiting on HES cement pump truck.Stage up pumps to 11 bpm and CBU.Circulate at 5 bpm while off loading and RU cement pump truck.Held pre job safety meeting with all involved personnel,begin pumping cement job as per cement program,pumped all of spacer,and 392 bbls lead cement.While mixing tail cement the cement mixing tanks flash set.Bring rig pumps up pumps to 10 bpm and displace cement out the hole with 9.4 ppg WBM. Slow down pumps to 4 bpm with cement retums back to surface in order to not out run CCU pump.Circulate at 5 bpm while waiting on cement unit to be barged out.Off load and RU cement unit.Circulate at 5 bpm while cleaning set up cement from RSC injection pits. 9/1/2010 9/2/2010 4,670.0 9.20 Circulate at 5 bprtt while cleaning set up cement from,R ifije t,R R040,P111p bpm in 1 bbllncrements'--hole`packed off.Cut pumps bBojC3n bR t p1ttpteapack Stage pumps up in 1/4 bbl increments.Max rate achievable:is 6 b' R 1 ny pack ciff&frl,', events.PJSM w/all involved personnel.Swap over to HE .,,pump!` R RIs eawater,release`1st; ,. bottom plugand kick Out wl last 2 bbls,test lines to 4000 fiat Loan sp,.plug,pump 60'bbls " ppg spacer,pump 442 bbls(600 sx)Lead Permafrost L'cement at 10.7 ppg(uv/yield of 444,).. Pump 145 bbls(665 sx)Tail Premium'G'cement at 15.8 ppg(w/yield of 1.19).Release tOpplug -Kick out w/20 bbls seawater.Displace w/9.4 ppg spud mud using lig pumps 6 bpm,1210 psi,-- Hole packed off and lost returns.Slow rate to 1 bpm to attempt to regain circulation unsuccessful.Attempt to reciprocate pipe to gain returns unsuccessful.Unable to resent casing hanger.Returns came back with 312 bbls of mud p aped Icement returns to surface, Cement set up in casing and was unable to bump plug sure up to 4600 psi 80%of casing burst.Needed 495 bbls to bump but could only pump'374 bbls leaving 121 bbls of cement • ' inside the casing.CIP at 20:20 hrs.Check floats--holding.RD cement head and lines and blow down same.LD landing joint.Flush cement from drilling riser with citric.acid,pills. . ' Page 1/7 Report Printed: 11/11/2010 PI 0 N E E R aerations Summary Report - Stats. NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) {ft) Mud(lb/gal) Summary 9/2/2010 9/3/2010 4,670.0 0.00 9.30 Flush cement from drilling riser with citric acid pills,and split riser to break up cement with water hose.ND and lay out drilling riser.NU drilling spool and test same to 5000 psi--Good test.NU drilling riser and BOP stack.Install trip nipple and secure stack with turn buckles.Perform body test on BOPE to 3500 psi on chart for 5 min--Good test.PU 10-5/8"BHA#2 f/surface 11590'. TIH f/590't13,380'--tagged top of cement.Drill cement f/3,380't/3,600'. 9/3/2010 9/4/2010 4,670.0 0.001 ik 9.50 Drill cement f/3,600't/4,588'.Attempt to test casing to 35001st af4,588`.Pressure up'on casing and pumped in at 2600 psi.Pressure bled back to 1500 psi. •Retest--max achieved pressure ® was 1800 p 1i .Test all surface equipment to 2600'psi--Good test.Perform"mock"formation 4 . , L.O.T.OT :at 4,660'MD/3,285'TVD with a 9.7 ppg mud. Leaked off at 1050 psi and stabilized at z 1000 psi EMW of leak off=15.55 ppg.CBI.)1.5 times at 4,588',POOH f/4,588't/590`. Tested choke mentf• t?.t lieF e,e AOGPC ret John Cnsp witnessed test.Rack back HWDP and lay down B i 9/4/2010 9/5/2010 4,670.0 0.00 9.50 TOOH and LD 10-5/8"Milltooth Bit and Mud Motor. Remove wear bushing and install test plug. RU testing equipment.Test Annular to 250 psi low/2500 psi high with 5"DP.Test Upper and Lower 2-7/8"x 5"VBR's,Blind Rams,Choke and Kill Line NCR's,Choke and Kill Line Manual valves, Floor Safety valve,Dart valve,Upper 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 2000 psi,Initial 200 psi recovery 26 sec's,Full recovery 1 min 39 sec's.Test witnessed by AOGCC Field Inspector John Crisp.RD testing equipment.Pull Test Plug and Install Wear Bushing. PU 11-3/4"RTTS and TIH to Test Casing. Planned to test casing in joint above FC @-4550'md;however,experienced excessive drag while TIH with RTTS at 3719'MD. Unable to get RTTS to set in casing between 3243'and 3719'MD. TOOH with RTTS and PU Clean Out Assy with PDC bit. 9/5/2010 9/6/2010 4,670.0 0.00 10.00 Finish washing and reaming t/4588'and to remove cement sheath from inside 11-3/4"casing, Circ weighted hi-vis sweep and cleaned cement cuttings from wellbore.TOH(/4588't/2374'and and TIH while PU 69 joints of 5"drill pipe.TOH and LID Clean-Out Assy. • 9/6/2010 9/7/2010 4,670.0 28.00 10.00 POOH f/3896'to the BHA at 567'.POOH laying down BHA f/567't/surface.PU RTTS and RIH on HWDP t/370'.TIH f/370't/4,550'.Circulate 10 bbls around RTTS and set same with 20k down.Test casing to 3500 psi on chart for 30 min--Good test.POOH f/4,550'1/370'.POOH racking back HWDP and lay down RTTS f/370'U surface.PU directional 10-5/8"BHA f/surface 1/650'and shallow pulse test same.TIH f/650't/4,588'.Drilling cement and float shoe f/4,588' t/4,670'.Drill 10-5/8"hole f/4,670't/4,690'.Perform F.I.T.at 4,659'MD/3,285'TVD with 10.0 ppg WBM to 1003 psi for EMW of 15.87 ppg.F.I.T.was witnessed by AOGCC rep John Crisp.Drill 10-5/8"hole f/4,690'114,698'. 9/7/2010' 918/2010 4,698.0 1,552.00 10.00 Directional drilling 10-5/8"hole#14,698't/4,770'.Drop 1-5/8"ball and pump ball on seat and sheer ball seat to engage under reamer cutters.Raise pump rate to 750 gpm to fully expand cutter blades and pull 10k against formation to ensure cutters engaged.Directional drill 10-5/8' hole f/4,770't/5597'.Change out#2 swab on#2 mud pump.Directional drill 10-5/8"hole f/5,597r t/6,250'. . ., 9/8/2010 9/9/2010 6,250.0 1,490.00 9.85 Directional drill 10-5/8"hole f/6,250't/7,740'. 9/9/2010 9/10/2010' >7 740.0 1,065:00 ' 9.80 Directional drill 10-5/8"hole f/7,740't/8,565'.Circulate with#1 pump while changing out swab and liner on#2 pump.Circulate with#2 pump while changing valves and seats in pump#1, ' Directional drill 10,518"hole f/8,565't/ 805'. 9/10/2010 9/11/2010 8,805.0 895.00 9.80 Directional drill 10-5/8"hole(/8,805't18,847'.Service rig and top drive while changing out 0-ring seal in stand pipe hammer union in PUTZ.Directional dril 10-5/8"hole f/8,847't/9,155'.Change out swab and liner on pump#2.Directional drill 10-5/8"hole f/9,155'119,700'. 9/11/2010 9/12/2010 9,700.0 1,228.00 - .. 9.75 Directional drill 10-5/8"hole f/9,700'1/10,683'.Circulate at reduced rate while trouble shooting sync issues with#3 generator after losing high line power.Directional drill 10-5/8"hole(/10,683' t/10,833'.Function test BOPE as per AOGCC PTD=-All functioned properly.Directional drill 10- • 5/8"hole f/10,833'1110,928'. Page 2/7 Report Printed: 11/11/2010 PIONEER ,aerations Summary Report - Stat_. NATURAL RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(lb/gal) Summary 9/12/2010 9/13/2010 10,928.0 52.00 9.80 Directional drill 10-5/8"hole f/10,928't/10,980'.Circulate the hole clean with 2x 45 bbls hi-vis, weighted sweeps at 12.4 ppg and make 400 bbl whole mud dilution with clean 9.8 ppg mud. Once hole was clean the derrick man was sent up to the monkey board and it was noticed that the board was damaged from the elevators being kicked out and striking the board as it went up past the board.Assess the damage and determine it is not repairable. Circulate and condition mud for one surface to surface volume every 6-8 hours to ensure mud properties are in spec for running casing. Monitor well while waiting on new monkey board to be fabricated in Dead Horse. 9/13/2010 9/14/2010 10,980.0 0.00 9.75 Monitor well while waiting on new monkey board to be fabricated in Dead Horse.Circulate and condition mud while pumping one surface to surface every 6-8 hours to ensure mud properties are in spec for running casing.Shut annular preventer and monitor well while prepping derrick to install new monkey board.Circulate and condition mud while pumping one surface to surface every 6-8 hours to ensure mud properties are in spec for running casing.Shut annular preventer and monitor well while installing new monkey board. 9/14/2010 9/15/2010 10,980.0 0.00 9.85 Shut annular preventer and monitor well while installing new monkey board.Perform magnetic particle inspection on all welds--All welds passed inspection.Circulate and condition mud with 2x bottoms up.POOH f/10,960't/5,512'.Attempt to circulate at 5,512'--packed off,work pipe free and use step rate method to establish circulation. POOH f/5,512't/4,677'. Establish circulation with step rate method up to 700 gpm and pull test Rhino reamer against casing shoe with 10k over P/U wt--Good test.Circulate hole clean with 3x bottoms up strokes.Pump out the hole f/4,677't/2,393'. 9/15/2010 9/16/2010 10,980.0 0.00 10.20 Pump out of 10-5/8"hole f/2393't/681'.Pump 30 bbls H.V.sweep around.Cut drilling line. POOH. LD BHA#6.PU BHA#7.Function test Rhino reamer.RIH t/4685'.Pull test reamer at shoe w/10k over. RIH 010885'.Circ hole clean.Open hole to 11-3/4"f/10885't/10969'(bullnose at 10,980').Pump H.V.sweep around surface to surface. NOTE:Notified AOGCC at 00:15 hrs on 09/16/10 for upcoming BOP test.At 00:30 hrs on 09/16/10,AOGCC Rep.Bob Noble waived witness of test. 9/16/2010 9/17/2010 10,980.0 0.00 10.30 Circulate H.V.sweep surface to surface. POOH f/10,980't16,170'. RIH t16,243'.CBU. POOH f/6,243't/4,763'.Pump H.V.sweep surface to surface.Pull test rhino reamer at shoe.Pump out of hole f/4,763't/956'.Troubleshoot Top Drive link tilt problem.Continue pump out of 10-5/8" hole f/956't/BHA at 577'.LD BHA.RU to test BOPE. Install test plug. Perform Accumulator Draw Down Test: -System pressure=3000 psi -Closure pressure=2000 psi -17 seconds to obtain 200 psi increase -1:57 to obtain full system pressure -5 bottles at 1700 psi avg Change bottom rams to 9-5/8"for upcoming liner run. AOGCC Rep.Bob Noble waived witness of test at 00:30 hrs on 09/16/2010. 9/17/2010 9/18/2010 10,980.0 0.00 10.10 Test BOPE per AOGCC&PXD rules and regulations.Test BOPE w/5"'test joint to 250 psi low/ 4500 psi high for 5 charted min each test.Test annular w/5"test joint to 250 psi low/2500 psi for 5 charted min each test.Test lower 9-5/8"rams to 250 psi low/4500 psi high for 5 charted min each test.Test annular w/9-5/8"test joint to 250 low/2500 high for 5 charted min each test Choke and Kill Line NCR's,Choke and Kill Line Manual valves,Floor Safety valve,Dart valve, Upper IBOP, 14 Choke Manifold valves to 250 psi low/4500 psi high for 5 charted min each test. Right to witness test waived by AOGCC Rep.Bob Noble at 00:30 hrs on 09/16/10. PU 3 DC's and 3 HWT from shed and stand back.RU&run 9-5/8"liner t/6,448'.PU liner hanger. 9/18/2010 9/19/2010 10,980.0 0.00 10.15 Run 9-5/8"40#L-80 Hyd 521 liner on 5"DP f/6,497't/10,978'(shoe depth).Drop ball and circ down. Pressure up to 3000 psi and set hanger.Circ and condition mud for cement job. Pump 10 bbls S.W.preflush.Test lines to 4000 psi. Pump 60 bbls dual spacer at 12.5 ppg. Mix&pump 128.4 bbls(665 sx)Class'G'cement at 15.8 ppg(1.19 yield).Drop DP wiper plug-Kick out w/ 17 bbls seawater.Switch to rig pumps. Displace cement w/10.1 ppg LSND mud w/9 bpm,2850 psi.Slow to 3 bpm to bump plug.Bump w/5280 stks.Pressure up to 3500 psi. Hold for 5 min.on chart. Bleed off.Check floats-OK.CIP at 1820 hrs. T.O.L.at 4,497'; B.O.L.at 10,978'.Set Liner Top packer at 4,519'.Test 11-3/4"x 9-5/8"to 3500 psi for 5 min.on chart.Good test. RD equipment. POOH f/4,467't/873' Page 3/7 Report Printed: 11/11/2010 PI 0 N E E R )erations Summary Report - StatL NATURAI RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 9/19/2010 9/20/2010 10,980.0 0.00 1.00 POOH f/873'to surface. LD liner running tool. ND BOPE,riser&drilling spool. Install wellheads &Multi bowl.Test to 5000 psi f/10 min. NU BOP&MPD equip.Change bottom rams to 2-7/8"x 5"VBR's.Test same to 250 psi low/4500 psi high for 5 charted min each test.Test choke&kill lines, MPD HCR&manual to 250 low/4500 high for 5 charted min each test. Install riser& flowline. RIH w/6 DC's&6 HWT.POOH LD same. PU 102 jts 5"DP f/shed t13,241'.Circ DP volume x 2. POOH. PU 8-1/2"drlg BHA. 9/20/2010 9/21/2010 10,980.0 20.00 10.00 PU 8-1/2"BHA#8.RIH t/10,850'.Test 11-3/4"x 9-5/8"casing to 3500 psi for 30 charted min. Good test.Tag Landing collar at 10,885'. Drill Landing Colla.Clean out to Float Collar at 10,897'.Drill same and clean out to 9-5/8"shoe at 10,977'.Drill shoe and clean out rathole t/10,980'.Drill 20'of new 8-1/2"hole t/11,000'.Circulate and displace well with new 10.0 ppg LSND mud.Perform FIT to 14.0 ppg EMW. New MW 10.0,shoe TVD=,5,372', 1120 psi=14.0 ppg EMW.Pull trip nipple. Install RCD head. 9/21/2010 9/22/2010 11,000.0 1,155.00 10.10 Install rotating head rubber. Install RCD.Fill lines and establish circ w/13 ppg EMW.Directional Drill 8-1/2"hole f/11,000't/12,155'.Maintain 13.0 ppg EMW w/MPD. 9/22/2010 9/23/2010 12,155.0 1,564.00 10.00 Directional drill 8-1/2"hole f/12,155't/13,719'while maintaining 13.0 ppg EMW w/MPD. 9/23/2010 9/24/2010 13,719.0 384.00 10.10 Directional drill 8-1/2"hole f/13,719't/14,103'while maintaining 13.0 ppg EMW w/MPD. Circulate hole clean with 2x 40 bbl hi-vis sweeps and 5x bottoms up strokes.Close annular preventer,trap 950 psi on annulus and change out RCD bearing--element went out.CBU at 14,103'. Back ream out the hole f113,977't113,590'.Work pipe to clear pack off,establish circulation,and circulate bottoms up at 13,590'. Back ream out the hole f113,590't/13,311' maintaining 13.0 ppg EMW w/MPD.Close annular preventer,trap 900 psi on annulus and change out RCD bearing--Top hydraulic seal went out.Back ream out the hole f/13,311' U13,121'. 9/24/2010 9/25/2010 14,103.0 5.00 10.00 Back ream out the hole f/13,121't/12,240'.Pump 40 bbl hi-vis sweep and circulate 2x bottoms up at 12,240'. POOH f/12,240't/10,978'.TIH f/10,978'U13,501'. Function test BOP's.Wash and ream in the hole f/13,501'U14,103'.Establish circulation,stage pumps up to 650 gpm and back ream out the hole f/14,103't/13,691'.TIH f/13,691'U14,103'.Directional drill 8-1/2"hole f/14,103' t114,108'maintaining 12.8 ppg EMW w/MPD. Pump 2x 50 bbl low-vis sweep,65 bbl 15.0 ppg weighted sweep,50 bbl hi-vis sweep and circulate surface to surface. 9/25/2010 9/26/2010 14,108.0 12.90 Pump 50 bbl low-vis sweep,65 bbl 15.0 ppg weighted sweep,50 bbl hi-vis sweep and circulate surface to surface.POOH f/14,108't/13,209'.TIH f/13,209't114,108'.CBU 2x.Circulate while making 800 bbl dilution with clean 11.0 ppg mud and raise mud weight to 12.8 using 18.0 ppg spike fluid.Monitor well--static,remove RCD bearing,and install trip nipple.Circulate and condition mud weight to 12.8.POOH f/14,108't/2,461'. 9/26/2010 9/27/2010 14,108.0 12.70 POOH f/2,461't/558'.Rack back HWDP,lay down BHA and clear rig floor of same.Remove wear bushing and install 7"test joint with test plug.Change out bottom pipe rams from 2-7/8"X 5"VBR's to 7"casing rams.RU test equipment,test bottom casing rams to 250 psi low/4,500 psi high on chart for 5 min each test. RD test equipment and install wear bushing.MU mule shoe,TIH picking up 6 jts of HWDP and rack back in derrick.RU 7"casing equipment and hold PJSM with all parties involved.RIH with 7"26#L-80 Hyd 511 casing f/surface t/3,244'. PU and MU WFT"PHR"rotating hyd hanger,"TSP"liner top packer,"PBR"tie back sleeve,running tool and bumper jars f/3,244't13,294'.TIH(/3,294't/4,436'with 7"liner on 5"drillpipe.Pump lx liner volume above 9-5/8"liner top.TIH f/4,436'U7,385' with 7"liner on 5"drill pipe. 9/27/2010 9/28/2010 14,108.0 10.00 TIH f/7,385't/10,900'with 7"liner.Establish circulation,stage up pumps to 3 bpm,and circulate while making up WFT cement head.TIH f/10,900't/14,106'with 7"liner.Stage up pumps in 1/4 bbl increments up to 4.5 bpm and circulate cutting mud weight back from 13.0 ppg to 10.0 ppg. Attempt to release setting tool from liner hanger-unsuccessful.Apply left hand torque to activate emergency release mechanism. Apply 6 rounds total of left hand torque to release setting tool. Circulate cutting mud weight back from 13.0 ppg to 10.1 ppg.Swap over to HES and Pump 10 bbls seawater preflush,test lines to 4000 psi.Pump 40 bbls dual spacer at 12.5 ppg,pump 48.3 bbls(230 sx)Premium'G'cement at 15.8 ppg(w/1.18 yield). Drop DP wiper plug-Kick out w/ 17 bbls seawater. Displace cement w/10.1 ppg mud with rig pumps. Plug did not bump. Bleed off-Check floats-OK. CIP at 22:50 hrs-Full returns for entire job.Set packer with 50k down wt.Top of 7",26#L-80 HYD 511 liner at 10,829'and liner shoe at 14,106'. Page 4/7 Report Printed: 11/11/2010 PI 0 N E E R •erations Summary Report - State NATURAL RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 9/28/2010 9/29/2010 14,108.0 10.20 Close top pipe rams and test liner top packer to 3500 psi by pumping down the kill line.Test held 30 min on chart--Good test.Circulate 1.5x bottoms up at 10,829'. No cement returns observed at shakers.Lay down WET cement head and lines.Slip and cut drill line. POOH(/10,809't/ surface laying down 5"DP. LD liner running tool and bumper jars. MU mule shoe and TIH f/ surface t/3,338'.Close blind rams and perform L.O.T.at 10,106'and/6,186'tvd. Leaked off at 1200 psi stabilized at 1050 psi for EMW of 13.2 ppg.RU 7"casing equipment and held PJSM with all involved personnel. MU tie back seal assembly and RIH with 7"L-80 26#BTC-M casing f/surface 1/106'. 9/29/2010 9/30/2010 14,108.0 ' 10.20 RIH with 7"L-80 26#BTC-M casing f/106'1110,848'. Stabbed into"PBR"at 10,829'— 18'of penetration.Close annular and test seal assembly to 2500 psi held and charted 5 min--Good test.Unsting from Seal Assembly and TOH to install space out pups.TOH 16.5 feet and experienced 100K overpull in attempt to unsting.Slacked seal assembly inside tie-back and tag up on locator to verify pipe free—unable to pull past tight spot with 100K overpull.Close annular and retest seal assembly to 2500 psi held and charted 5 min--Good test.MU 4-1/2"IF x 7"BTC crossover as drive sub and worked pipe with 6K torque while reciprocating pipe. PU and pulled into tight spot with 100K.Slack off and PU and pulled through tight spot.Continue TOH while laying down 3 joints to install space out pups.MU space out pups and one full joint,7"hanger with pup and landing joint.TIH and position seal assy—3'above tie-back with hanger below annular.Close annular and hold pre-job meeting,pressure test lines with P6 pump to 1500 psi and pump 140 bbls of diesel freeze protection into annulus while taking returns up the 7"casing. Slack off 7"while stripping through the annular to land hanger and engage seals in tie-back at 10,840'with 11'of seal assembly stung into PBR.Test seal assembly to 2500 psi on chart 30 min--Good test. RD all casing equipment and RU all 4"handling equipment while loading 4"DP in pipe shed. 9/30/2010 10/1/2010 14,108.0 10.20 Install pack off in multi-bowl and test same to 5000 psi for 10 min on chart--Good test. Install test plug and change out bottom pipe rams from 7"casing rams to 2-7/8"X 5"VBR's.Test upper and lower 2-7/8"X 5"VBR's to 250 psi low/4500 psi high.Test annular to 250 psi low/2500 psi high.All tests charted and held for 5 min per test.TIH with 7"FasDrill cement retainer f/ surface 1/12,443'while picking up singles from pipe shed. 10/1/2010 10/2/2010 14,108.0 10.20 TIH with 7"FasDrill cement retainer f/12,443'1/13,953'.PU and MU 10'pup joint to space out FasDrill retainer at 13,960'.Set retainer and sheer off with 65k overpull.Tag retainer at 13,960' to confirm depth.Test casing to 3500 psi for 30 min on chart--Good test.Stab stinger thru FasDrill retainer,set down 20k,and test annulus to 1500 psi on chart for 5 min--Good test. Bleed off annulus pressure and obtain injection rates at 1/2 bbl increments up to 2 bpm.PU t/13,950 and break circulation with HES cement unit,Pumped 8 bbls of seawater spacer,test lines to 3500 psi--Good test.Pump 15 bbls of 15.8 ppg cement(1.18 yield Premium G).Chase with 13 bbls of seawater,and shut down cement pump. Break out pup joint,insert DP wiper ball into pipe,MU same,and displace cement to stinger. Pumped 102 bbls of 10.1 ppg mud.Sting into cement retainer at 13,960'and inject cement while monitoring annulus pressure. Inject 28 bbls spotting 2 bbls of spacer below retainer.Unsting from retainer and observed 1100 psi bleed I off.CBU 1.5x at 13,950'. POOH f/13,950'117,332'.Trouble shoot and change out joy stick control for draw works. POOH f/7,332'U surface and LD setting tool.Tested choke manifold 250 psi low/4500 psi high while POOH.Change out lower well control valve and saver sub on top drive to 4"XT-39.Test BOPE per AOGCC&PXD rules and regulations.Test BOPE w/4"test joint to " ? 250 psi low/4500 psi high.Test annular w/4"test joint to 250pst low/2500 psi high.Test all floor valves to 250 psi low/ psi high.All tests charted and all test held for 5 min.Right to witness waived by AOGCC Rep.Jeff Jones at 0800 hrs on 09/29/10. 10/2/2010 10/3/2010 14,108.0 20.00 10.20 Test upper and lower 2-7/8"X 5"VBR's w/4.5"test joint to 250 psi low/4500 psi high.All tests charted and all test held for 5 min.Right to witness waived by AOGCC Rep.Jeff Jones at 0800 hrs on 09/29/10.Install wear bushing.TIH with clean out 6-1/8"BHA f/surface t/2,212'.Slip and cut drill line.TIH f/2,212'1113,600'.Madd pass BAT Sonic at 4/-300 fph f/13,600'1/13,960'. Drill cement and float equipment f/13,690'1114,108'. Page 5/7 Report Printed: 11/11/2010 PIONEER .)erations Summary Report - Stak NATURAE RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 10/3/2010 10/4/2010 14,128.0 0.00 10.20 Drill 6-1/8"hole f/14,108't/14,128' CBU at 14,128'. Perform F.I.T.at 14,106'and/6,186'tvd with 10.2 ppg mud to 740 psi,for EMW of 12.5 ppg. Pump dry job and madd pass BAT Sonic (/14,128't/14,060'. POOH f/14,060't/surface. PU directional 6-1/8"BHA#11 t/379'and shallow test same.TIH f/379't/14,064'. Break circulation and test MWD at 14,064'. Remove trip nipple and install RCD bearing. Displace well to 7.7 ppg reconditioned OBM at 14,128'. 10/4/2010 10/5/2010 14,128.0 1,865.00 7.80 Displace well to 7.7 ppg OBM at 14,128'. Maintain 9.8 ppg EMW using MPD equipment. ' Directional drill 6-1/8"hole f/14,128'015,993'. 10/5/2010 10/6/2010 15,993.0 - 7.90 Directional drill 6-1/8"hole f/15,933't/16,571'. Element failed on RCD,trap pressure with annular 14,099.00 and change out RCD bearing. Directional drill 6-1/8"hole f/16,571'017,887'maintaining 10.0 ppg EMW w/MPD. 10/6/2010 10/7/2010 17,887.0 1,964.00 8.00 Directional drill 6-1/8"hole f/17,887'019,851'maintaining 10.0 ppg EMW w/MPD. 10/7/2010 10/8/2010 19,851.0 96.00 8.00 Drill 6-1/8"hole to lower lateral f/19,851'to TD at 19,947'maintaining 10.1 ppg EMW w/MPD. Circulate hole clean. POOH for wiper trip f/19,947't/14,064'.Cut&slip drlg line.Service rig. RIH (/14,064't/18,890'.Wash&ream f/18,890't/19,690'to overcome negative weight.CBU x2.Spot 200 bbls new 6.9 ppg LVT in DP.Chase w/10 bbls H.V.spacer and 104 bbls 10.0 ppg MOBM. POOH stopping to spot 16 bbls 10.0 ppg MOBM every 10 stands 015,213'. 10/8/2010 10/9/2010 19,947.0 0.00 8.10 Spot 10.0 H.V.pill across sump section at 15,213'.POOH to 14,064'.Displace well w/10.1 ppg MOBM.POOH.LD BHA.Function test BOPE per AOGCC weekly requirements-good test.PU 24 jts of 4"HWT f/pipeshed.Circ pipe volume.POOH stand back HWT.RU&run 4-1/2"12.6#L -80 Hyd.521 "plop&drop"liner 01,798'. 10/9/2010 10/10/2010 19,947.0 0.00 10.10 RIH w/4-1/2"12.6#L-80 Hyd 521 "plop&drop"liner f/1,798'05,403'.PU Liner top billet and GS — spear. RIH w/liner on 4"DP(/5,450'019,700'. Release liner. Shoe at 19,695'.Top of liner top billet at 14,265'. POOH to 7"shoe.Circ 10.1 ppg MOBM around. POOH t/7,309'. -NOTE:AOGCC was notified of upcoming BOP test at 11:00 hrs.AOGCC Rep Lou Grimaldi waived witness of test at 11:30 hrs on 10/09/10. 10/10/2010 10/11/2010 14,210.0 7.90 POOH w/liner running tools f/7,903't/surface.LD tools.PU 24 jts DP and 4 HWT from shed. Circ pipe volume.POOH stand back same.Test BOPE per AOGCC&PXD rules®ulations: Test upper and lower 2-7/8"X 5"VBR's wf 2-7/8"&4.5"test joints to 250 psi low/4500 psi high. Test annular w/2/7/8"&`4.5"test joints to 250 psi low/2500 psi high.Test all floor valves and choke manifold to 250 psi low/4500 psi high.All tests charted and all test held for 5 min. Perform accumulator draw down test: Right to witness waived by AOGCC Rep Lou Grimaldi at 11:30 hrs on 10/09/10. Install wear bushing.PU drilling 6-1/8"BHA and RIH 06159'. 10/11/2010 10/12/2010 14,210.0 510.00 7.85 RIH f/6,159't/14,062'.Cut&slip drlg line.Service rig. Pull trip nipple. Install RCD. Displace well to 7.8 ppg MOBM.RIH 014,260'. PU and cut trough/sidetrack 6-1/8"hole f/14,180't/14,210' maintaining 9.8 ppg EMW w/MPD.Control drilling new 6-1/8"hole f/14,210'014,255'. Directional drill 6-1/8"hole f/14,255't/14,720'maintaining 9.8 ppg EMW w/MPD. 10/12/2010 10/13/2010 14,720.0 2,980.00 8.05 Directional drill 6-1/8"Lateral 1 f/14,720't/17,700'maintaining 10.1 ppg EMW w/MPD. e( 10/13/2010 10/14/2010 17,700.0 2,437.00 8.00 Directional drill 6-1/8"Lateral 1 f/17,700't/18,306'maintaining 10.1 ppg EMW w/MPD.Circ open hole volume.Change RCD bearing.Directional drill Lateral 1 (/18,306't/20,137'. 10/14/2010 10/15/2010 20,137.0 815.00 8.10 Directional drill lateral 1 f120,137't/TD at 20,952'.Circ hole clean,POOH ft wiper trip t/14,063'(inside 7"shoe).Change Top Drive wash pipe.Change ROD bearing. 10/15/2010 10/16/2010 20,952.0 0.00 8.15 RIH f/14,063't/18,306'.Wash&ream due to 0 down wt f/18,306'020,952'maintaining 10.2 ppg EMW w/MPD. Circulate hole clean.Spot 6.9 ppg LVT in Lat.1.POOH t/14,062'(inside 7" casing). Pump 25 bbls 10.1 ppg H.V.spacer and chase w/118 bbls 10.1 ppg MOBM. RIH t/14,405'.POOH pumping 2 bpm and spotting H.V. 10.1 ppg pill f/14,405'013,780'.Displace well w/10.1 ppg MOBM f/13,780't/surface. Page 6/7 Report Printed: 11/11/2010 PI O N E E R aerations Summary Report - State NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(Ib/gal) Summary 1 0/16/201 0 10/17/2010 20,952.0 0.00 10.10 Complete displacing well w/10.1 ppg MOBM. Pull RCD. Install trip nipple.Circ to confirm KW mud around.Observe well. POOH f113,780't/377'.LD BHA. RIH PU 21 jts 4"HWT f/shed. Circulate pipe vol+. POOH stand back same. RU and run 130 jts 4-1/2"12.6#L-80 HYD 521 liner t/5,354'. 10/17/2010 10/18/2010 20,952.0 0.00 10.00 Run 4-1/2"12.6#L-80 Hyd.521 liner t/7,124'. RIH w/liner on 4"DP t/14,061'(7"shoe).Circulate DP volume.Obtain parameters.Continue RIH.w/liner on DP t/20 940'(s1)ne depth).Drop setting ball and pump down on seat. Pressure to 1500 psi.Set down 20k.Increase pressure in 500 psi increments and observe ball seat shear w/3400 psi.PU to clear setting dogs.Set down to confirm.PU and rotate down w/40 rpm.Set down 75k while rotating and observe shear/set of packer.PU to up wt.Close top rams.Attempt to test liner lap to 3500 psi. No test.Bleed off.PU and set down 75k on liner top.Attempt to pressure up to 3500 psi.No success.Pumping away at 2 bpm, 1200 psi.POOH 1 stand t/13,880'. Dispalce well w/10.0 ppg brine(/13,880't/surface. Top of Liner @ 13,953'&Liner shoe @,20,940'. NOTE: Function test BOPE per AOGCC weekly requirements-good test. 10/18/2010 10/19/2010 20,952.0 0.00 10.00 Displace well 1/13,880't/surface w/10.0 ppg brine.Cut&slip drilling line.Circ 1/2 BU. POOH LD DP(/13,880't/surface. RIH w/70 stands 4"DP f/derrick.CBU 2x to flush pipe.Displace well w/ clean 10.0 ppg brine.POOH LD DP t/4,728'. 10/19/2010 10/20/2010 20,952.0 0.00 10.00 POOH LDDP f/4,728'U surface. RU and RIH PU 2-7/8"tubing joints t/13,450'while waiting on Centrilift personnel&equip. 10/20/2010 10/21/2010 20,952.0 0.00 10.00 POOH standing back 2-7/8"tubing f/13,450't/surface.Flush stack.RU and run ESP completion f/surface U1,603' 10/21/2010 10/22/2010 20,952.0 0.00 10.00 RIH w/2-7/8"ESP completion f/1,603't/10 890 ` 10/22/2010 10/23/2010 20,952.0 0.00 10.00 RIH w/2-7/8"6.5#L-80 IBT-M tubing f/10,890't/11,111'.Make ESP penetration thru Hydrow II pakcer.Test packer vent valve from below to 4000 psi for 10 min-Good test. RIH w/2-7/8"6.5# L-80 IBT-M tubing(/11,111't/13,708'.Make ESP cable and control line penetrations thru tubing hanger.Meg test ESP cable-Good test.Test control lines to 5000 psi after making penetrations. Land tubing hanger at f/13,708't/13,752'. Verify and lock down tubing hanger.Test upper and lower hanger seals to 5000 psi on chart 10 min-Good test. ND BOP stack and drillng riser. Make SSSV and GVV line penetration and test same to 5000 psi for 10 min-Good test. Make ESP cable penetrations and meg test same-Good test.NU tree,test void and tree to 5000 psi for 10 min each test on chart-Good test. Remove test plug from tubing hanger.RU lines and reverse out manifold,test lines to 4500 psi for 5 min.Open SSSV with 3500 psi on control line and freeze protect well with 75 bbls diesel by reverse circulate pumping diesel down annulus taking returns thru tubing. 10/23/2010 10/24/2010 20,952.0 0.00 10.00 Freeze protect well by pumping 75 bbls diesel down annulus and taking returns thru tubing.RU lubricator and drop ball bar rod,allow to fall for 30 min.Set Hydrow II packer by pressuring up to 3500 psi in 500 psi increments. Held 3500 psi for 15 min then bleed tubing down to 500 psi. Tested annulus to 2500 psi held 30 min on chart-Good test.Blow down all lines and RD reverse circulating manifold.RU slick line unit. Run#1, Retrieve Ball&Rod from 9,856'wlm. Run#2, Retrieve RHCM Plug Body from 9,874'wlm. Run#3,Drop catcher&Retrieve Dummy f/GLM at 9,771'wlm.Attempt to set 1/4"OV in GLM#2 at 9,772'wlm-unsuccessful on first 3 runs with same.Modify K.O.T.by removing knuckle joint and RIH with 1/4"O.V.and work to seat same at 6,772'wlm. Rig released on ODSN-17/17L1 @ 23:59 hrs, 10/23/10 Page 7/7 Report Printed: 11/11/2010 PIONEERCurrent Schematic - State Well Name: ODSN-17 NATURAL RESOURCES HORIZONTAL-Lateral 1, 11/17/2010 2:22:26 PM Well Attributes Vertical schematic(actual)Vertical Field Name Well Status Total Depth(ftKB) __ 50-703-20622-00-00/50- 000GURUK DRILLING 20,952.0 1-2 ' 703-20622-60-00 k� Casing Strings Conductor,158.0ftKB • Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Dept... Grade Top Connection Wt/Len(Ib/ft) Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 11-1 Casing Components I1-7 Top(TVD) " Item S Item Des Top(ftKB) (ftKB) - OD(in) ID(in) Com 1-11 1-1 16"Conductor 47.7 47.7 16 14.670 Surface,4,659.8ftKB 11-15 — Description OD(in) ID(in) Top(ftKB) Set Depth(ft_ Set Dept.. Grade Top Connection Wt/Len(Ib/ft) Surface 11 3/4 10.772 39.0 4,659.8 3,285.0 L-80 HYD 521 60.00 1-19 " 4-1 Casing Components 1! 4-2 Top(TVD) 4-3 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 2-7 11 3/4"Surface Shoe 4,658.0 3,284.4 11 3/4 10.772 12 71 Intermediate 2 Tie back,10,843.9ftKB 1-23 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept.. Grade Top Connection Wt/Len(Ib/ft) ' Intermediate 2 7 6.276 37.8 10,843.9 5,320.1 L-80 BTC-M 26.00 ® _ Tie back 3_8 Casing Components r' i ® --'- _ Top(TVD) i 5-1 Item# Item Des Top(ftKB) (ftK8) OD(in) ID(in) Com 3-8 WFT"SHR"hold down sub 10,817.4 5,311.3 7 6.276 1 5-2 r 5 3 3-11 WFT Tie back seal 10,824.6 5,313.7 7 6.276 4-11 assembly 4 seals 7-1 1-31 1 �7.2 Intermediate,10,978.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Dept... Grade Top Connection Wt/Len(lb/ft) 1-32 = 7-4 Intermediate 9 5/8 8.835 4,497.4 10,978.0 5,364.4 L-80 Hyd 521 40.00 I ' 7-7 Casing Components 17-10 Top(TVD) I1 7.11tem# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn rr 7-14 4-1 Tie Back 4,497.4 3,231.2. 9 5/8. 8.835 L. 7-17 4-2 Packer 4,519.1 3,238.4 9 5/8 8.835 7-20 4-3 Hanger 4,521.3 3,239.1 9 5/8 8.835 7-23 4-11 9-5/8"Drilling Liner Shoe 10,976.3 5,363.8 9 5/8 8.835 725 Intermediate 2 Drlg Liner,14,106.0ftKB ® Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft)' { 7-29 Intermediate 2 7 6.276 10,835.5 14,106.0 6,186.1 L-80 Hyd 511 26.00 li ® Drlg Liner ® Casing Components ® Top(TVD) 7-37 Item# Item Des • Top(ftKB) (ftKB) OD(in) ID(in) - Corn I 7-40 5-1 PBR Tie Back Sleeve 10,835.5 5,317.3 8 1/4 7.500 7-42 7-44 5-2 7"x9-5/8"TSP Liner Top 10,856.5 5,324.2 8 3/16 6.250 Pkr 7-46 5-3 7"x9-5/8"PHR Rot Hyd Hgr 10,859.3 5,325.2 8 5/16 6.250 • 7-48 • 7.50 5-10 7"Casing Shoe 14,106.0 6,186.1 7 6.276 Ray Oil Tool 511 FS h• ® Production Plop&Drop,19,695.3ftKB ' 7-54 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) • 7-56 Production 4 1/2 3.958 14,265.0 19,695.3 6,360.5 L-80 HYD 521 12.60 ' 7-58 Plop&Drop T 7.61 Casing Components I 7-64 Top(TVD) I Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 7-66 6-1 6"Aluminum Liner top Billet 14,265.0 6,207.8 4 1/2 3.958 7-68 • ' 7-70 6-4 Perforated Pup Joint 14,452.8 6,222.0 4 1/2 3.958 I7-72 �7-74 //7-76 7-78 • • 7-80 7-82 7-84 • 7-86 • I.i 7-88 i• 7-90 Page 1/3 Report Printed: 11/17/2010 PI 0 N E E R Current Schematic - State Well Name: ODSN-17 NATURAL RESOURCES HORIZONTAL-Lateral 1, 11/17/2010 2:22:27 PM Casing Components Vertical schematic actual Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-2 6-7 Resman Tracer ROS- 14,665.3 6,235.3 4 1/2 3.958 132/RWS-145 if 6-9 Perforated Pup Joint 14,756.0 6,240.4 4 1/2 3.958 o r 6-11 Perforated Pup Joint 14,958.4 6,256.8 4 1/2 3.958 J1-1 6-13 Perforated Pup Joint 15,166.5 6,266.3 4 1/2 3.958 6-15 Perforated Pup Joint 15,373.7 6,260.4 4 1/2 3.958 1-7 II 6-18 Resman Tracer#ROS- 15,543.4 6,247.8 4 1/2 3.958 1-11 129/RWS-142 1116-20 Perforated Pup Joint 15,794.7 6,229.8 4 1/2 3.958 1-15 I1-19 'I.. 6-22 Perforated Pup Joint 15,996.2 6,235.3 4 1/2 3.958 ,4-1 6-24 Perforated Pup Joint 16,203.3 6,253.0 4 1/2 3.958 y' / 4-2 6-26 Perforated Pup Joint 16,408.8 6,273.2 4 1/2 3.958 4-3-3 6-28 Perforated Pup Joint 16,613.5 6,288.0 4 1/2 3.958 6-30 Perforated Pup Joint 16,820.2 6,298.2 4 1/2 3.958 12-71 6-32 Perforated Pup Joint 17,027.3 6,310.9 4 1/2 3.958 1-23 6-34 Perforated Pup Joint 17,227.3 6,307.6 4 1/2 3.958 1-27 I 6-36 Perforated Pup Joint 17,434.1 6,293.4 4 1/2 3.958 I3-8 6-39 Resman tracer#ROS- 17,642.5 6,276.7 41/2 3.958 , , 3-111 127/RWS-140 I _ 1 5-1 6-41 Perforated Pup Joint 17,853.5 6,260.0 4 1/2 3.958 5-2 6-43 Perforated Pup Joint 18,057.6 6,248.9 4 1/2 3.958 r 4-1, /5-3 6-45 Perforated Pup Joint 18,262.6 6,255.7 4 1/2 3.958 jil 7-1 6-47 Perforated Pup Joint 18,468.4 6,270.9 4 1/2 3.958 1-31 I7-2 6-49 Perforated Pup Joint 18,670.2 6,288.6 4 1/2 3.958 1-32 7-4 6-51 Perforated Pup Joint 18,875.6 6,300.0 4 1/2 3.958 • 7-7 6-53 Perforated Pup Joint 19,078.4 6,311.2 4 1/2 3.958 , 7-10 6-55 Perforated Pup Joint 19,280.0 6,327.9 4 1/2 3.958 I ' 7-14 6-57 Perforated Pup Joint 19,486.3 6,345.6 4 1/2 3.958 ME 6-59 Perforated Pup Joint 19,689.4 6,360.1 4 1/2 3.958 �.: 7-20 6 60 Float Shoe 19,694.1 6,360.4 7-23 Production Lateral 1,20,940.0ftKB 7_25 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) . , ® 4 4 1/2 3.958 13,953.3 20,940.0 L-80 HYD 521 12.60 Lateral 1 • 7-29 Casing Components ' ® Top(TVD) ' • ® Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn ' ® 7-1 Tieback receptacle w/ 13,953.3 ' 4 1/2 3.958 ' 7-37 polished bore 4. • 7-40 7-2 NTH Liner Top packer 13,968.7 4 1/2 3.958 , i 7-42 7-4 PHR Liner Hanger 13,972.1 4 1/2 3.958 • 7-44 7-7 Perforated Pup Joint 14,058.7 4 1/2 3.958 • 7-46 7-10 Weatherford Sliding Sleeve 14,269.1 6,211.3 4 1/2 3.958 7-48 7-50 • ® 7-11 Perforated Pup Joint 14,274.2 6,212.0 4 1/2 3.958 I 7-54 7-14 Weatherford Oil Swell 14,363.8 6,219.0 4 1/2 3.958 7-56 Packer 17-58 7-17 Perforated Pup Joint 14,543.5 6,219.0 4 1/2 3.958 7-61 7-20 Resman tracer#ROS- 14,709.5 6,219.0 4 1/2 3.958 7-64 141/RWS-151 I 1 7-66 7-23 Perforated Pup Joint 14,762.2 6,218.1 4 1/2 3.958 7-68 7-25 Perforated Pup Joint 14,966.5 6,212.8 4 1/2 3.958 • 7-70 7-27 Perforated Pup Joint 15,173.5 6,213.1 4 1/2 3.958 1'77--7274 7-29 Perforated Pup Joint 15,376.2 6,220.5 4 1/2 3.958 �(7 76 7-31 Perforated Pup Joint 15,580.9 6,223.8 4 1/2 3.958 I / 7-78 7-80 7-82 • 7-84 I • 7-86 7-88 i T 7-90 Page 2/3 Report Printed: 11/17/2010 . , PI ® NEER Current Schematic - State Well Name: ODSN-17 NATURAL RESOURCES HORIZONTAL-Lateral 1, 11/17/2010 2:22:28 PM Casing Components Vertical schematic(actual) Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-2 7-33 Perforated Pup Joint 15,781.9 6,219.7 4 1/2 3.958 7-35 Perforated Pup Joint 15,987.8 6,217.3 4 1/2 3.958 13I if 7-37 Resman tracer#ROS- 15,995.2 6,217.2 4 1/2 3.958 i 143/RWS-153 J 1-1 7-40 Perforated Pup Joint 16,210.3 6,218.6 4 1/2 3.958 7-42 Perforated Pup Joint 16,415.2 6,227.6 4 1/2 3.958 1-7 7-44 Perforated Pup Joint 16,618.9 6,236.5 4 1/2 3.958 1-11 III, 7-46 Perforated Pup Joint 16,823.7 6,244.0 4 1/2 3.958 1-15 7-48 Perforated Pup Joint 17,028.6 6,244.5 4 1/2 3.958 1-19 - 4-17-50 Perforated Pup Joint 17,236.4 6,235.1 4 1/2 3.958 7-52 Perforated Pup Joint 17,442.0 6,231.1 4 1/2 3.958 `, 4-2 7-54 Perforated Pup Joint 17,647.0 6,228.3 4 1/2 3.958 4-3 7-56 Perforated Pup Joint 17,850.9 6,243.6 4 1/2 3.958 J L 12-7 7-58 Perforated Pup Joint 18,053.2 6,254.2 4 1/2 3.958 1-23 c 7-61 Resman tracer#ROS- 18,182.4 6,254.9 4 1/2 3.958 144/RWS-154 1-27 1 7-64 Perforated Pup Joint 18,274.8 6,251.8 4 1/2 3.958 3-8 7-66 Perforated Pup Joint 18,479.7 6,240.1 4 1/2 3.958 • , 1 3-111 7-68 Perforated Pup Joint 18,683.3 6,235.2 4 1/2 3.958 5-1 7-70 Perforated Pup Joint 18,885.6 6,243.8 4 1/2 3.958 52 P 5-3 7-72 Perforated Pup Joint 19,089.9 6,254.6 4 1/2 3.958 t 4-11 7-74 Perforated Pup Joint 19,296.7 6,265.7 4 1/2 3.958 7-1 7-76 Perforated Pup Joint 19,501.2 6,262.4 4 1/2 3.958 1-31 , 17-2 7-78 Perforated Pup Joint 19,702.2 6,258.4 4 1/2 3.958 1-32 ~r 7-4 7-80 Perforated Pup Joint 19,907.5 6,255.8 4 1/2 3.958 Ir' 7-7 7-82 Perforated Pup Joint 20,114.5 6,246.8 4 1/2 3.958 7-10 7-84 Perforated Pup Joint 20,321.0 6,256.2 4 1/2 3.958 I 4 7-86 Perforated Pup Joint 20,524.6 6,270.4 4 1/2 3.958 ® 7-88 Perforated Pup Joint 20,728.8 6,278.6 4 1/2 3.958 -x: , 7-20 7-90 Perforated Pup Joint 20,893.6 6,287.6 4 1/2 3.958 a 7-23 7-92 Weatherford Solid Shoe 20,938.7 7-25 Tubing Strings TubingDescription StringM... ID(in) Top(ftKB) Set Depth f_. Set .. Wt Ib/ft Grade TopThread P ) P ( Dept ( ) 7-29 Tubing-Production 2 7/8 2.441 35.0 13,752.6 6,122.0 6.50 L-80 IBT-M 1 , ® Tubing Components l , ® Item# Item Des Top(ftKB) Top o(ftKB)D) OD(in) ID(in) Corn • 1-2 Vetco Tubing Hgr 35.0 35.0 11 2.992 7-37t 1-7 Wellstar TRScSSSV 2,007.2 1,960.5 2 7/8 2.441 '7 -40 7-42 1-11 1 1/2"x 2 7/8"Gas Lift 2,403.2 2,296.3 2 7/8 2.441 , 17 44 Mandrel#1 1 1 7-46 1-15 X-Nipple w/2.313"ID 2,519.4 2,385.1 2 7/8 2.441 I 17-48 1-19 Weatherford Hydrow Il 2,633.2 2,465.8 2 7/8 2.441 17-50 Packer 1® 1-23 1 1/2"x 2 7/8"Gas Lift 9,756.4 4,964.7 2 7/8 2.441 7-54 Mandrel#2 w/dummy j i 7-56 1-27 2.313"X-Nipple w/RHC-M 9,868.4 5,001.2 2 7/8 2.313 j 17-58 plug I7-61 1-31 ADV assembly 13,682.7 6,108.2 2 7/8 0.000 7-64 1-32 ESP-Pump Assembly 13,692.0 6,110.1 2 7/8 0.000 } il 7-66 7-68 7-70 REM 1 r 7-74 t 7-76 1 7-78 7-80 • 7-82 j 7-84 7-86 } • 7-88 1 Ti 7-90 Page 3/3 Report Printed: 11/17/2010 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.00 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +E/-W 0.00 ft Easting: 469,826.11 ft Longitude: 150° 14'48.230 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-17 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) 1 IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 L1 PN13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 14,180.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 194.97 Survey Program Date 10/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,105.00 ODSN-17 Gyro(ODSN-17 PN13 mid) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 8/26/2010 1: 1,154.91 4,612.64 ODSN-17 MWD 1 (ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8/27/2010 t 4,710.05 10,949.10 ODSN-17 MWD 2(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/7/2010 12: 11,042.53 14,070.86 ODSN-17 MWD 3(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/21/2010 t 14,156.32 14,180.00 ODSN-17 MWD 4(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/4/2010 t 14,219.23 20,917.84 ODSN-17L1 PN13 MWD 5(ODSN-17 L'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/12/2010 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,056.25 469,826.11 0.00 0.00 UNDEFINED 100.00 0.35 5.53 100.00 43.80 0.18 0.02 6,031,056.43 469,826.13 0.61 -0.17 SR-Gyro-SS(1) 172.00 0.78 357.31 172.00 115.80 0.88 0.01 6,031,057.13 469,826.13 0.61 -0.86 SR-Gyro-SS(1) 218.00 0.77 11.51 217.99 161.79 1.50 0.06 6,031,057.75 469,826.18 0.42 -1.46 SR-Gyro-SS(1) 264.00 0.67 32.05 263.99 207.79 2.03 0.27 6,031,058.28 469,826.38 0.60 -2.03 SR-Gyro-SS(1) 310.00 0.51 59.03 309.99 253.79 2.36 0.58 6,031,058.61 469,826.70 0.69 -2.43 SR-Gyro-SS(1) 356.00 1.45 98.70 355.98 299.78 2.38 1.33 6,031,058.63 469,827.45 2.41 -2.64 SR-Gyro-SS(1) 399.00 1.30 100.16 398.97 342.77 2.21 2.35 6,031,058.45 469,828.47 0.36 -2.74 SR-Gyro-SS(1) 445.00 1.49 102.67 444.95 388.75 1.99 3.45 6,031,058.23 469,829.57 0.43 -2.81 SR-Gyro-SS(1) 493.00 1.12 103.85 492.94 436.74 1.74 4.51 6,031,057.97 469,830.63 0.77 -2.85 SR-Gyro-SS(1) 10/19/2010 3:38:19PM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 539.00 0.59 88.47 538.94 482.74 1.64 5.19 6,031,057.87 469,831.30 1.25 -2.92 SR-Gyro-SS(1) 585.00 0.57 339.47 584.93 528.73 1.86 5.34 6,031,058.09 469,831.46 2.05 -3.18 SR-Gyro-SS(1) 631.00 2.15 303.65 630.92 574.72 2.55 4.54 6,031,058.78 469,830.66 3.74 -3.64 SR-Gyro-SS(1) 679.00 2.89 299.16 678.87 622.67 3.64 2.74 6,031,059.88 469,828.86 1.59 -4.22 SR-Gyro-SS(1) 725.00 4.49 297.38 724.78 668.58 5.03 0.13 6,031,061.28 469,826.26 3.49 -4.89 SR-Gyro-SS(1) 775.00 5.09 297.86 774.60 718.40 6.97 -3.57 6,031,063.23 469,822.57 1.20 -5.81 SR-Gyro-SS(1) 821.00 6.25 296.89 820.38 764.18 9.06 -7.61 6,031,065.34 469,818.54 2.53 -6.78 SR-Gyro-SS(1) 870.00 6.52 296.43 869.07 812.87 11.50 -12.48 6,031,067.80 469,813.68 0.56 -7.89 SR-Gyro-SS(1) 916.00 6.47 297.18 914.78 858.58 13.85 -17.12 6,031,070.17 469,809.04 0.21 -8.95 SR-Gyro-SS(1) 964.00 6.72 300.83 962.46 906.26 16.52 -21.94 6,031,072.86 469,804.24 1.02 -10.29 SR-Gyro-SS(1) 1,010.00 7.59 303.62 1,008.10 951.90 19.58 -26.78 6,031,075.94 469,799.41 2.04 -12.00 SR-Gyro-SS(1) 1,059.00 8.84 304.73 1,056.60 1,000.40 23.52 -32.57 6,031,079.90 469,793.64 2.57 -14.31 SR-Gyro-SS(1) 1,105.00 10.33 306.26 1,101.95 1,045.75 27.97 -38.80 6,031,084.38 469,787.43 3.29 -17.00 SR-Gyro-SS(1) 1,154.91 10.97 306.14 1,151.00 1,094.80 33.42 -46.25 6,031,089.85 469,780.01 1.28 -20.34 MWD+IFR2+MS+sag(2) 1,249.75 12.79 310.01 1,243.81 1,187.61 45.49 -61.57 6,031,101.99 469,764.73 2.09 -28.04 MWD+IFR2+MS+sag(2) 1,345.36 14.25 306.47 1,336.77 1,280.57 59.29 -79.14 6,031,115.86 469,747.21 1.75 -36.84 MWD+IFR2+MS+sag(2) 1,441.50 16.46 305.59 1,429.47 1,373.27 74.25 -99.74 6,031,130.90 469,726.68 2.31 -45.97 MWD+IFR2+MS+sag(2) 1,535.55 17.50 301.22 1,519.42 1,463.22 89.34 -122.67 6,031,146.08 469,703.82 1.75 -54.62 MWD+IFR2+MS+sag(2) 1,630.45 18.59 302.17 1,609.66 1,553.46 104.79 -147.68 6,031,161.63 469,678.88 1.19 -63.09 MWD+IFR2+MS+sag(2) 1,696.70 18.80 298.73 1,672.41 1,616.21 115.54 -165.98 6,031,172.46 469,660.62 1.69 -68.75 MWD+IFR2+MS+sag(2) 1,757.05 18.77 298.18 1,729.55 1,673.35 124.80 -183.06 6,031,181.78 469,643.57 0.30 -73.28 MWD+IFR2+MS+sag(2) 1,852.52 20.92 295.54 1,819.34 1,763.14 139.41 -211.98 6,031,196.50 469,614.71 2.44 -79.92 MWD+IFR2+MS+sag(2) 1,947.56 25.06 292.03 1,906.82 1,850.62 154.28 -245.97 6,031,211.51 469,580.79 4.59 -85.51 MWD+IFR2+MS+sag(2) 2,042.11 27.21 292.05 1,991.70 1,935.50 169.91 -284.57 6,031,227.29 469,542.26 2.27 -90.63 MWD+IFR2+MS+sag(2) 2,137.05 30.84 291.63 2,074.70 2,018.50 187.03 -327.32 6,031,244.59 469,499.58 3.83 -96.13 MWD+IFR2+MS+sag(2) 2,232.35 31.42 292.38 2,156.28 2,100.08 205.50 -373.00 6,031,263.24 469,453.98 0.73 -102.17 MWD+IFR2+MS+sag(2) 2,327.45 35.63 292.98 2,235.54 2,179.34 225.76 -421.45 6,031,283.69 469,405.63 4.44 -109.23 MWD+IFR2+MS+sag(2) 2,422.51 38.40 290.54 2,311.44 2,255.24 246.93 -474.60 6,031,305.08 469,352.57 3.30 -115.95 MWD+IFR2+MS+sag(2) 2,517.34 42.48 288.71 2,383.60 2,327.40 267.55 -532.53 6,031,325.93 469,294.72 4.48 -120.90 MWD+IFR2+MS+sag(2) 2,613.42 46.37 284.64 2,452.22 2,396.02 286.75 -596.94 6,031,345.39 469,230.40 5.02 -122.82 MWD+IFR2+MS+sag(2) 2,708.38 48.97 279.31 2,516.18 2,459.98 301.24 -665.58 6,031,360.16 469,161.83 4.97 -119.09 MWD+IFR2+MS+sag(2) 2,803.28 51.29 273.38 2,577.05 2,520.85 309.22 -737.91 6,031,368.43 469,089.54 5.38 -108.11 MWD+IFR2+MS+sag(2) 2,899.43 54.08 268.08 2,635.35 2,579.15 310.13 -814.32 6,031,369.65 469,013.14 5.26 -89.25 MWD+IFR2+MS+sag(2) 2,994.43 56.77 265.45 2,689.27 2,633.07 305.69 -892.40 6,031,365.52 468,935.05 3.63 -64.79 MWD+IFR2+MS+sag(2) 3,090.16 59.62 263.56 2,739.72 2,683.52 297.88 -973.36 6,031,358.04 468,854.06 3.42 -36.33 MWD+IFR2+MS+sag(2) 3,185.33 63.02 262.45 2,785.39 2,729.19 287.70 -1,056.22 6,031,348.20 468,771.17 3.72 -5.10 MWD+IFR2+MS+sag(2) 3,279.10 65.81 261.16 2,825.88 2,769.68 275.63 -1,139.92 6,031,336.48 468,687.44 3.22 28.18 MWD+IFR2+MS+sag(2) 1 3,374.77 70.37 260.38 2,861.57 2,805.37 261.39 -1,227.50 6,031,322.59 468,599.80 4.83 64.56 MWD+1FR2+MS+sag(2) 3,469.87 72.08 259.20 2,892.18 2,835.98 245.42 -1,316.11 6,031,306.99 468,511.14 2.15 102.87 MWD+IFR2+MS+sag(2) 3,565.72 70.73 257.02 2,922.74 2,866.54 226.72 -1,405.00 6,031,288.64 468,422.18 2.57 143.91 MWD+IFR2+MS+sag(2) 10/19/2010 3:38:19PM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,661.41 70.08 255.90 2,954.84 2,898.64 205.61 -1,492.64 6,031,267.90 468,334.47 1.30 186.94 MWD+IFR2+MS+sag(2) 3,756.32 70.91 255.84 2,986.52 2,930.32 183.77 -1,579.40 6,031,246.41 468,247.63 0.88 230.45 MWD+IFR2+MS+sag(2) 3,851.14 71.00 256.41 3,017.47 2,961.27 162.28 -1,666.41 6,031,225.27 468,160.54 0.58 273.69 MWD+IFR2+MS+sag(2) 3,945.82 70.58 256.69 3,048.62 2,992.42 141.48 -1,753.37 6,031,204.83 468,073.51 0.52 316.24 MWD+IFR2+MS+sag(2) 4,041.02 71.21 257.51 3,079.78 3,023.58 121.40 -1,841.05 6,031,185.11 467,985.75 1.05 358.29 MWD+IFR2+MS+sag(2) 4,136.12 71.00 258.58 3,110.57 3,054.37 102.76 -1,929.07 6,031,166.83 467,897.66 1.09 399.03 MWD+IFR2+MS+sag(2) 4,231.28 70.01 259.27 3,142.33 3,086.13 85.53 -2,017.11 6,031,149.96 467,809.57 1.24 438.42 MWD+IFR2+MS+sag(2) 4,326.25 70.46 258.64 3,174.45 3,118.25 68.41 -2,104.83 6,031,133.19 467,721.79 0.78 477.62 MWD+IFR2+MS+sag(2) 4,421.27 70.63 258.51 3,206.10 3,149.90 50.66 -2,192.64 6,031,115.80 467,633.91 0.22 517.45 MWD+IFR2+MS+sag(2) 4,516.95 70.67 258.35 3,237.80 3,181.60 32.55 -2,281.09 6,031,098.06 467,545.41 0.16 557.79 MWD+IFR2+MS+sag(2) 4,612.64 70.46 259.48 3,269.64 3,213.44 15.20 -2,369.64 6,031,081.07 467,456.79 1.14 597.42 MWD+IFR2+MS+sag(2) 4,710.05 71.86 259.82 3,301.09 3,244.89 -1.36 -2,460.33 6,031,064.88 467,366.05 1.47 636.85 MWD+IFR2+MS+sag(3) 4,803.06 71.54 259.66 3,330.30 3,274.10 -17.09 -2,547.22 6,031,049.50 467,279.10 0.38 674.49 MWD+IFR2+MS+sag(3) 4,898.59 71.16 259.30 3,360.85 3,304.65 -33.61 -2,636.21 6,031,033.34 467,190.05 0.53 713.44 MWD+IFR2+MS+sag(3) 4,994.01 70.97 259.96 3,391.81 3,335.61 -49.86 -2,724.99 6,031,017.46 467,101.21 0.68 752.07 MWD+IFR2+MS+sag(3) 5,088.97 70.57 259.98 3,423.09 3,366.89 -65.47 -2,813.29 6,031,002.20 467,012.87 0.42 789.96 MWD+IFR2+MS+sag(3) 5,186.08 70.17 260.76 3,455.71 3,399.51 -80.78 -2,903.46 6,030,987.27 466,922.64 0.86 828.04 MWD+IFR2+MS+sag(3) 5,278.62 70.69 260.22 3,486.71 3,430.51 -95.18 -2,989.46 6,030,973.21 466,836.59 0.79 864.17 MWD+IFR2+MS+sag(3) 5,376.29 71.16 259.12 3,518.63 3,462.43 -111.74 -3,080.26 6,030,957.03 466,745.73 1.17 903.62 MWD+IFR2+MS+sag(3) 5,469.55 70.84 256.79 3,548.99 3,492.79 -130.13 -3,166.50 6,030,938.98 466,659.43 2.39 943.67 MWD+IFR2+MS+sag(3) 5,564.83 70.64 255.55 3,580.42 3,524.22 -151.63 -3,253.83 6,030,917.84 466,572.02 1.25 987.00 MWD+IFR2+MS+sag(3) 5,659.60 70.97 254.92 3,611.58 3,555.38 -174.44 -3,340.38 6,030,895.38 466,485.39 0.72 1,031.39 MWD+IFR2+MS+sag(3) 5,754.46 70.75 254.41 3,642.69 3,586.49 -198.14 -3,426.80 6,030,872.04 466,398.88 0.56 1,076.61 MWD+IFR2+MS+sag(3) 5,848.47 70.70 254.77 3,673.72 3,617.52 -221.72 -3,512.35 6,030,848.81 466,313.24 0.37 1,121.49 MWD+IFR2+MS+sag(3) 5,943.87 70.12 255.24 3,705.71 3,649.51 -244.98 -3,599.17 6,030,825.91 466,226.34 0.76 1,166.38 MWD+IFR2+MS+sag(3) 6,040.89 70.30 255.87 3,738.55 3,682.35 -267.75 -3,687.57 6,030,803.50 466,137.85 0.64 1,211.21 MWD+IFR2+MS+sag(3) 6,135.45 70.37 257.19 3,770.38 3,714.18 -288.49 -3,774.17 6,030,783.11 466,051.18 1.32 1,253.62 MWD+IFR2+MS+sag(3) 6,231.22 70.89 258.90 3,802.14 3,745.94 -307.20 -3,862.55 6,030,764.76 465,962.73 1.77 1,294.53 MWD+IFR2+MS+sag(3) 6,325.15 71.08 260.28 3,832.75 3,776.55 -323.25 -3,949.89 6,030,749.07 465,875.34 1.40 1,332.59 MWD+IFR2+MS+sag(3) 6,421.02 70.77 260.20 3,864.08 3,807.88 -338.61 -4,039.19 6,030,734.07 465,785.99 0.33 1,370.49 MWD+IFR2+MS+sag(3) 6,516.19 70.75 260.29 3,895.44 3,839.24 -353.83 -4,127.74 6,030,719.21 465,697.38 0.09 1,408.08 MWD+IFR2+MS+sag(3) 6,613.33 70.35 260.71 3,927.79 3,871.59 -368.95 -4,218.08 6,030,704.46 465,606.99 0.58 1,446.02 MWD+IFR2+MS+sag(3) 6,706.26 70.37 261.96 3,959.02 3,902.82 -382.14 -4,304.60 6,030,691.63 465,520.42 1.27 1,481.10 MWD+IFR2+MS+sag(3) 6,800.98 70.63 260.84 3,990.64 3,934.44 -395.49 -4,392.89 6,030,678.63 465,432.10 1.15 1,516.81 MWD+IFR2+MS+sag(3) 6,896.38 70.76 261.31 4,022.18 3,965.98 -409.46 -4,481.83 6,030,665.03 465,343.11 0.48 1,553.28 MWD+IFR2+MS+sag(3) 6,992.18 70.91 260.31 4,053.63 3,997.43 -423.91 -4,571.16 6,030,650.94 465,253.73 1.00 1,590.31 MWD+IFR2+MS+sag(3) 7,088.03 71.15 259.90 4,084.79 4,028.59 -439.49 -4,660.45 6,030,635.73 465,164.38 0.48 1,628.43 MWD+IFR2+MS+sag(3) 7,182.18 71.35 259.30 4,115.05 4,058.85 -455.58 -4,748.14 6,030,619.99 465,076.64 0.64 1,666.63 MWD+IFR2+MS+sag(3) 7,277.41 71.34 257.39 4,145.52 4,089.32 -473.81 -4,836.50 6,030,602.13 464,988.21 1.90 1,707.06 MWD+IFR2+MS+sag(3) 7,372.56 70.96 257.20 4,176.26 4,120.06 -493.61 -4,924.35 6,030,582.68 464,900.30 0.44 1,748.88 MWD+IFR2+MS+sag(3) 10/19/2010 3:38:19PM Page 4 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,468.27 70.82 257.82 4,207.59 4,151.39 -513.17 -5,012.64 6,030,563.48 464,811.93 0.63 1,790.59 MWD+IFR2+MS+sag(3) 7,563.47 70.03 257.84 4,239.49 4,183.29 -532.08 -5,100.32 6,030,544.93 464,724.19 0.83 1,831.50 MWD+IFR2+MS+sag(3) 7,658.61 70.36 258.45 4,271.72 4,215.52 -550.47 -5,187.92 6,030,526.90 464,636.52 0.70 1,871.90 MWD+IFR2+MS+sag(3) 7,754.46 70.37 258.66 4,303.93 4,247.73 -568.38 -5,276.41 6,030,509.35 464,547.97 0.21 1,912.06 MWD+IFR2+MS+sag(3) 7,848.82 70.25 259.03 4,335.72 4,279.52 -585.57 -5,363.57 6,030,492.52 464,460.75 0.39 1,951.18 MWD+IFR2+MS+sag(3) I 7,945.27 70.68 259.62 4,367.98 4,311.78 -602.41 -5,452.89 6,030,476.04 464,371.37 0.73 1,990.52 MWD+IFR2+MS+sag(3) 8,038.91 70.82 259.69 4,398.85 4,342.65 -618.28 -5,539.86 6,030,460.52 464,284.34 0.17 2,028.32 MWD+IFR2+MS+sag(3) 8,134.96 70.96 260.58 4,430.29 4,374.09 -633.83 -5,629.28 6,030,445.34 464,194.88 0.89 2,066.43 MWD+IFR2+MS+sag(3) 8,230.17 71.28 260.76 4,461.10 4,404.90 -648.43 -5,718.17 6,030,431.10 464,105.93 0.38 2,103.51 MWD+IFR2+MS+sag(3) 8,324.98 71.15 260.58 4,491.63 4,435.43 -662.99 -5,806.74 6,030,416.91 464,017.31 0.23 2,140.44 MWD+IFR2+MS+sag(3) 8,420.04 70.82 260.48 4,522.60 4,466.40 -677.77 -5,895.39 6,030,402.48 463,928.61 0.36 2,177.63 MWD+IFR2+MS+sag(3) 8,515.53 70.29 260.55 4,554.39 4,498.19 -692.61 -5,984.20 6,030,388.00 463,839.75 0.56 2,214.90 MWD+IFR2+MS+sag(3) 8,609.58 70.82 260.71 4,585.70 4,529.50 -707.05 -6,071.71 6,030,373.92 463,752.20 0.59 2,251.46 MWD+IFR2+MS+sag(3) 8,705.65 71.28 260.48 4,616.90 4,560.70 -721.90 -6,161.35 6,030,359.44 463,662.51 0.53 2,288.96 MWD+IFR2+MS+sag(3) 8,801.16 71.66 259.31 4,647.26 4,591.06 -737.79 -6,250.50 6,030,343.91 463,573.30 1.23 2,327.33 MWD+IFR2+MS+sag(3) 8,896.34 70.45 258.87 4,678.16 4,621.96 -754.82 -6,338.89 6,030,327.24 463,484.84 1.34 2,366.63 MWD+IFR2+MS+sag(3) 8,991.27 70.09 258.28 4,710.20 4,654.00 -772.52 -6,426.48 6,030,309.89 463,397.20 0.70 2,406.35 MWD+IFR2+MS+sag(3) 9,086.77 70.30 258.61 4,742.56 4,686.36 -790.52 -6,514.51 6,030,292.26 463,309.10 0.39 2,446.48 MWD+IFR2+MS+sag(3) 9,182.69 70.49 258.53 4,774.75 4,718.55 -808.43 -6,603.08 6,030,274.71 463,220.47 0.21 2,486.65 MWD+IFR2+MS+sag(3) 9,277.16 70.87 258.94 4,806.00 4,749.80 -825.84 -6,690.51 6,030,257.65 463,132.98 0.57 2,526.06 MWD+IFR2+MS+sag(3) 9,372.89 69.98 259.04 4,838.07 4,781.87 -843.07 -6,779.05 6,030,240.79 463,044.38 0.93 2,565.57 MWD+IFR2+MS+sag(3) 9,467.20 70.36 259.56 4,870.07 4,813.87 -859.54 -6,866.22 6,030,224.67 462,957.15 0.66 2,604.00 MWD+IFR2+MS+sag(3) 9,563.91 71.00 259.30 4,902.06 4,845.86 -876.28 -6,955.93 6,030,208.30 462,867.38 0.71 2,643.35 MWD+IFR2+MS+sag(3) 9,659.05 71.01 258.16 4,933.03 4,876.83 -893.86 -7,044.16 6,030,191.08 462,779.09 1.13 2,683.13 MWD+IFR2+MS+sag(3) 9,752.68 70.89 257.04 4,963.59 4,907.39 -912.87 -7,130.59 6,030,172.43 462,692.59 1.14 2,723.81 MWD+IFR2+MS+sag(3) 9,849.04 71.03 257.88 4,995.03 4,938.83 -932.64 -7,219.51 6,030,153.01 462,603.60 0.84 2,765.89 MWD+IFR2+MS+sag(3) 9,943.96 71.22 258.20 5,025.73 4,969.53 -951.25 -7,307.37 6,030,134.76 462,515.67 0.38 2,806.56 MWD+IFR2+MS+sag(3) 10,039.79 70.31 256.57 5,057.31 5,001.11 -971.01 -7,395.67 6,030,115.36 462,427.31 1.87 2,848.46 MWD+IFR2+MS+sag(3) 10,134.14 71.07 253.76 5,088.51 5,032.31 -993.81 -7,481.73 6,030,092.91 462,341.16 2.92 2,892.71 MWD+IFR2+MS+sag(3) 10,229.16 71.22 250.69 5,119.23 5,063.03 -1,021.26 -7,567.34 6,030,065.82 462,255.45 3.06 2,941.35 MWD+IFR2+MS+sag(3) 10,324.49 71.07 247.66 5,150.04 5,093.84 -1,053.33 -7,651.65 6,030,034.10 462,171.02 3.01 2,994.10 MWD+IFR2+MS+sag(3) 10,419.51 70.82 244.06 5,181.07 5,124.87 -1,090.05 -7,733.60 6,029,997.71 462,088.93 3.59 3,050.74 MWD+IFR2+MS+sag(3) 10,508.96 70.45 240.96 5,210.74 5,154.54 -1,128.99 -7,808.45 6,029,959.07 462,013.93 3.30 3,107.70 MWD+IFR2+MS+sag(3) 10,610.40 70.69 236.81 5,244.49 5,188.29 -1,178.42 -7,890.32 6,029,909.99 461,931.86 3.87 3,176.60 MWD+IFR2+MS+sag(3) 10,705.79 71.54 232.94 5,275.38 5,219.18 -1,230.34 -7,964.12 6,029,858.37 461,857.86 3.94 3,245.82 MWD+IFR2+MS+sag(3) 10,800.97 70.83 229.60 5,306.08 5,249.88 -1,286.69 -8,034.40 6,029,802.31 461,787.37 3.40 3,318.42 MWD+IFR2+MS+sag(3) 10,895.62 70.57 224.59 5,337.39 5,281.19 -1,347.48 -8,099.81 6,029,741.79 461,721.72 5.00 3,394.04 MWD+IFR2+MS+sag(3) 10,949.10 70.78 223.14 5,355.08 5,298.88 -1,383.87 -8,134.78 6,029,705.55 461,686.61 2.59 3,438.22 MWD+IFR2+MS+sag(3) 11,042.53 71.73 222.09 5,385.11 5,328.91 -1,448.98 -8,194.68 6,029,640.69 461,626.45 1.47 3,516.59 MWD+IFR2+MS+sag(4) i 11,088.41 71.75 221.46 5,399.48 5,343.28 -1,481.47 -8,223.70 6,029,608.32 461,597.29 1.30 3,555.48 MWD+IFR2+MS+sag(4) 10/19/2010 3:38:19PM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,183.91 70.74 219.27 5,430.19 5,373.99 -1,550.36 -8,282.27 6,029,539.67 461,538.45 2.42 3,637.16 MWD+IFR2+MS+sag(4) 11,279.14 71.02 215.72 5,461.39 5,405.19 -1,621.74 -8,337.02 6,029,468.53 461,483.41 3.53 3,720.26 MWD+IFR2+MS+sag(4) 11,373.84 71.41 212.82 5,491.89 5,435.69 -1,695.82 -8,387.50 6,029,394.66 461,432.64 2.93 3,804.87 MWD+IFR2+MS+sag(4) 11,469.31 71.08 209.09 5,522.60 5,466.40 -1,773.33 -8,433.99 6,029,317.35 461,385.84 3.72 3,891.75 MWD+IFR2+MS+sag(4) 11,565.32 70.57 205.46 5,554.14 5,497.94 -1,853.91 -8,475.54 6,029,236.94 461,343.97 3.61 3,980.33 MWD+IFR2+MS+sag(4) 11,660.83 72.20 201.49 5,584.64 5,528.44 -1,936.91 -8,511.57 6,029,154.10 461,307.60 4.29 4,069.83 MWD+IFR2+MS+sag(4) 11,755.15 72.84 198.69 5,612.98 5,556.78 -2,021.39 -8,542.47 6,029,069.75 461,276.37 2.91 4,159.43 MWD+IFR2+MS+sag(4) 11,850.51 73.61 195.85 5,640.51 5,584.31 -2,108.57 -8,569.57 6,028,982.69 461,248.92 2.96 4,250.64 MWD+IFR2+MS+sag(4) 11,946.56 73.95 192.22 5,667.34 5,611.14 -2,198.03 -8,591.93 6,028,893.34 461,226.20 3.65 4,342.84 MWD+IFR2+MS+sag(4) 12,042.13 73.74 188.24 5,693.94 5,637.74 -2,288.34 -8,608.23 6,028,803.10 461,209.53 4.01 4,434.30 MWD+IFR2+MS+sag(4) 12,136.56 73.79 184.72 5,720.35 5,664.15 -2,378.41 -8,618.46 6,028,713.08 461,198.94 3.58 4,523.95 MWD+IFR2+MS+sag(4) 12,231.94 74.12 183.17 5,746.72 5,690.52 -2,469.86 -8,624.76 6,028,621.67 461,192.26 1.60 4,613.92 MWD+IFR2+MS+sag(4) 12,326.15 73.47 181.03 5,773.01 5,716.81 -2,560.26 -8,628.08 6,028,531.29 461,188.58 2.29 4,702.11 MWD+IFR2+MS+sag(4) 12,421.45 73.28 179.34 5,800.28 5,744.08 -2,651.57 -8,628.38 6,028,439.99 461,187.91 1.71 4,790.40 MWD+IFR2+MS+sag(4) 12,516.10 74.76 177.01 5,826.34 5,770.14 -2,742.50 -8,625.47 6,028,349.05 461,190.45 2.84 4,877.50 MWD+IFR2+MS+sag(4) 12,612.64 75.21 175.12 5,851.35 5,795.15 -2,835.52 -8,619.07 6,028,256.02 461,196.47 1.95 4,965.71 MWD+IFR2+MS+sag(4) 12,707.53 74.31 172.56 5,876.30 5,820.10 -2,926.54 -8,609.25 6,028,164.97 461,205.92 2.77 5,051.10 MWD+IFR2+MS+sag(4) 12,797.87 74.71 170.43 5,900.43 5,844.23 -3,012.63 -8,596.38 6,028,078.84 461,218.44 2.31 5,130.95 MWD+IFR2+MS+sag(4) 12,897.12 74.83 166.63 5,926.51 5,870.31 -3,106.47 -8,577.34 6,027,984.94 461,237.10 3.70 5,216.68 MWD+IFR2+MS+sag(4) 12,993.65 75.07 163.20 5,951.58 5,895.38 -3,196.46 -8,553.08 6,027,894.86 461,260.99 3.44 5,297.35 MWD+IFR2+MS+sag(4) 13,090.13 76.50 158.81 5,975.28 5,919.08 -3,284.86 -8,522.64 6,027,806.34 461,291.07 4.65 5,374.89 MWD+IFR2+MS+sag(4) 13,183.84 76.56 155.90 5,997.12 5,940.92 -3,368.96 -8,487.55 6,027,722.11 461,325.81 3.02 5,447.07 MWD+IFR2+MS+sag(4) 13,278.88 76.22 153.10 6,019.48 5,963.28 -3,452.32 -8,447.79 6,027,638.59 461,365.23 2.89 5,517.33 MWD+IFR2+MS+sag(4) 13,373.87 76.86 151.23 6,041.60 5,985.40 -3,534.01 -8,404.66 6,027,556.74 461,408.03 2.03 5,585.10 MWD+IFR2+MS+sag(4) 13,468.91 77.43 149.40 6,062.74 6,006.54 -3,614.50 -8,358.77 6,027,476.07 461,453.58 1.97 5,651.01 MWD+IFR2+MS+sag(4) 13,564.20 77.50 146.25 6,083.43 6,027.23 -3,693.22 -8,309.24 6,027,397.16 461,502.78 3.23 5,714.27 MWD+IFR2+MS+sag(4) 13,658.27 78.51 143.53 6,102.98 6,046.78 -3,768.48 -8,256.32 6,027,321.69 461,555.39 3.03 5,773.31 MWD+IFR2+MS+sag(4) 13,753.68 78.76 142.94 6,121.78 6,065.58 -3,843.42 -8,200.34 6,027,246.54 461,611.07 0.66 5,831.23 MWD+IFR2+MS+sag(4) 13,848.63 79.02 142.71 6,140.08 6,083.88 -3,917.66 -8,144.04 6,027,172.08 461,667.06 0.36 5,888.41 MWD+IFR2+MS+sag(4) 13,944.20 79.65 142.01 6,157.77 6,101.57 -3,992.03 -8,086.68 6,027,097.48 461,724.11 0.98 5,945.44 MWD+IFR2+MS+sag(4) 14,038.97 80.15 139.71 6,174.39 6,118.19 -4,064.38 -8,027.79 6,027,024.89 461,782.70 2.45 6,000.13 MWD+IFR2+MS+sag(4) 14,070.86 80.28 139.78 6,179.81 6,123.61 -4,088.37 -8,007.49 6,027,000.83 461,802.91 0.46 6,018.05 MWD+IFR2+MS+sag(4) 14,156.32 80.88 139.42 6,193.80 6,137.60 -4,152.57 -7,952.84 6,026,936.41 461,857.28 0.82 6,065.96 MWD+IFR2+MS+sag(5) 14,180.00 81.81 139.36 6,197.36 6,141.16 -4,170.34 -7,937.61 6,026,918.58 461,872.44 3.94 6,079.20 MWD+IFR2+MS+sag(5) 14,219.23 80.07 138.64 6,203.54 6,147.34 -4,199.58 -7,912.19 6,026,889.24 461,897.74 4.79 6,100.87 MWD+IFR2+MS+sag(6) 14,315.03 85.35 136.60 6,215.69 6,159.49 -4,269.74 -7,848.16 6,026,818.83 461,961.48 5.90 6,152.11 MWD+IFR2+MS+sag(6) 14,412.28 90.36 136.54 6,219.33 6,163.13 -4,340.29 -7,781.37 6,026,748.02 462,027.97 5.15 6,203.02 MWD+IFR2+MS+sag(6) 14,508.63 90.30 129.73 6,218.77 6,162.57 -4,406.13 -7,711.10 6,026,681.90 462,097.97 7.07 6,248.47 MWD+IFR2+MS+sag(6) 14,539.96 90.24 127.31 6,218.62 6,162.42 -4,425.64 -7,686.59 6,026,662.30 462,122.40 7.73 6,260.99 MWD+IFR2+MS+sag(6) 14,572.04 90.11 124.94 6,218.53 6,162.33 -4,444.55 -7,660.68 6,026,643.28 462,148.23 7.40 6,272.56 MWD+IFR2+MS+sag(6) 10/19/2010 3:38:19PM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,605.35 89.74 121.34 6,218.57 6,162.37 -4,462.76 -7,632.79 6,026,624.96 462,176.04 10.86 6,282.95 MWD+IFR2+MS+sag(6) 14,636.51 89.93 119.87 6,218.66 6,162.46 -4,478.62 -7,605.98 6,026,608.99 462,202.79 4.76 6,291.34 MWD+IFR2+MS+sag(6) 14,669.14 89.99 117.83 6,218.68 6,162.48 -4,494.36 -7,577.40 6,026,593.13 462,231.30 6.25 6,299.17 MWD+IFR2+MS+sag(6) 14,700.74 90.24 117.02 6,218.62 6,162.42 -4,508.92 -7,549.35 6,026,578.47 462,259.29 2.68 6,305.99 MWD+IFR2+MS+sag(6) 14,797.43 92.09 119.50 6,216.65 6,160.45 -4,554.68 -7,464.21 6,026,532.36 462,344.23 3.20 6,328.21 MWD+IFR2+MS+sag(6) 14,893.76 91.35 125.17 6,213.76 6,157.56 -4,606.16 -7,382.89 6,026,480.56 462,425.33 5.93 6,356.93 MWD+IFR2+MS+sag(6) 14,990.76 90.67 128.86 6,212.05 6,155.85 -4,664.54 -7,305.46 6,026,421.87 462,502.51 3.87 6,393.33 MWD+IFR2+MS+sag(6) 15,087.17 89.25 130.69 6,212.12 6,155.92 -4,726.21 -7,231.37 6,026,359.90 462,576.35 2.40 6,433.77 MWD+IFR2+MS+sag(6) 15,183.95 90.11 135.01 6,212.66 6,156.46 -4,792.02 -7,160.44 6,026,293.82 462,647.01 4.55 6,479.02 MWD+IFR2+MS+sag(6) 15,279.90 87.14 136.50 6,214.96 6,158.76 -4,860.72 -7,093.52 6,026,224.85 462,713.64 3.46 6,528.10 MWD+IFR2+MS+sag(6) 15,376.12 86.71 140.58 6,220.12 6,163.92 -4,932.71 -7,029.92 6,026,152.61 462,776.94 4.26 6,581.22 MWD+IFR2+MS+sag(6) 15,472.70 89.19 142.34 6,223.58 6,167.38 -5,008.20 -6,969.79 6,026,076.89 462,836.76 3.15 6,638.61 MWD+IFR2+MS+sag(6) I 15,569.44 90.85 142.14 6,223.54 6,167.34 -5,084.67 -6,910.55 6,026,000.18 462,895.68 1.73 6,697.19 MWD+IFR2+MS+sag(6) 15,665.85 91.04 138.06 6,221.95 6,165.75 -5,158.61 -6,848.73 6,025,926.00 462,957.19 4.24 6,752.65 MWD+IFR2+MS+sag(6) 15,762.67 91.53 137.47 6,219.78 6,163.58 -5,230.28 -6,783.67 6,025,854.08 463,021.96 0.79 6,805.08 MWD+IFR2+MS+sag(6) 15,859.02 90.54 138.46 6,218.04 6,161.84 -5,301.83 -6,719.16 6,025,782.27 463,086.16 1.45 6,857.54 MWD+IFR2+MS+sag(6) 15,955.65 90.48 137.69 6,217.18 6,160.98 -5,373.72 -6,654.60 6,025,710.13 463,150.42 0.80 6,910.31 MWD+IFR2+MS+sag(6) 16,050.92 91.10 138.45 6,215.87 6,159.67 -5,444.59 -6,590.95 6,025,639.01 463,213.78 1.03 6,962.33 MWD+IFR2+MS+sag(6) 16,147.19 88.63 138.41 6,216.09 6,159.89 -5,516.61 -6,527.07 6,025,566.74 463,277.36 2.57 7,015.41 MWD+IFR2+MS+sag(6) 16,241.79 86.90 139.96 6,219.78 6,163.58 -5,588.14 -6,465.29 6,025,494.96 463,338.84 2.45 7,068.56 MWD+IFR2+MS+sag(6) 16,338.30 87.64 141.67 6,224.38 6,168.18 -5,662.86 -6,404.39 6,025,420.00 463,399.44 1.93 7,125.01 MWD+IFR2+MS+sag(6) 16,437.25 88.26 141.62 6,227.92 6,171.72 -5,740.40 -6,343.03 6,025,342.22 463,460.48 0.63 7,184.07 MWD+IFR2+MS+sag(6) 16,533.51 87.08 140.09 6,231.83 6,175.63 -5,814.99 -6,282.31 6,025,267.39 463,520.88 2.01 7,240.45 MWD+IFR2+MS+sag(6) 16,629.54 87.21 140.64 6,236.62 6,180.42 -5,888.86 -6,221.13 6,025,193.29 463,581.76 0.59 7,296.00 MWD+IFR2+MS+sag(6) 16,726.75 87.82 143.00 6,240.83 6,184.63 -5,965.19 -6,161.10 6,025,116.71 463,641.47 2.51 7,354.24 MWD+IFR2+MS+sag(6) 16,822.82 88.88 142.27 6,243.60 6,187.40 -6,041.52 -6,102.82 6,025,040.16 463,699.43 1.34 7,412.91 MWD+IFR2+MS+sag(6) 16,919.83 89.62 138.83 6,244.87 6,188.67 -6,116.41 -6,041.20 6,024,965.03 463,760.75 3.63 7,469.35 MWD+IFR2+MS+sag(6) 17,016.37 91.16 137.83 6,244.21 6,188.01 -6,188.52 -5,977.02 6,024,892.67 463,824.62 1.90 7,522.43 MWD+IFR2+MS+sag(6) 17,112.58 93.33 138.82 6,240.44 6,184.24 -6,260.32 -5,913.10 6,024,820.62 463,888.24 2.48 7,575.28 MWD+IFR2+MS+sag(6) 17,207.86 92.40 138.80 6,235.68 6,179.48 -6,331.93 -5,850.43 6,024,748.76 463,950.61 0.98 7,628.27 MWD+IFR2+MS+sag(6) 17,304.97 91.78 139.00 6,232.14 6,175.94 -6,405.06 -5,786.64 6,024,675.38 464,014.11 0.67 7,682.44 MWD+IFR2+MS+sag(6) 17,402.92 89.80 138.06 6,230.79 6,174.59 -6,478.44 -5,721.78 6,024,601.74 464,078.66 2.24 7,736.58 MWD+IFR2+MS+sag(6) 17,498.27 92.95 138.26 6,228.50 6,172.30 -6,549.45 -5,658.21 6,024,530.48 464,141.94 3.31 7,788.76 MWD+IFR2+MS+sag(6) 17,594.02 89.31 137.60 6,226.61 6,170.41 -6,620.50 -5,594.07 6,024,459.18 464,205.78 3.86 7,840.83 MWD+IFR2+MS+sag(6) 17,691.58 87.45 136.52 6,229.37 6,173.17 -6,691.89 -5,527.64 6,024,387.53 464,271.91 2.20 7,892.64 MWD+IFR2+MS+sag(6) 17,787.04 83.92 135.15 6,236.55 6,180.35 -6,760.16 -5,461.34 6,024,319.00 464,337.93 3.97 7,941.46 MWD+IFR2+MS+sag(6) 17,883.33 84.85 140.05 6,245.98 6,189.78 -6,830.90 -5,396.74 6,024,248.00 464,402.23 5.16 7,993.12 MWD+IFR2+MS+sag(6) 17,980.12 88.20 143.96 6,251.85 6,195.65 -6,907.02 -5,337.29 6,024,171.65 464,461.36 5.31 8,051.30 MWD+IFR2+MS+sag(6) 18,076.70 89.19 142.40 6,254.05 6,197.85 -6,984.31 -5,279.43 6,024,094.13 464,518.91 1.91 8,111.02 MWD+IFR2+MS+sag(6) 18,173.14 90.36 139.86 6,254.43 6,198.23 -7,059.38 -5,218.92 6,024,018.82 464,579.11 2.90 8,167.91 MWD+IFR2+MS+sag(6) 10/19/2010 3:38:19PM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) MINT) (ft) Survey Tool Name 18,269.89 93.08 141.32 6,251.52 6,195.32 -7,134.09 -5,157.53 6,023,943.87 464,640.19 3.19 8,224.23 MWD+IFR2+MS+sag(6) 18,365.72 93.82 139.93 6,245.76 6,189.56 -7,208.03 -5,096.85 6,023,869.69 464,700.57 1.64 8,279.99 MWD+IFR2+MS+sag(6) 18,462.13 92.71 136.43 6,240.26 6,184.06 -7,279.75 -5,032.67 6,023,797.72 464,764.44 3.80 8,332.69 MWD+IFR2+MS+sag(6) 18,558.62 91.04 133.64 6,237.11 6,180.91 -7,347.98 -4,964.53 6,023,729.23 464,832.30 3.37 8,381.00 MWD+IFR2+MS+sag(6) 18,655.38 91.47 133.37 6,234.99 6,178.79 -7,414.57 -4,894.37 6,023,662.35 464,902.18 0.52 8,427.21 MWD+IFR2+MS+sag(6) 18,751.33 86.83 134.17 6,236.41 6,180.21 -7,480.92 -4,825.11 6,023,595.73 464,971.17 4.91 8,473.42 MWD+IFR2+MS+sag(6) 18,848.17 87.27 136.42 6,241.39 6,185.19 -7,549.65 -4,757.08 6,023,526.73 465,038.91 2.36 8,522.24 MWD+IFR2+MS+sag(6) 18,944.77 87.15 136.11 6,246.10 6,189.90 -7,619.37 -4,690.38 6,023,456.75 465,105.32 0.34 8,572.36 MWD+IFR2+MS+sag(6) 19,040.81 86.65 135.73 6,251.29 6,195.09 -7,688.26 -4,623.66 6,023,387.60 465,171.75 0.65 8,621.68 MWD+IFR2+MS+sag(6) 19,137.97 85.84 135.04 6,257.65 6,201.45 -7,757.27 -4,555.57 6,023,318.32 465,239.55 1.09 8,670.77 MWD+IFR2+MS+sag(6) 19,234.67 87.39 135.97 6,263.36 6,207.16 -7,826.13 -4,487.92 6,023,249.19 465,306.91 1.87 8,719.81 MWD+IFR2+MS+sag(6) 19,330.50 89.80 136.28 6,265.71 6,209.51 -7,895.18 -4,421.53 6,023,179.88 465,373.02 2.54 8,769.37 MWD+IFR2+MS+sag(6) 19,426.67 91.66 135.67 6,264.49 6,208.29 -7,964.32 -4,354.70 6,023,110.47 465,439.56 2.04 8,818.90 MWD+IFR2+MS+sag(6) 19,522.98 92.16 132.30 6,261.28 6,205.08 -8,031.16 -4,285.45 6,023,043.36 465,508.53 3.54 8,865.58 MWD+IFR2+MS+sag(6) 19,619.59 90.91 131.14 6,258.69 6,202.49 -8,095.43 -4,213.37 6,022,978.81 465,580.34 1.76 8,909.05 MWD+IFR2+MS+sag(6) 19,715.94 89.80 131.63 6,258.09 6,201.89 -8,159.12 -4,141.08 6,022,914.83 465,652.36 1.26 8,951.91 MWD+IFR2+MS+sag(6) 19,811.89 90.36 133.43 6,257.96 6,201.76 -8,223.98 -4,070.38 6,022,849.69 465,722.80 1.96 8,996.30 MWD+IFR2+MS+sag(6) 19,908.75 92.58 134.72 6,255.47 6,199.27 -8,291.33 -4,000.82 6,022,782.07 465,792.07 2.65 9,043.39 MWD+IFR2+MS+sag(6) 20,005.66 92.15 134.88 6,251.47 6,195.27 -8,359.55 -3,932.11 6,022,713.57 465,860.49 0.47 9,091.56 MWD+IFR2+MS+sag(6) 20,101.60 93.14 133.20 6,247.05 6,190.85 -8,426.17 -3,863.23 6,022,646.68 465,929.11 2.03 9,138.12 MWD+IFR2+MS+sag(6) 20,132.81 90.60 130.82 6,246.03 6,189.83 -8,447.05 -3,840.05 6,022,625.71 465,952.19 11.15 9,152.30 MWD+IFR2+MS+sag(6) 20,165.99 87.02 128.94 6,246.72 6,190.52 -8,468.31 -3,814.60 6,022,604.34 465,977.56 12.19 9,166.27 MWD+IFR2+MS+sag(6) 20,198.58 86.90 128.59 6,248.44 6,192.24 -8,488.69 -3,789.22 6,022,583.87 466,002.85 1.13 9,179.40 MWD+IFR2+MS+sag(6) 20,230.18 86.90 129.37 6,250.15 6,193.95 -8,508.54 -3,764.70 6,022,563.92 466,027.29 2.46 9,192.24 MWD+IFR2+MS+sag(6) 20,294.32 86.15 129.77 6,254.04 6,197.84 -8,549.32 -3,715.35 6,022,522.94 466,076.47 1.32 9,218.89 MWD+IFR2+MS+sag(6) 20,390.67 85.23 131.37 6,261.28 6,205.08 -8,611.80 -3,642.37 6,022,460.17 466,149.19 1.91 9,260.40 MWD+IFR2+MS+sag(6) 20,487.78 86.77 135.46 6,268.06 6,211.86 -8,678.37 -3,572.02 6,022,393.33 466,219.26 4.49 9,306.54 MWD+IFR2+MS+sag(6) 20,583.93 87.39 136.11 6,272.96 6,216.76 -8,747.19 -3,505.05 6,022,324.24 466,285.93 0.93 9,355.73 MWD+IFR2+MS+sag(6) 20,680.93 88.32 135.47 6,276.59 6,220.39 -8,816.67 -3,437.47 6,022,254.49 466,353.23 1.16 9,405.39 MWD+IFR2+MS+sag(6) 20,777.24 86.90 133.03 6,280.60 6,224.40 -8,883.81 -3,368.55 6,022,187.08 466,421.87 2.93 9,452.45 MWD+IFR2+MS+sag(6) 20,873.16 86.47 131.60 6,286.15 6,229.95 -8,948.28 -3,297.74 6,022,122.34 466,492.41 1.55 9,496.43 MWD+IFR2+MS+sag(6) 20,917.84 87.45 131.30 6,288.52 6,232.32 -8,977.81 -3,264.30 6,022,092.67 466,525.73 2.29 9,516.33 MWD+IFR2+MS+sag(6) 20,952.00 87.45 131.30 6,290.04 6,233.84 -9,000.33 -3,238.66 6,022,070.04 466,551.27 0.00 9,531.46 PROJECTED to TD 10/19/2010 3:38:19PM Page 8 COMPASS 2003.16 Build 42F S1TAITE [1 [F dELa 6 SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Alex Vaughan Operations Drilling Manager Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-17L1 Pioneer Natural Resources Alaska, Inc. Permit No: 210-140 Surface Location: 2940' FSL, 1172' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3923' FSL, 3742' FEL, SEC. 23, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well ODSN-17, Permit No 210- 093, API 50-703-20622-00. Production should continue to be reported as a function of the original API number stated above. 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 : ommission order, or the terms and conditions of this permit may result in the r- oc..t on or suspension of the permit. 410-$ it" . o o sioner DATED this day of September, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) F( )°'I D STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM ION P_\k'' 1 201i' PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil 2 .Service- Winj ❑ Single Zone Q lc.Specify ifLwe9lrfs'pri used for: Drill ❑ Redrill 0 Stratigraphic Test ❑ Development-Gas 0 Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket E Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 . ODSN-17L1 ` 3.Address: 700 G Street,Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 21,785' . TVD: 6246' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuiqsut Oil Pool Surface: 2940'FSL, 1172'FEL,Sec. 11,T13N, R7E, UM • ADL 355036/ADL 355038 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4180'FSL, 3930'FEL,Sec. 15,T13N, R7E, UM 417497 September 24,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3923'FSL,3742'FEL,Sec.23,T13N, R7E, UM 5760 1349' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 56.2 feet 15.Distance to Nearest Well Open Surface: x-469826.11 . y-6031056.25 . Zone-ASP 4 GL Elevation above MSL: to Same Pool: ODSN-16 is 1680' • 13.5 feet away 16.Deviated wells: Kickoff depth: 14,134 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.01 degrees Downhole: 3183 • Surface: 2484. 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6-1/8" 4-1/2" 12.6# L-80 Hyd 521 7923' 13,862' 6147' 21,785' 6246' Uncemented - - t 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 10,980 5365' N/A 10,980' 5365' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" Driven 158' 158' Surface 4621' 11-3/4" 600 sx PF'L';665 sx Class'G' 4660' 3285' Intermediate)-Drip Liner 6496' 9-5/8" 411 sx Class'G' 4333'- 10,829' 3184'-5316' Intermediate 2 13,912' 7" 197 sx Class'G' 13,955' 6147' Liner 6110' 4-1/2" Uncemented 13,722'- 19,832' 6092'-6217' Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program E 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date G/— / `I^z©►/G7 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan,343-2186 Prepared By:Kathy Campoamor,343-2183 Printed Name Alex Vaughan Title Operations Drilling Engineer Signature /j Phone 343-2186 Date 9/14/2010 Commission Use Only — Permit to Drill-l /`/( API Number Permit App v I See cover letter for other Number: 50-7C3—7Z) z_z `�1-'�4"Date: �'� requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed met�ane,g s hydrates,or gas contained in shales: [Z Other: 7A` YSDO I, s,:, Sof �S tSamples req'd: Yes 0 No g, Mud log req'd: Yes 0 No RI/4 z SoO r S,.: Ahn•A.-1 r Cf----,. ../' ,l J H2S measures: Yes❑ No Directional svy req'd: Yes 12/No 0 Ii DATE: 9.17..-/C) , APPROVED BY THE COMMISSION ,COMMISSIONER oRIL � N . - 1. /P 2.,s Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 September 14th, 2010 e- ID State of Alaska t Alaska Oil and Gas Conservation Commission �� *�,; ,ra Ssion 333 West 7thAvenue, Suite#100 ; ; k t.,..•-• Anchorage, AK 99501 't` RE: Application for Permit to Drill ODSN-17L1 Surface Location: 2940' FSL, 1172' FEL, Sec 11, T13N, R7E, UM X = 469826.11, Y = 6031056.25, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. They well is designed to be the second lateral of a multi-lateral production well in the Oooguruk- • Nuiqsut formation. PNRA requests the Permit to Drill based on approved Pool Rules. As indicated in the attachments, the drilling and well construction program includes the following: • ODSN-17L1 Production Hole: o Kick off ODSN-17 lateral @ 14,134' MD / 6,186' TVD • o Drill 6-1/8" horizontally to -21,785' MD / 6,246' TVD and set a 4-1/2" solid liner with perforated pups. • Completion: w•l( MOT 1 u r.► Fe c c- Si-gr iLy O 2-7/8" tubing w%'Sp -� ? /? / PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Production hole section of ODSN-17L1 as outlined below. • From the Intermediate 2 Shoe to ODSN-17L1 TD o Use -7.2-8.2 ppg fluid while using MPD to control pressure from the surface to -9.8-10.2 ppg EMW at the bottom of the hole during connections and while tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the ' well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. Alaska Oil&Gas Commissior September 14, 2010 Page 2 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 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 summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. /' 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) 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). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) 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. Alaska Oil &Gas Conservatic mmission September 14, 2010 Page 3 The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Drilling Superintendent (20 AAC 25.070) 907.343.2111 vern.johnson aapxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daqqettpxd.com The anticipated date for this well to continue off the originally approved ODSN-17 well (PTD #210-093) is approximately September 24th, 2010. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Operations Drilling ngineer Attachments: Form 10-401 Supporting permit information cc: ODSN-17L1 Well File Cs P N-17 & N-17L1 Proposed Completion Design Casing 1 Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 11-3/4"60#L-80 Hydril 521, 10.772" ID 4483 3239 Allill C 9-5/8"40#L-80 Hydril 521,8.835" ID" 10893 5347 6172 D 7"26#L-80 BTC-M,6.276"ID"" 14012 O E 4-1/2" 12.6#Hydril 521 3.958" ID 20095 6206 F 4-1/2" 12.6#Hydril 521 3.958" ID 21784 6246 --ts -i G 2-7/8"6.5#L-80 IBT-M 13730 6124 "Planned TOC @ 9256'MD ""Planned TOC @ 12762'MD 1 VetcoGray Tubing Hanger 34 34 G 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,000 1,954 - - 3 GLM#1 -2-7/8"x 1-1/2"(min.2 jts above top X nipple) 2,528 2,386 1K 42-7/8"X Nipple 2.313" I.D. (min.2 jts above Gas Vent 4 Valve Packer) 2,608 2,444 5 WFT 7"x 2-7/8"Gas Vent Valve Packer(max.TVD 2500') 2,688 2,500 6 GLM#2-2-7/8"x 1-1/2"(min.2 jts above X nipple) 9,800 4,988 Y3 O 2-7/8"X Nipple,2.313" ID(max.incl. 70 deg)w/RHC-M 7 Plug Body 9,900 5,021 8 Automatic Divert Valve(ADV) 13,659 6,111 4 9 ESP(Pump, Motor,and Jewelry) 13,669 6,113 0- 11.- . ►$ End of Assembly 13,730 6,124 10 WFT 7"x 3-1/2" Retrievable Packer 13,780 6,132 11 WFT 3-1/2"Sliding Sleeve 13,805 6,137 612 WFT 3-1/2"Formation Saver Valve 13,830 6,141 fJ WLEG 13,840 6,143 End of Assembly 13,845 6,144 17-7 • 4.1110.111111 13 WeatherforAluminum 14,1621 6,185 14 Resman Tracer Pup(heel location) 14,202 6,188 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), O 15 spaced every 200'. 16 Resman Tracer Pup(midlateral location) 17,129 6,197 17 Resman Tracer Pup(toe location) 20,053 6,207 $ 18 Liner Shoe(PLUGGED)w/4-1/2"Hydril 521 20,093 6,206 K__}-110'0K__}-110'0_�O O End of Assembly 20,095 6,206 N-17 L1 Item# Item MD(ft) TVD(ft) 19 WFT PBR Tie Back Sleeve 158 13,845 6,144 9 20 WFT"NTH" Liner Top Pkr 13,860 6,146 21 WFT"PHR" Rotating Hyd Set Liner Hanger 13,862 6,146 1111) Weatherford Sliding Sleeve(6)1/2"ports(-across from 22 aluminum billet) 14,162 6,188 � I _ �� 23 Oil Swell Packer(approx. 3 joints below side track point) 14,282 6,195 24 Resman Tracer Pup(heel location) 14,322 6,197 • O O 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), -• 25 spaced every 200'. �v`' 26 Resman Tracer Pup(midlateral location) 17,898 6,209 ID 27 Resman Tracer Pup(toe location) 21,744 6,246 28 Liner Shoe(PLUGGED)w/4-1/2" Hydril 521 21,782 6,246 0 ,-, •:. 01 End of Assembly 21,784 6,246 5.75"x 4-''/z' O Oil Base Swell Packer ResMan Produced Oil&Water Markers 22 / ODSN-17 Sliding 00 00 00 00 00 00 00 TD:21,784' Sleeve 23 24 0 0 (21-50 0 0 0 r 0 0 0 0 0 0 27 28 MD TVD 46 O 00 I0o 00 00 00 00 oo ODSN-17L1 2,_�gS`f`(� Aluminum Kick- Y "c/ H13 14 00 15 00 00 16 ' 00 00 00 i 17 18 MD:/6326 Off Billet 00 00001'06 00 00 00 MDD326' Date: Revision By: Comments N-17 & N-17L1 PIONEER 9/14/2010 JAD Dual Lateral Revision Proposed NATURAL RESOURCESAIASKA Completion Design Permit to Drill Well Plan Summary ODSN-17L1 Oooguruk - Nuiqsut Lateral Production Well ODSN-17L1 Lateral Kickoff @ 14,134' MD / 6,186' TVD ODSN-17L1 Lateral TD @ 21 ,785' MD / 6,246' TVD ODSN-17 Surface Location: 2940' FSL, 1172' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X=469826.11 Y=6031056.25 ODSN-17 Target: Oooguruk-Nuiqsut 4180' FSL, 3930' FEL, Sec. 15, T13N, R7E, Umiat X =461776.00 Y= 6027053.46 6168' TVDrkb Bottom Hole Location ODSN-17L1 3923' FSL, 3742' FEL, Sec. 23,T13N, R7E, Umiat X =467226.00 Y= 6021491.20 6246' TVDrkb AFE Number: 018840 Est. Start Date: Sep 24th, 2010 Rig: Nabors 19AC Operating days: 6 days to Drill and Complete Objective &Well Type Nuiqsut Development Well Well Design: Modified Slimhole (4-1/2" liner) Multi-Lateral 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: 158' MDrkb Pioneer Natural Resources Last Revised:Sep 14th,2010 ODSN-17L1 Permit To Drill Page 1 of 5 Well Control: 6-1/8" ODSN 17L1 Production Liner Hole Section: • Maximum anticipated BHP: 3183 psi @ 6246'TVD (Based on 9.8 ppg Oooguruk-Nuiqsut pore pressure) • Maximum surface pressure: 2496 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 4500 psi CP surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) . Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel 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 Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Pioneer Natural Resources Last Revised:Sep 14th,2010 ODSN-17L1 Permit To Drill Page 2 of 5 Drilling Fluids Program: Production Hole Mud Properties: 6-1/8" hole MOBM Interval Density(ppq) Viscosity(secs) YP PV ES HTHP 0/W Initial to TD 7.2 - 8.2 ppg 55 -80 12 -25 10-20 800-2000 <6 94/6 (-S. ppg via MPD) Formation Markers: Formation Tops MD (ft) TVDrkb(ft) Pore Press. EMW Comments (Psi) (ppg) Top Nuiqsut 13984 6163 3141 9.8 Top of Zone 1 7"casing point 14009 6168 3143 9.8 Second lat TD 20090 6207 3163 9.8 Logging Program: ODSN-17L1 6-1/8" Section: Drilling: Mud logging Dir/GR/Azm Res/Neut/PWD Open Hole: N/A Cased Hole: N/A ODSN-17L1 Casing Program: Hole Casing/ Weight Grade Conn. Casing CsglTbg Hole Btm Size Tubing Length Top MDrkb/TVDrkb MDrkb • H 7923 13862 21785 6246 6-1/8" 4-1/2" 12.6# L-80 52dril 1 Tubing 2-7/8" 6.4# L-80 IBT-BTC 13803 Surface 13845 6144 Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 4-1/2" 12.6# L-80 3.958" 3.833" Hydril 521 na na 289 M 289 M Pioneer Natural Resources Last Revised:Sep 14th,2010 ODSN-17L1 Permit To Drill Page 3 of 5 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Riq Work 1. 7" intermediate casing string has been set and cemented. Riq Activity: Drill and Complete ODSN-17L1 1. MU 6-1/8" RSS, MWD/LWD drilling assembly and RIH to intermediate shoe. RD MPD trip nipple and RU bearing assembly. 2. Displace heavy weight balance brine pill to drill-in-fluid. • 3. RIH to 14,134' MD and kickoff aluminum billet to drill ODSN-17L1. 4. Drill 6-1/8"ODSN-17L1 lateral production hole to TD. - 21,7S S 5. Circulate and condition hole to run liner.. 6. POH to intermediate shoe and set heavy weight balance brine pill. Cont POH to surface. 7. Change one set of pipe rams to 4-1/2" and test BOPE as required. - 8. RIH w/4-1/2"solid production liner w/perforated pups from 150' inside the intermediate shoe to TD. 9. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and •• POOH. 10. MU and RIH w/2-7/8" production completion w/ESP, packer, GLM, SSSV. • 11. Space out, Land the tubing and RILDS. Install TWC. 12. ND BOPE, NU tree and test to 5,000 psi. 13. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to • -2000'TVD and allow to u-tube. 14. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi-chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi-chart and hold for 30 minutes. Bleed off pressure. 15. RDMO to next well. . Post-Riq Work 1. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 2. RD Slickline. Pioneer Natural Resources Last Revised:Sep 14th,2010 ODSN-17L1 Permit To Drill Page 4 of 5 ODSN-17L1 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling the Nuiqsut, hold a pre-reservoir meeting to outline heightened awareness for kick detection and lost circulation. Kick Tolerance/Integrity Testing Kick Tolerance/Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press ODSN-17L1 7" Intermediate/ Infinite 7.2 8.2 ppg 3183 n/a 6-1/8" (9.8-10.2 EMW w/MPD) NOTE: All LOT/FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H2S site, however Standard Operating - Procedures for H25 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:Sep 14th,2010 ODSN-17L1 Permit To Drill Page 5 of 5 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-17 - Slot ODS-17 ODSN-17 PN13 mid L1 Plan: ODSN-17 PN13 mid L1 wp02 Standard Proposal Report 07 September, 2010 4� X4 wl� , � rf HALLIBURTON • • Sperry Drilling Services it °__ r H H ;-. Y CO ZOO > > E d N Q Q 6660000 o Q ��� 0 ; 00 — m m ++ o P f2P m o (00 �� .2Z," 000000 5 5 5 5 5 5 5 _o 4mrn l,77 1 A y 0 A A A m ono 0 0 0 o o o 728 E ot33 r O O O O O O O —s o0Z .2 ro)22 p000roMpp 00o N,emm-,00,wu+no-N,N Cn 0- - O000 0oMO0000 SM0*r ' o;m � ^ RNnm N 8.KK� '4! _ f,co tO tG th f�Oth{p CV IV tO t+i maa m mmoo� rpr�oo > COn1.Ntt,O0NM(0Nco ��o�$ � n �� 8 ��8 O fA c�N.�. N w w-1`C'))N N co N N U 10 fN.,NO @�U 0 m o oCOCO CO o CO m�o m 888m,-8,d=8a:emo`.8�08N.-S 88 —$ F ZNNC } vv 3 < vvvvvvvvvovc F 91%,6 o20oa^o�oo800 oo O)000000)0p 000 - N 0+— 'Q 33t O COOOONOnOSO NO 0** m vov 004o`4 z.t,2o Srn� 888888888$8888888 88888.8 d A 0 - EEE Q $oomi Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid Li Design: ODSN-17 PN13 mid L1 wp02 Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70°29'46.242 N From: Map Easting: 469,920.45ft Longitude: 150°14'45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23? Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.0 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +EI-W 0.0 ft Easting: 469,826.11 ft Longitude: 150° 14'48.230 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-17 PN13 mid L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (7) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 PN13 mid L1 wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 14,134.5 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) t. (ft) (ft) (7) 42.7 0.0 0.0 194.97 9/7/2010 4:15:19PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face ' (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?1100ft) (?/100ft) (?) 1 14,134.5 85.37 138.90 6,186.0 6,129.8 -4,148.0 -7,918.1 0.00 0.00 0.00 0.00 ' 14,194.5 84.55 136.63 6,191.2 6,135.0 -4,192.2 -7,877.9 4.00 -1.36 -3.78 250.00 14,394.5 90.55 132.63 6,199.8 6,143.6 -4,332.5 -7,735.8 3.60 3.00 -2.00 -33.67 14,456.2 92.01 131.50 6,198.4 6,142.2 -4,373.8 -7,690.1 3.00 2.37 -1.84 -37.77 14,879.2 92.01 131.50 6,183.6 6,127.4 -4,654.0 -7,373.4 0.00 0.00 0.00 0.00 15,013.8 90.00 128.00 6,181.2 6,125.0 -4,740.0 -7,270.0 3.00 -1.50 -2.60 -119.85 15,103.2 87.90 125.68 6,182.8 6,126.6 -4,793.6 -7,198.5 3.50 -2.35 -2.60 -132.11 15,152.5 87.90 125.68 6,184.6 6,128.4 -4,822.4 -7,158.4 0.00 0.00 0.00 0.00 15,509.6 90.00 138.00 6,191.2 6,135.0 -5,060.0 -6,893.0 3.50 0.59 3.45 80.49 15,621.7 90.67 141.30 6,190.5 6,134.3 -5,145.4 -6,820.4 3.00 0.60 2.94 78.45 16,794.8 90.67 141.30 6,176.8 6,120.6 -6,060.9 -6,086.9 0.00 0.00 0.00 0.00 16,889.6 90.00 138.53 6,176.2 6,120.0 -6,133.4 -6,025.9 3.00 -0.71 -2.91 -103.69 16,953.8 88.08 138.61 6,177.3 6,121.1 -6,181.5 -5,983.4 3.00 -3.00 0.12 177.73 18,361.7 88.08 138.61 6,224.5 6,168.3 -7,237.1 -5,053.1 0.00 0.00 0.00 0.00 18,462.4 90.00 136.28 6,226.2 6,170.0 -7,311.3 -4,985.0 3.00 1.91 -2.31 -50.52 18,491.5 90.87 136.38 6,226.0 6,169.8 -7,332.4 -4,964.8 3.00 2.98 0.35 6.61 19,423.0 90.87 136.38 6,211.9 6,155.7 -8,006.6 -4,322.3 0.00 0.00 0.00 0.00 19,508.8 90.00 133.96 6,211.2 6,155.0 -8,067.4 -4,261.8 3.00 -1.01 -2.82 -109.72 19,593.5 87.50 134.39 6,213.0 6,156.8 -8,126.4 -4,201.1 3.00 -2.96 0.51 170.19 20,376.4 87.50 134.39 6,247.2 6,191.0 -8,673.5 -3,642.2 0.00 0.00 0.00 0.00 20,557.2 90.00 129.57 6,251.2 6,195.0 -8,794.4 -3,507.8 3.00 1.38 -2.66 -62.60 20,569.0 90.23 129.57 6,251.2 6,195.0 -8,801.9 -3,498.8 2.00 2.00 0.00 0.00 21,784.9 90.23 129.57 6,246.2 • 6,190.0 -9,576.5 -2,561.5 0.00 0.00 0.00 0.00 9/7/2010 4:15:19PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 • Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,129.77 14,134.5 85.37 138.90 6,186.0 6,129.8 -4,148.0 -7,918.1 6,026,940.86 461,892.03 3.00 6,053.12 14,134.6 85.37 138.90 6,186.0 6,129.8 -4,148.1 -7,918.0 6,026,940.79 461,892.09 0.00 6,053.18 Start Dir 4°/100':14134.5'MD,6186'TVD:250°LT TF 1 14,194.5 84.55 136.63 6,191.2 6,135.0 -4,192.2 -7,877.9 6,026,896.45 461,932.01 4.01 6,085.49 Start Dir 3.6°/100':14194.5'MD,6191.2'TVD 14,200.0 84.71 136.52 6,191.8 6,135.6 -4,196.2 -7,874.2 6,026,892.46 461,935.76 3.60 6,088.36 14,300.0 87.71 134.52 6,198.4 6,142.2 -4,267.4 -7,804.3 6,026,821.00 462,005.36 3.60 6,139.07 14,359.4 89.50 133.34 6,199.8 6,143.6 -4,308.6 -7,761.5 6,026,779.66 462,047.92 3.61 6,167.80 ODSN-17 L1 V2 T2 14,394.5 90.55 132.63 6,199.8 6,143.6 -4,332.5 -7,735.8 6,026,755.60 462,073.53 3.61 6,184.30 Start Dir 3°/100':14394.5'MD,6199.8'TVD 14,400.0 90.68 132.53 6,199.7 6,143.5 -4,336.2 -7,731.8 6,026,751.86 462,077.56 3.00 6,186.85 14,456.2 92.01 131.50 6,198.4 6,142.2 -4,373.8 -7,690.1 6,026,714.09 462,119.14 3.00 6,212.39 End Dir:14456.2'MD,6198.4'TVD 14,500.0 92.01 131.50 6,196.9 6,140.7 -4,402.9 -7,657.3 6,026,684.96 462,151.81 0.00 6,231.94 14,600.0 92.01 131.50 6,193.4 6,137.2 -4,469.1 -7,582.4 6,026,618.44 462,226.38 0.00 6,276.57 14,700.0 92.01 131.50 6,189.9 6,133.7 -4,535.3 -7,507.6 6,026,551.92 462,300.95 0.00 6,321.20 14,800.0 92.01 131.50 6,186.3 6,130.1 -4,601.5 -7,432.7 6,026,485.40 462,375.52 0.00 6,365.83 14,879.2 92.01 131.50 6,183.6 6,127.4 -4,654.0 -7,373.4 6,026,432.72 462,434.58 0.00 6,401.18 Start Dir 3°/100':14879.2'MD,6183.6'TVD 14,900.0 91.70 130.96 6,182.9 6,126.7 -4,667.7 -7,357.8 6,026,418.95 462,450.16 3.00 6,410.38 15,000.0 90.21 128.36 6,181.2 6,125.0 -4,731.5 -7,280.8 6,026,354.84 462,526.86 3.00 6,452.13 15,011.4 90.04 128.06 6,181.2 6,125.0 -4,738.5 -7,271.9 6,026,347.75 462,535.80 3.00 6,456.63 ODSN-17 L1 V2 T3 15,013.8 90.00 128.00 6,181.2 6,125.0 -4,740.0 -7,270.0 6,026,346.28 462,537.67 3.00 6,457.57 Start Dir 3.5°/100':15013.8'MD,6181.2'TVD-ODSN-17 L1 V2 T3.1 15,100.0 87.98 125.76 6,182.7 6,126.5 -4,791.7 -7,201.1 6,026,294.28 462,606.39 3.50 6,489.72 1 15,103.2 87.90 125.68 6,182.8 6,126.6 -4,793.6 -7,198.5 6,026,292.40 462,608.97 3.45 6,490.85 End Dir:15103.2'MD,6182.8'ND 15,152.5 87.90 125.68 6,184.6 6,128.4 -4,822.3 -7,158.4 6,026,263.51 462,648.87 0.00 6,508.27 Start Dir 3.5°/100':15152.5'MD,6184.6'TVD 15,200.0 88.18 127.32 6,186.3 6,130.1 -4,850.6 -7,120.3 6,026,235.12 462,686.91 3.50 6,525.68 15,300.0 88.76 130.77 6,188.9 6,132.7 -4,913.5 -7,042.7 6,026,171.85 462,764.28 3.50 6,566.45 15,400.0 89.35 134.22 6,190.6 6,134.4 -4,981.1 -6,968.9 6,026,104.03 462,837.71 3.50 6,612.64 15,500.0 89.94 137.67 6,191.2 6,135.0 -5,052.9 -6,899.4 6,026,031.90 462,906.93 3.50 6,664.09 15,507.2 89.99 137.92 6,191.2 6,135.0 -5,058.3 -6,894.6 6,026,026.51 462,911.78 3.49 6,668.02 ODSN-17 L1 V2 T4 15,509.6 90.00 138.00 6,191.2 6,135.0 -5,060.0 -6,893.0 6,026,024.78 462,913.33 3.496,669.28 I Start Dir 3°/100':15509.6'MD,6191.2'TVD-ODSN-17 L1 V2 T4.1 15,600.0 90.54 140.66 6,190.8 6,134.6 -5,128.6 -6,834.1 6,025,955.97 462,971.97 3.00 6,720.31 15,621.7 90.67 141.30 6,190.5 6,134.3 -5,145.4 -6,820.4 6,025,939.06 462,985.56 3.00 6,733.06 End Dir:15621.7'MD,6190.5'ND 15,700.0 90.67 141.30 6,189.6 6,133.4 -5,206.5 -6,771.5 6,025,877.76 463,034.27 0.00 6,779.44 15,800.0 90.67 141.30 6,188.4 6,132.2 -5,284.6 -6,708.9 6,025,799.49 463,096.47 0.00 6,838.66 15,900.0 90.67 141.30 6,187.3 6,131.1 -5,362.6 -6,646.4 6,025,721.21 463,158.67 0.00 6,897.89 16,000.0 90.67 141.30 6,186.1 6,129.9 -5,440.6 -6,583.9 6,025,642.93 463,220.87 0.00 6,957.12 9/7/2010 4:15:19PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,128.72 16,100.0 90.67 141.30 6,184.9 6,128.7 -5,518.7 -6,521.3 6,025,564.65 463,283.07 0.00 7,016.34 16,200.0 90.67 141.30 6,183.7 6,127.5 -5,596.7 -6,458.8 6,025,486.37 463,345.28 0.00 7,075.57 16,300.0 90.67 141.30 6,182.6 6,126.4 -5,674.7 -6,396.3 6,025,408.09 463,407.48 0.00 7,134.80 16,400.0 90.67 141.30 6,181.4 6,125.2 -5,752.8 -6,333.8 6,025,329.82 463,469.68 0.00 7,194.02 16,500.0 90.67 141.30 6,180.2 6,124.0 -5,830.8 -6,271.2 6,025,251.54 463,531.88 0.00 7,253.25 16,600.0 90.67 141.30 6,179.0 6,122.8 -5,908.8 -6,208.7 6,025,173.26 463,594.09 0.00 7,312.48 16,700.0 90.67 141.30 6,177.9 6,121.7 -5,986.9 -6,146.2 6,025,094.98 463,656.29 0.00 7,371.70 16,794.8 90.67 141.30 6,176.8 6,120.6 -6,060.8 -6,086.9 6,025,020.77 463,715.25 0.00 7,427.85 Start Dir 3°/100':16794.8'MD,6176.8'TVD 16,800.0 90.64 141.15 6,176.7 6,120.5 -6,064.9 -6,083.7 6,025,016.71 463,718.49 2.97 7,430.92 16,889.6 90.00 138.53 6,176.2 6,120.0 -6,133.4 -6,025.9 6,024,948.00 463,776.00 3.00 7,482.15 ODSN-17 L1 V2 T5 16,900.0 89.69 138.55 6,176.2 6,120.0 -6,141.2 -6,019.0 6,024,940.19 463,782.84 3.00 7,487.89 16,953.8 88.08 138.61 6,177.3 6,121.1 -6,181.5 -5,983.4 6,024,899.72 463,818.26 3.00 7,517.65 End Dir:16953.8'MD,6177.3'ND 17,000.0 88.08 138.61 6,178.8 6,122.6 -6,216.1 -5,952.9 6,024,864.96 463,848.65 0.00 7,543.23 17,100.0 88.08 138.61 6,182.2 6,126.0 -6,291.1 -5,886.8 6,024,789.72 463,914.42 0.00 7,598.59 17,200.0 88.08 138.61 6,185.5 6,129.3 -6,366.1 -5,820.7 6,024,714.48 463,980.19 0.00 7,653.95 17,300.0 88.08 138.61 6,188.9 6,132.7 -6,441.1 -5,754.6 6,024,639.24 464,045.96 0.00 7,709.31 17,400.0 88.08 138.61 6,192.2 6,136.0 -6,516.1 -5,688.6 6,024,564.00 464,111.73 0.00 7,764.66 17,500.0 88.08 138.61 6,195.6 6,139.4 -6,591.0 -5,622.5 6,024,488.76 464,177.50 0.00 7,820.02 17,600.0 88.08 138.61 6,199.0 6,142.8 -6,666.0 -5,556.4 6,024,413.52 464,243.27 0.00 7,875.38 17,700.0 88.08 138.61 6,202.3 6,146.1 -6,741.0 -5,490.3 6,024,338.28 464,309.04 0.00 7,930.74 17,800.0 88.08 138.61 6,205.7 6,149.5 -6,816.0 -5,424.2 6,024,263.04 464,374.80 0.00 7,986.10 17,900.0 88.08 138.61 6,209.0 6,152.8 -6,891.0 -5,358.2 6,024,187.79 464,440.57 0.00 8,041.46 18,000.0 88.08 138.61 6,212.4 6,156.2 -6,965.9 -5,292.1 6,024,112.55 464,506.34 0.00 8,096.82 18,100.0 88.08 138.61 6,215.7 6,159.5 -7,040.9 -5,226.0 6,024,037.31 464,572.11 0.00 8,152.18 18,200.0 88.08 138.61 6,219.1 6,162.9 -7,115.9 -5,159.9 6,023,962.07 464,637.88 0.00 8,207.53 18,300.0 88.08 138.61 6,222.4 6,166.2 -7,190.9 -5,093.8 6,023,886.83 464,703.65 0.00 8,262.89 1 18,361.7 88.08 138.61 6,224.5 6,168.3 -7,237.1 -5,053.1 6,023,840.41 464,744.23 0.00 8,297.05 Start Dir 3°/100':18361.7'MD,6224.5'TVD 18,400.0 88.81 137.72 6,225.6 6,169.4 -7,265.7 -5,027.5 6,023,811.79 464,769.65 3.00 8,318.01 18,462.4 90.00 136.28 6,226.2 6,170.0 -7,311.3 -4,985.0 6,023,766.00 464,812.00 3.00 8,351.08 ODSN-17 L1 V2 T6 18,491.5 90.87 136.38 6,226.0 6,169.8 -7,332.3 -4,964.9 6,023,744.86 464,832.02 3.00 8,366.23 End Dir:18491.5'MD,6226'ND 18,500.0 90.87 136.38 6,225.9 6,169.7 -7,338.5 -4,959.0 6,023,738.68 464,837.86 0.02 8,370.66 18,600.0 90.87 136.38 6,224.3 6,168.1 -7,410.9 -4,890.0 6,023,666.03 464,906.54 0.00 8,422.76 18,700.0 90.87 136.38 6,222.8 6,166.6 -7,483.3 -4,821.0 6,023,593.37 464,975.22 0.00 8,474.86 18,800.0 90.87 136.38 6,221.3 6,165.1 -7,555.6 -4,752.1 6,023,520.72 465,043.90 0.00 8,526.96 18,900.0 90.87 136.38 6,219.8 6,163.6 -7,628.0 -4,683.1 6,023,448.06 465,112.58 0.00 8,579.06 19,000.0 90.87 136.38 6,218.3 6,162.1 -7,700.4 -4,614.1 6,023,375.41 465,181.25 0.00 8,631.17 19,100.0 90.87 136.38 6,216.7 6,160.5 -7,772.8 -4,545.1 6,023,302.75 465,249.93 0.00 8,683.27 19,200.0 90.87 136.38 6,215.2 6,159.0 -7,845.2 -4,476.1 6,023,230.10 465,318.61 0.00 8,735.37 19,300.0 90.87 136.38 6,213.7 6,157.5 -7,917.6 -4,407.2 6,023,157.44 465,387.29 0.00 8,787.47 9/7/2010 4:15:19PM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,156.00 19,400.0 90.87 136.38 6,212.2 6,156.0 -7,989.9 -4,338.2 6,023,084.79 465,455.97 0.00 8,839.57 19,423.0 90.87 136.38 6,211.9 6,155.7 -8,006.6 -4,322.3 6,023,068.08 465,471.77 0.00 8,851.55 Start Dir 3°/100':19423'MD,6211.9'TVD 19,500.0 90.09 134.20 6,211.2 6,155.0 -8,061.3 -4,268.2 6,023,013.14 465,525.71 3.00 8,890.41 19,508.8 90.00 133.96 6,211.2 6,155.0 -8,067.4 -4,261.8 6,023,007.00 465,532.00 3.00 8,894.69 ODSN-17 L7 V2 T7 19,593.5 87.50 134.39 6,213.1 6,156.9 -8,126.4 -4,201.1 6,022,947.76 465,592.49 3.00 8,936.00 i End Dir:19593.5'MD,6213'ND 19,600.0 87.50 134.39 6,213.3 6,157.1 -8,131.0 -4,196.5 6,022,943.20 465,597.11 0.00 8,939.19 19,700.0 87.50 134.39 6,217.7 6,161.5 -8,200.9 -4,125.1 6,022,873.03 465,668.21 0.00 8,988.25 19,800.0 87.50 134.39 6,222.1 6,165.9 -8,270.7 -4,053.7 6,022,802.86 465,739.31 0.00 9,037.32 I 19,900.0 87.50 134.39 6,226.4 6,170.2 -8,340.6 -3,982.3 6,022,732.69 465,810.42 0.00 9,086.38 20,000.0 87.50 134.39 6,230.8 6,174.6 -8,410.5 -3,910.9 6,022,662.53 465,881.52 0.00 9,135.44 20,100.0 87.50 134.39 6,235.2 6,179.0 -8,480.4 -3,839.5 6,022,592.36 465,952.62 0.00 9,184.51 20,200.0 87.50 134.39 6,239.5 6,183.3 -8,550.3 -3,768.1 6,022,522.19 466,023.72 0.00 9,233.57 20,300.0 87.50 134.39 6,243.9 6,187.7 -8,620.2 -3,696.7 6,022,452.03 466,094.82 0.00 9,282.63 20,376.4 87.50 134.39 6,247.2 6,191.0 -8,673.6 -3,642.2 6,022,398.42 466,149.15 0.00 9,320.12 Start Dir 3°/100':20376.4'MD,6247.2'TVD 20,400.0 87.82 133.76 6,248.2 6,192.0 -8,690.0 -3,625.2 6,022,381.95 466,166.02 3.01 9,331.59 20,500.0 89.21 131.10 6,250.8 6,194.6 -8,757.4 -3,551.4 6,022,314.22 466,239.52 3.00 9,377.67 20,557.2 90.00 129.57 6,251.2 6,195.0 -8,794.4 -3,507.8 6,022,277.00 466,283.00 3.00 9,402.18 Start Dir 2°/100':20557.2'MD,6251.27VD-ODSN-17 L1 V2 T8 20,569.0 90.23 129.57 6,251.2 6,195.0 -8,801.9 -3,498.7 6,022,269.48 466,292.03 2.00 9,407.07 End Dir:20569'MD,6251.2'ND 20,600.0 90.23 129.57 6,251.0 6,194.8 -8,821.7 -3,474.8 6,022,249.63 466,315.84 0.00 9,419.98 20,700.0 90.23 129.57 6,250.6 6,194.4 -8,885.4 -3,397.8 6,022,185.62 466,392.65 0.00 9,461.60 20,800.0 90.23 129.57 6,250.2 6,194.0 -8,949.1 -3,320.7 6,022,121.62 466,469.47 0.00 9,503.22 20,900.0 90.23 129.57 6,249.8 6,193.6 -9,012.8 -3,243.6 6,022,057.61 466,546.28 0.00 9,544.84 1 21,000.0 90.23 129.57 6,249.4 6,193.2 -9,076.5 -3,166.5 6,021,993.60 466,623.10 0.00 9,586.47 l 21,100.0 90.23 129.57 6,249.0 6,192.8 -9,140.2 -3,089.4 6,021,929.59 466,699.91 0.00 9,628.09 21,200.0 90.23 129.57 6,248.6 6,192.4 -9,203.9 -3,012.4 6,021,865.58 466,776.73 0.00 9,669.71 21,300.0 90.23 129.57 6,248.2 6,192.0 -9,267.6 -2,935.3 6,021,801.57 466,853.55 0.00 9,711.34 21,400.0 90.23 129.57 6,247.8 6,191.6 -9,331.3 -2,858.2 6,021,737.56 466,930.36 0.00 9,752.96 21,500.0 90.23 129.57 6,247.4 6,191.2 -9,395.0 -2,781.1 6,021,673.55 467,007.18 0.00 9,794.58 21,600.0 90.23 129.57 6,247.0 6,190.8 -9,458.7 -2,704.0 6,021,609.54 467,083.99 0.00 9,836.20 21,700.0 90.23 129.57 6,246.5 6,190.3 -9,522.4 -2,626.9 6,021,545.53 467,160.81 0.00 9,877.83 21,784.8 90.23 129.57 6,246.2 6,190.0 -9,576.4 -2,561.6 6,021,491.25 467,225.94 0.00 9,913.12 Total Depth:21784.9'MD,6246.2'ND 21,784.9 90.23 129.57 6,246.2 6,190.0 -9,576.5 -2,561.5 6,021,491.20 467,226.00 0.00 9,913.15 ODSN-17 L1 V2 T9 9/7/2010 4:15:19PM Page 6 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTONJ Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) ODSN-17 L1 V2 T3.1 0.00 359.71 6,181.2 -4,740.0 -7,270.0 6,026,346.28 462,537.67 -plan hits target -Point I ODSN-17 L1 V2 T6 0.00 359.71 6,226.2 -7,311.3 -4,985.0 6,023,766.00 464,812.00 , -plan hits target -Point ODSN-17 L1 V2 T1 0.00 359.71 6,163.2 -4,014.3 -8,034.7 6,027,075.00 461,776.00 -plan misses by 178.8ft at 14134.5ft MD(6186.0 TVD,-4148.0 N,-7918.1 E) -Point ODSN-17 L1 V2 T7 0.00 359.71 6,211.2 -8,067.4 -4,261.8 6,023,007.00 465,532.00 -plan hits target -Point ODSN-17 L1 V2 T2 0.00 359.71 6,196.2 -4,300.2 -7,753.5 6,026,788.00 462,056.00 I -plan misses by 12.2ft at 14359.5ft MD(6199.8 TVD,-4308.7 N,-7761.4 E) -Point ODSN-17 L1 V2 T4.1 0.00 359.71 6,191.2 -5,060.0 -6,893.0 6,026,024.78 462,913.33 -plan hits target -Point ODSN-17 L1 Geo Poly 0.00 359.71 6,163.2 -4,014.3 -8,034.7 6,027,075.00 461,776.00 -plan misses by 178.8ft at 14134.5ft MD(6186.0 TVD,-4148.0 N,-7918.1 E) -Polygon Point 1 6,163.2 -3,902.8 -7,885.3 6,027,185.85 461,925.87 Point 2 6,163.2 -3,996.6 -7,798.0 6,027,091.75 462,012.76 Point 3 6,163.2 -4,124.9 -7,665.3 6,026,962.91 462,144.88 Point 4 6,163.2 -4,249.2 -7,522.4 6,026,838.08 462,287.30 Point 5 6,163.2 -4,500.0 -7,238.3 6,026,586.11 462,570.35 Point 6 6,163.2 -4,565.8 -7,150.8 6,026,520.01 462,657.51 Point 7 6,163.2 -4,618.2 -7,073.6 6,026,467.30 462,734.56 Point 8 6,163.2 -4,756.1 -6,908.1 6,026,328.69 462,899.49 Point 9 6,163.2 -4,928.9 -6,748.5 6,026,155.28 463,058.36 Point 10 6,163.2 -5,087.0 -6,623.5 6,025,996.73 463,182.72 Point 11 6,163.2 -5,319.9 -6,434.5 6,025,763.05 463,370.76 Point 12 6,163.2 -6,005.6 -5,866.7 6,025,075.13 463,935.64 Point 13 6,163.2 -6,896.9 -5,063.8 6,024,180.69 464,734.83 Point 14 6,163.2 -7,325.8 -4,657.1 6,023,750.17 465,139.75 Point 15 6,163.2 -7,683.0 -4,307.3 6,023,391.58 465,488.11 I Point 16 6,163.2 -7,957.4 -4,027.9 6,023,116.11 465,766.37 Point 17 6,163.2 -8,491.7 -3,465.6 6,022,579.57 466,326.40 Point 18 6,163.2 -8,619.9 -3,309.5 6,022,450.75 466,482.02 Point 19 6,163.2 -9,119.9 -2,684.9 6,021,948.27 467,104.50 Point20 6,163.2 -9,307.2 -2,450.5 6,021,760.04 467,338.08 Point21 6,163.2 -9,369.7 -2,372.4 6,021,697.23 467,415.94 Point22 6,163.2 -9,422.6 -2,306.1 6,021,644.01 467,481.99 Point 23 6,163.2 -9,819.1 -2,631.1 6,021,248.89 467,155.45 Point 24 6,163.2 -9,763.9 -2,695.6 6,021,304.32 467,091.20 Point25 6,163.2 -9,699.0 -2,771.7 6,021,369.53 467,015.34 Point26 6,163.2 -9,504.1 -2,999.8 6,021,565.37 466,788.05 Point 27 6,163.2 -8,964.6 -3,632.1 6,022,107.33 466,158.02 Point 28 6,163.2 -8,623.3 -3,978.3 6,022,450.02 465,813.29 Point 29 6,163.2 -8,198.6 -4,400.5 6,022,876.43 465,392.77 Point 30 6,163.2 -7,899.4 -4,676.9 6,023,176.70 465,117.67 Point 31 6,163.2 -7,606.1 -4,948.9 6,023,471.08 464,846.88 Point 32 6,163.2 -7,381.7 -5,154.2 6,023,696.23 464,642.56 Point 33 6,163.2 -6,772.9 -5,676.7 6,024,307.11 464,122.55 Point 34 6,163.2 -6,243.6 -6,133.9 6,024,838.27 463,667.53 9/7/2010 4.15:19PM Page 7 COMPASS 2003.16 Build 42B Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 Company: Well Planning-Pioneer-Oooguruk ND 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Point 35 6,163.2 -5,844.0 -6,446.7 6,025,239.09 463,356.42 Point 36 6,163.2 -5,233.3 -6,929.2 6,025,851.61 462,876.41 Point 37 6,163.2 -5,157.5 -7,000.4 6,025,927.73 462,805.54 Point 38 6,163.2 -5,032.9 -7,144.7 6,026,052.86 462,661.71 Point 39 6,163.2 -4,928.2 -7,294.4 6,026,158.19 462,512.52 Point 40 6,163.2 -4,857.8 -7,380.1 6,026,228.89 462,427.15 Point 41 6,163.2 -4,717.8 -7,534.8 6,026,369.51 462,273.01 Point 42 6,163.2 -4,519.0 -7,759.2 6,026,569.25 462,049.42 Point43 6,163.2 -4,445.2 -7,838.7 6,026,643.35 461,970.25 Point44 6,163.2 -4,292.3 -7,983.1 6,026,796.78 461,826.50 Point45 6,163.2 -4,214.6 -8,045.9 6,026,874.81 461,764.02 Point46 6,163.2 -4,124.9 -8,120.1 6,026,964.72 461,690.13 ODSN-17 L1 V2 T3 0.00 359.71 6,181.2 -4,767.4 -7,294.6 6,026,319.00 462,513.00 -plan misses by 36.7ft at 15011.4ft MD(6181.2 TVD,-4738.5 N,-7271.9 E) -Point ODSN-17 L1 V2 T5 0.00 359.71 6,176.2 -6,133.4 -6,025.9 6,024,948.00 463,776.00 I -plan hits target 1 -Point 1 ODSN-17 L1 V2 T9 0.00 359.71 6,246.2 -9,576.5 -2,561.5 6,021,491.20 467,226.00 -plan hits target -Point ODSN-17 L1 V2 T4 0.00 359.71 6,191.2 -5,105.0 -6,946.1 6,025,980.00 462,860.00 -plan misses by 69.6ft at 15507.4ft MD(6191.2 ND,-5058.4 N,-6894.5 E) -Point ODSN-17 L1 V2 T8 0.00 359.71 6,251.2 -8,794.4 -3,507.8 6,022,277.00 466,283.00 -plan hits target -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 4,670.0 3,301.4 11 3/4" 11.750 14.500 10,893.6 5,348.0 9 5/8" 9.625 11.750 13,984.5 6,168.0 7" 7.000 8.750 21,784.9 6,246.2 4 1/2" 4.500 6.125 9/7/2010 4:15:19PM Page 8 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-17-Slot ODS-17 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: ODSN-17 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-17 PN13 mid L1 Design: ODSN-17 PN13 mid L1 wp02 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lit.o...gy (0) (?) 13,955.6 6,163.2 Top Nuiqsut 0.00 2,409.5 2,296.2 Top West Sak 0.00 12,945.0 5,958.2 Kalubik Mkr 0.00 13,794.4 6,135.2 BCU 0.00 1,689.9 1,666.2 Base Permafrost 0.00 4,401.9 3,213.2 Hue2 tuff 0.00 9,787.3 4,984.2 Top Torok Sand 0.00 13,143.6 6,006.2 Top Kup C 0.00 7,619.2 4,271.2 Brook 2B 0.00 12,663.8 5,885.2 Base HRZ 0.00 12,216.6 5,762.2 Top HRZ 0.00 13,143.6 6,006.2 LCU 0.00 10,933.7 5,361.2 Torok Shale 1 0.00 3,448.1 2,899.2 Tuffacious Shales 0.00 10,331.6 5,163.2 Base Torok Sand 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 14,134.6 6,186.0 -4,148.1 -7,918.0 Start Dir 4°/100':14134.5'MD,6186'TVD:250°LT TF 14,194.5 6,191.2 -4,192.2 -7,877.9 Start Dir 3.6°/100':14194.5'MD,6191.2'TVD 14,394.5 6,199.8 -4,332.5 -7,735.8 Start Dir 3°/100': 14394.5'MD,6199.8'TVD 14,456.2 6,198.4 -4,373.8 -7,690.1 End Dir: 14456.2'MD,6198.4'TVD 14,879.2 6,183.6 -4,654.0 -7,373.4 Start Dir 3°/100': 14879.2'MD,6183.6'TVD 15,013.8 6,181.2 -4,740.0 -7,270.0 Start Dir 3.5°/100':15013.8'MD,6181.2'TVD 15,103.2 6,182.8 -4,793.6 -7,198.5 End Dir: 15103.2'MD,6182.8'TVD 15,152.5 6,184.6 -4,822.3 -7,158.4 Start Dir 3.5°/100':15152.5'MD,6184.6'TVD 15,509.6 6,191.2 -5,060.0 -6,893.0 Start Dir 3°/100': 15509.6'MD,6191.2'TVD j 15,621.7 6,190.5 -5,145.4 -6,820.4 End Dir: 15621.7'MD,6190.5'TVD 16,794.8 6,176.8 -6,060.8 -6,086.9 Start Dir 3°/100': 16794.8'MD,6176.8'TVD 16,953.8 6,177.3 -6,181.5 -5,983.4 End Dir: 16953.8'MD,6177.3'TVD 18,361.7 6,224.5 -7,237.1 -5,053.1 Start Dir 3°/100':18361.7'MD,6224.5'TVD 18,491.5 6,226.0 -7,332.3 -4,964.9 End Dir: 18491.5'MD,6226'TVD 19,423.0 6,211.9 -8,006.6 -4,322.3 Start Dir 3°/100':19423'MD,6211.9'TVD 19,593.5 6,213.1 -8,126.4 -4,201.1 End Dir: 19593.5'MD,6213'TVD 20,376.4 6,247.2 -8,673.6 -3,642.2 Start Dir 3°/100':20376.4'MD,6247.2'TVD 20,557.2 6,251.2 -8,794.4 -3,507.8 Start Dir 2°/100':20557.2'MD,6251.2'TVD 20,569.0 6,251.2 -8,801.9 -3,498.7 End Dir:20569'MD,6251.2'TVD 21,784.8 6,246.2 -9,576.4 -2,561.6 Total Depth:21784.9'MD,6246.2'TVD 9/7/2010 4:15:19PM Page 9 COMPASS 2003.16 Build 428 2 0 L r sm 0 CC m M3 C W 0 J ..1 L QL 0 = a Np L C 7, M J a_ L M M N O Z 0 a U O ii ma 2 67 N Z. 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Cn (n (n fn CO CO CO U) 0) d '- O C .0 4 i+ U d o 0 0 0 0 0 0 O 0 0 co m c 0 co _ m U 0 0 0 0 0 0 O O n a N N Q HCLC0CD W 0 U) 5 0 Q TRANSMITTAL LETTER CHECKLIST WELL NAME c ;/- /7L 1 PTD# 2-/CJ / 4-/C i Development 7`" C /Development Service Exploratory Stratigraphic Test Non-Conventional Well / L FIELD: C''C` t.( d �� POOL: C' LC v'l.-( /�-` A/�C��'S it-6T 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 fora new well re segment of existing well /7 , (If last two digits in API number are Permit No. ���jn API No. 50-�L?')-7 :��� - . between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (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 To N 0 0 N a0 ° a) 0 CO LN 7 r E 'O -5 C C)) O 0 2 a1.0 0i • CD .- E a O . O 0 O z (0 0 p 'O LS = a) a) c C '3 c O o L CO O m E OC c 2 L -c O o . 3 E c CO 2 Z c 0 L N = a O E Z 0 > (n co c -o — ' ° d rn c W O 0 3 0 7 a) 0_ 0Lo U _O O 0 E N N > T E O J 4 0 d c o_ o 7 a) 0 a) a a) D N C O E r a co P o < o - O d I > L ui ui L m w 0 O°I I- ) .3 0 0 a 3 C a w _ o o N cojo =` m uM .o U v(° -O o aa s c a mo a) co O C C O0 _ Q L n a) = 0. 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V 0 a) N m N 'n 'n ° = 0 c 0 •cP a - 0 c Ci O 0 LL O O O V X X L Ea U0 ° 3 m m m `o v v 0 ° a.a a) E N 0 0 U z 0 0 N a) N 7 0 0 ° o E CO 0 O) IIwo_ ° 0 0 z 7 O O O O 0 0 0 o I 0 OL a) a) 0 < N N X 0 W (n 0 0 0 0 0 U) co a` 0 d' 4 3 2 - 2 I I W -0 CI_ > W 0 Q a.) aa)) O aa)) 0a0) 0aa)) aa)) aa)) aa)) aa)), < < < <, < < < < o a.) aa)) < aa)) < aa)) aa)) aa)) aa)) aa)) 0 < a) aa)) < < < az >- >- z >- >- >- >- >- >- >- >- >- zzzz z zz z z >- >- z >- z >- >- >- >- >- z z >- >- z zz N. T i N Li.. T CO N _ U N o _1 c E - E 0 O 0 0 c N c N C O _ ° 0 Ii\ C C2 T N C ■. � C L O 4t ° C T ` (n P 3 E 0 ° O 0 co N U T (-D C ° a) a a) 2 in O c 0 0 E 0 0 m N N Q 01 O 0 E N a 0 z @ 0 0 <`! U n 0 F J N Q 7 `O T ... C 7 0 N (6. O• ih a N N CO I Y �° o a a Q N N 2c CO v 0 a) a.) r 0 R (n U) «. N -6 (9 a w0-- U r ot) U N a) o N N a 0 - 00 N Q W ) 7 a)) > 1-'5 m c cri 0 o f 06 E 0 o .5 ° n O E N N ow D O 0 0 C1 0 0 a) C a a) N o. O D O m a) m 0 00 O N d L c o � C N 00 d' c = o N LO CO > • ° > 0 0- N N N o O O N D D E E ._ -O C C E N 2 O M C C H .-� C O o($ a) C 0 w a N L O_ m C X O p O O a U -0 0 m ° n p 0 Q ocn ° 0 U n L Q a) o a ° 3 > m Y a`)c O W 00 a) 0 .O 5 T o 7 7 ° "O 0 •(6 O - m O O `O N @ O E as is (6 Q N N 0 m 0 a) C CD N O U U _0 0 0 a) C u = Z o E 7 3 0 2 a) L m 3 - E c 0 _1 0 , a o o (o n n 0 L L -0 CO (o -70 E aa) 0n E c - N co 0 '� r 2 o 0. 0_ 3 o c ° T 3 a E Q n -o c �' r •F, 0 0 c° 3 3 a) 2 a) .. o -° 0 - 3 3 2 0 °_ 0 0 0, ' m 0 3 a) L 0 2 W U v d 2 c "O "O > o a) .Q a s p al E O C 2> N O O O" O N "00 1-15a) N E O O) C "O a N 7 a) on) a) o c o 0 0 0 ,� 0 o E 0 E L 0 0 N c H a) a 0 a a)` 0 0 0 7 7 n c v 0 ° 0_ 0 0 0 _ -0 0 ,- 2 -o m E rn o r_. 7 CO 0 ors Q L (Q Oa Oa O) a) O_ N N Cl L r N O) 0- CO CO a) a) 0 a) 0 N CO C ° 3 N a N O (p 0 L _ @ N C _ a D_ N N T N L Q D 3 L a CO C 0Cr,- 66 N > a) Q a L O U 0 00 00 >. - 0 LL W a) L 0 0 0 o C @ '-' a) U C N N a a O N R. L 3 a N •C 0 L C a7 C E E a) -p O L C C o 0 - 0 N 00 0 (6 C a) C 0 (p W a) 7 3 a3 a3 a7 C a3 a7 3 7 O U a3 CO = = a @ = C U a) N a) U C co O c 0 0 0 0 0 ° ° 0 0 u _o `� o c c 0 0 0 m t) m ui at a) E -0. - a J a E N a - - - � a>) o m E E 0 - 3 0' 0 a L H H I- - a0 m e > 5 a d o Y 3 E yo N c c TO 0 a@) .0 a) a) a) 7 -° n n a`) a`) a) 0 - 0 0 7 2 2 2 m -O o a ' = O O L ° N- a) a) a) a) a) 0 0 U c a J I c) - 0 0 a a U Q a z U (n U U U U < Q � O m m U - 2 a 0 o) (n O W ° O N M V L0 O n W 0 O N M V Lc:), O r CO o) O N M A L aJ ';:i a0 0) V �- N M V LU (0 ti CO 0) r- N N N N N N N N N N M M M M M M M M M M p O O O 0 0 O y 0 O 0 2 0 C m N N N U C O O N W o +�-+ Ci E rn rn o .E J NE >0) 0 0 N • c� E -Iiia. uj 3 a E a u- C a O 0 U a Q < w Q C7 Q Well History File APPENDIX information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I HALLI B U RTO N Sperry Drilling END OF WELL REPORT ODSN-17 L1 Oooguruk Development oldwilisi y tAr Surface Data Logging Services a\°' HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup PIONEER NATURAL RESOURCES HALLIBURTON Sperry Drilling GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-17 L1 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20622-60-00 Sperry Job Number: AK-AM-7007267 Job Start Date: 6 Sep 2010 Spud Date: 11 Oct 2010 Total Depth: 20952' MD, 6290' TVD North Reference: True Declination: 21 .314 Dip Angle: 80.942 Total Field Strength: 57630 nT Date Of Magnetic Data: 25 Aug 2010 Wellhead Coordinates N: North 70° 29' 45.30" Wellhead Coordinates W: West 150° 14' 48.23" Drill Floor Elevation 56.2' Ground Elevation: 13.6' Permanent Datum: Mean Sea Level SDL Engineers: Tom Mansfield, Colby Marks, Mark Lindloff, Ryan Massey Company Geologist: Jacque Ledbetter, Paul Cozma, Jim Stewart, Mindaugas Kuzminskas Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling DAILY SUMMARY Begin ODSN-17 L1 10/11/2010 Continued running in the hole with 6.125" BHA to casing shoe. Slipped and cut drilling line, Displaced 10.1 ppg mud with 7.9 ppg. Time drilled to open hole. Sidetracked the well at 14180. Pulled back to reshoot surveys. Drilled ahead with gas running between 500-2600 units. Samples are 100% sandstone, no real change in litho logic composition. 10/12/2010 Drilled ahead with drill gas running between 500-2500 units avg. Connection gases were noted at 16667' MD (1995 units, 760 BG) and 16759' MD (1853 units, 650 BG) but none observed thereafter. Samples are 100% sandstone, no real change in composition. Drilled ahead. 10/13/2010 Drilled ahead with drill gas running between 500- 2100 units avg. No connection gas was noted. Samples were 100% sandstone, no real change in composition. Drilled ahead looking for possible fault zone. 10/14/2010 Continued drilling. Gas dropped off to 230 units by TD, Samples remained 100% sandstone although last samples began looking slightly silty. ROP dropped from 159 ft/hr at 20940' to 27 ft/hr by 20944'from suspected Siderite creating severe dogleg. Circulated well while waiting on orders. TD of ODSN-17L1 called at 20952' MD, 6290' TVD. Serviced rig —wash pipe leaking. Short tripped into 7" CSG at 14063'. Changed out RCD element. Changed out swivel packing. Trouble shot new wash pipe. Checked new wash pipe, RIH, washed down from 18269' Trip in the hole. 10/15/2010 Continued to RIH to bottom. Circulated B/U to clean hole with 1292 units of trip gas at bottoms up. Gas dropped off sharply. Started POOH until 18297' MD. Repaired air pressure line on MPD backpressure pump. Continued to POOH to14062'md. Pumped kill weight mud. RIH to14405' MD, pumped hi vis sweep while POOH. Continued to POOH to 13780' MD and started displacing to 10.1 ppg mud. Changed out RCD element. Finished displacing and returned to POOH. Trip displacement showing minor loss and no gains. 10/16/2010 Finished POOH, laying down the same. Lost 9 bbls over displacement during trip out. Rigged up and ran in hole with 4.5" liner. Hole took 2 bbl/hr liner run. Prepare to rig up liner head to run in on 4" DP. PIONEER NATURAL RESOURCES Customer: Pioneer Natural Res. Report#: 36 Well: ODSN-17L1 Date: 10/12/2010-04:00 HALLIBURTSIN Area: Oooguruk 04:00 Depth 15123' Location: North Slope Progress 24 hrs: 955' Sperry Grilling Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007007267 Report For: J. Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $226,304.95 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 106.0 160.0 370.0 na Flow In (gpm) 273 SPP (psi) 2184 Gas (units) 480 799 1954 14100' Flow In (spm) 68 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.49 Min 9.86 Avg 10.11 Max 15123' 11.4 10 bbls 6.25" All Circ 9.48 Min 9.86 Avg 10.16 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 14464' 7.85 7.85 42 6.4 6 6 1661 5.96 4.6 4.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Sec FXG-54 6.125 0.389 0.00 14180' _ 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd _ Sst _ Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) " Depth max avg Cl C2 C3 C4 C5 Type 14180 to 15122 1954 782 204444 3862 1141 368 94 GP to to to to to to to to Gas Type abreviations: BG - Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Continue runing in the hole with 6.125"BHA to casing shoe,slip and cut drill line, Displace 10.1 ppg mud with 7.9 ppg. Time drill to open hole sidetrack the well at 14180.Pulled back to reshoot surveys. Drilling ahead with gas running between 500-1300 units Samples are 100%sandstone, no real change in compisition.Currently drilling ahead. I Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 37 Well: ODSN-17L1 Date: 10/13/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 18183' ------------------ Location: North Slope Progress 24 hrs: 3060' Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: J. Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $241,992.90 ,, ` ROP 8r Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ 178.0 200.3 468.0 16099' Flow In(gpm) 240 SPP(psi) 2815 Gas(units) 648 1222 2837 17246' Flow In(spm) 68 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.52 Min 10.03 Avg 10.74 Max 18016' 11.4 10 bbls 6.25" All Circ 9.52 Min 10.03 Avg 10.74 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 14464' 8.05 8.05 42 6 8 8 1207 3.24 2.5 5.2 _BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB _ RPM Condition 800 Sec FXG-54 6.125 0.389 0.00 14180' 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): _ Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 'Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 15200 to 16200 2616 1170 271654 4847 1500 543 150 GP 16201 to 17000 2756 1163 282627 4992 1570 551 161 GP 17001 to 18000 2837 1293 273902 4625 1474 522 161 GP to __to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG- Ream Gas;T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Drilling ahead with drill gas running between 500-2500 units avg.Connection gases were noted at 16667'and(1995 units,760 BG) and 16759'and(1853 units,650 BG)but none have been observed since then.Samples are 100%sandstone,no real change in composition.Currently drilling ahead. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 38 Well: ODSN-17L1 Date: 10/14/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 20427' Location: North Slope Progress 24 hrs: 2244' Sperry Drilling Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $6,361.15 Total Charges: $248,354.05 ROP & Gas: Current Avg 24 hr Max Max@ft Current Pump & Flow Data: R.O.P. (ft/hr) 139.0 158.0 652.0 18263' Flow In (gpm) 240 _ SPP (psi) 2964 Gas (units) 1319 849 2115 20323' Flow In (spm) 67 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 8.85 Min 10.16 Avg 11.01 Max 20427' 44.4 35 bbls 6.25" All Circ 8.85 Min 10.16 Avg 11.01 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 0/0 19992' 8.00 8.00 42 8 8 6 1174 2.59 2 4.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800_ Sec FXG-54 6.125 0.389 0.00 14180' 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 18638 to 20450 2115 849 254914 4328 1395 489 156 GP to to to _ to to to to to Gas Type abreviations: BG - Background Gas; GP- Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Drilling ahead with drill gas running between 500-2100 units avg.No connection gas was noted. Samples are 100%sandstone, no real change in composition.Currently drilling ahead looking for Logging Engineer: Tom Mansfield/Mark Lindloff " 10000 units = 100%Gas In Air Customer: Pioneer Natural Res. Report#: 39 Well: ODSN-17L1 Date: 10/1452010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 20952' Location: North Slope Progress 24 hrs: 705' Sperry Drilling Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $6,361.15 Total Charges: $248,354.05 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 151.0 229.0 20632' Flow In(gpm) 0 SPP (psi) 0 Gas (units) 0 651 2115 20598' Flow In (spm) 0 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.01 Min 10.25 Avg 10.37 Max 20952' 91.1 40 bbls 6.40" All Circ 10.10 Min 10.24 Avg 10.45 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 20952' 8.10 8.10 42 6.2 10 8 1311 4.59 3.8 5.4 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Sec FXG-54 6.125 0.389 0.00 14180' 12 131 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd _ Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type 20427 to 20952 796 2115 28267 5403 1741 583 175 GP to to to to to to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG-Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Con't drilling,gas dropping off till 200 to 300 units by TD,Samples remained 100%sandstone.Circ well while waiting on orders- TD called at 20952'MD.Service rig-washpipe leaking.Short trip into 7"csg at 14063'.Change out RCD element.Change out swivel packing.Trouble shoot new washpipe.Check new wash pipe,RIH,washed down from 18269'Currently Tripping in the hole. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units = 100% Gas In Air # Customer: Pioneer Natural Res. Report#: 40 Well: ODSN-17L1 Date: 10/16/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 20952' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007007267 Report For: R.Klepzig/J.Haberthur Daily Charges $5,991.94 Total Charges: $260,707.14 ' ..,..' ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0' Flow In(gpm) 0 SPP(psi) 0 Gas(units) 0 67 1292 20984' Flow In(spm) 0 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max 20952' 91.1 40 bbls 6.40" All Circ 10.10 Min 10.24 Avg 10.45 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) _ (m1/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 20952' 8.15 8.15 45 6.2 9 9 1358 3.76 2.9 6.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Sec FXG-54 6.125 0.389 0.00 14180' 12 131 700 Sec FXG-54 6.125 0.389 0.00 14128' 19948' 5820' 13 109 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg Cl C2 C3 C4 C5 Type to to to to to to to to 1 to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG- Produced Gas; RG -Ream Gas; T---Trip...; F--- Formation...; E---Early... 24 hr Recap: Continue to RIH to bottom,Circulate B/U to clean hole, 1292 Units of trip gas at bottoms up,Gas dropped off very quickly. Start POOH till 18297'md,repair air pressure line.Continue POOH to14062'md,Pumped kill weight mud,RIH to14405'md,pumped hi vis sweep,while POOH,-10 displacement, POOH to 13780'and start displacing to 10.1 ppg mud.Change out RCD element.. Finish displacing and return to POOH.Trip displacenet showing no losses and no gains.POOH at report time. Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 41 Well: ODSN-17L1 Date: 10/17/2010-04:00 HALLIBURTON Area: Oooguruk 04:00 Depth 20952' Location: North Slope Progress 24 hrs: Cr Sperry Drilling Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007007267 Report For: R. Klepzig/J.Haberthur Daily Charges $4,515.11 Total Charges: $265,222.25 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 0.0 0.0 0.0 _ 0' Flow In(gpm) 0 SPP (psi) 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 3.5170 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max All Circ Min Avg Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkal Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 20952' 10.10 10.10 44 6 15 14 1470 7.12 5.5 18.4 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Sec FXG-54 6.125 0.389 0.00 14180' 20952' 6772' 12 131 1-1-ER-N-X-I-NO-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) 100 Gas Breakdown H2S Data I Sample Line Max: 0 Avg: 0 I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth max avg C1 C2 C3 C4 C5 Type to to to to_ to _ to to to to Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG -Wiper Trip Gas; POG- Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Finish POOH,lay down the same. Lost 9 bbls POOH during trip. Rig up and run in hole with 4.5"liner. Hole took 2 bbl/hr during trip. Curently rigging up liner head at report time. Charges for ADT end 10/16/2010. i Logging Engineer: Tom Mansfield/Mark Lindloff * 10000 units= 100% Gas In Air N ta E N CC a) J • O O O 7 N N `z V V O• C c O O o O O a _ 4 m oza - _ 1- z < Lu a o m • Q a /- -o z m o <• < (I) U) c o O 0 -)-c i' m W 2 a 0 x 3 £ N 0 `N J tL N 0 2 o a m o at `O £ `o 7 V N n 2 k a t.... z �i n ct E a z a, i in 0 a7 a7 Y O of 0 a co z a di 2 oo oE o 6 a z ¢ r < CC J W K • d Waw O n_ ti cn V) I- o 1r` i co m 0 co 2 ',1- a) Qt as N O r- O co U- L N 1 0• 7 rn 00 0 to D. O cp v Q r N_ F mN co ce O 3 toal w J aco X LL L Y Q i m m m co 0 U 4) U y w (Y.. 0 R Q E m i0 L N N co 3 c c c is c7 '6 0 6 0 }} (0 co a0 (0 N_ L. + c00 (O 0 0 CO = U N N N (Ni N 4) co O - N 0 Y O. 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(0 00 0 o to a 'tbOa s- 'En 6Is- N (O N N N N O ) O p�� CO V V 'Cr C 'Cr 0 /�� (_0 V /CC V p6 r OA C.O (0 (0 0 0 LI. 0 E y o Cil 0 O O I.I a r F- co os eo 5 (0 'a 6 a) = a� `tm 2 c ? E L r v N O M ra � Q N O) O. rnnr- w N VnCO c �� r 0 7 N N U (D N a i vs 1-4 00000 HALLIBURTON PIONEER Sperry Drilling NAI URAL RESOU) ,S ODSN-17L1 Interpolated Tops Marker MD INC AZ TVD TVDSS Base of Permafrost 1692.00 18.79 298.97 1667.96 Top West Sak 2408.00 37.98 290.91 2300.03 2243.83 Tuffaceous Shale 3674.00 70.19 255.89 2959.11 2902.91 Hue_1 3998.00 70.93 257.14 3065.82 3009.62 Hue_2 4340.00 70.48 258.62 3179.04 3122.84 Top of 9 7/8"Liner 4498.00 70.66 258.38 3231.52 3175.32 SCP 4659.80 71.14 259.64 3285.15 3228.95 Brook 2B 7643.00 70.31 258.35 4266.47 4210.27 Torok Top 9797.00 70.95 257.43 4978.08 4921.88 Torok Base 10382.00 70.92 245.48 5168.77 5112.57 Top of 7"Liner Tieback Seal 10829.00 70.75 228.12 5315.31 5259.11 Torok SH_1 10930.00 70.71 223.66 5348.78 5292.58 ICP1 10978.00 71.07 222.82 5364.53 5308.33 Top HRZ 12244.00 74.04 182.90 5750.02 5693.82 Base HRZ 12713.00 74.33 172.43 5877.78 5821.58 Kalubik Marker 13008.00 75.28 162.55 5955.25 5899.05 Top Kup C 13236.00 76.37 154.36 6009.32 5953.12 LCU 13239.00 76.36 154.27 6010.03 5953.83 BCU 13834.00 78.98 142.75 6137.29 6081.09 13991.00 79.90 140.87 6166.08 6109.88 Top Nuiqsut_D1 14061.00 80.24 139.76 6178.14 6121.94 Top Nuiq::Nuiq_1_D1 14080.00 80.34 139.74 6181.35 6125.15 ICP2 14106.00 80.53 139.63 6185.67 6129.47 KOP-L1 Sid( 14180.00 81.81 139.36 6197.36 6141.16 T2(Invert#1 -D1) 14405.33 90.00 136.54 6219.35 6163.15 T3(Revert#1 -U2) 15036.36 90.00 129.73 6211.78 6155.58 T4(Invert#2-D3) 15520.00 90.00 142.24 6223.91 6167.71 T5(Revert#2-U4) 16093.90 90.00 138.43 6215.46 6159.26 T6(Invert#3-D5) 16943.50 90.00 138.58 6244.95 6188.75 T7(Revert#3-U6) 17575.97 90.00 137.72 6226.50 6170.30 T8(Invert#4-D7) 18143.60 90.00 140.64 6254.52 6198.32 T9(Revert#4-U8) 18685.78 90.00 133.62 6234.60 6178.40 T10(Invert#5-D9) 19341.00 90.00 136.21 6265.73 6209.53 Nuiq_1::Top Nuiq_1_U10 20110.00 92.46 132.56 6246.64 6190.44 T11 (Revert#5-U10) 20138.40 90.00 130.50 6246.00 6189.80 Top Nuiq_1::Nuiq_1_D11 20180.00 86.97 128.79 6247.45 6191.25 Total Depth 20952.00 87.45 131.30 6290.04 6233.84 i li F I Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-17 L1 Permit to Drill:210-140 API: 50-703-20622-60-00 Sperry Drilling Definitive Survey Report 19 October, 2010 HALLIBURTON Sperry Drilling 1 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-17-Slot ODS-17 Well Position +N/-S 0.00 ft Northing: 6,031,056.25 ft Latitude: 70°29'45.303 N +EI-W 0.00 ft Easting: 469,826.11 ft Longitude: 150°14'48.230 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-17 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-17 L1 PN13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 14,180.00 Vertical Section: Depth From(TVD) +N/-S +EJ-W Direction (ft) (ft) (ft) (?) I 42.70 0.00 0.00 194.97 Survey Program Date 10/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,105.00 ODSN-17 Gyro(ODSN-17 PN13 mid) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 8/26/2010 1: 1,154.91 4,612.64 ODSN-17 MWD 1 (ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8/27/2010 1: 4,710.05 10,949.10 ODSN-17 MWD 2(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/7/2010 12: 11,042.53 14,070.86 ODSN-17 MWD 3(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9/21/2010 1: 14,156.32 14,180.00 ODSN-17 MWD 4(ODSN-17 PN13 mid) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/4/2010 1: 14,219.23 20,917.84 ODSN-17L1 PN13 MWD 5(ODSN-17 L'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/12/2010 Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,056.25 469,826.11 0.00 0.00 UNDEFINED 100.00 0.35 5.53 100.00 43.80 0.18 0.02 6,031,056.43 469,826.13 0.61 -0.17 SR-Gyro-SS(1) 172.00 0.78 357.31 172.00 115.80 0.88 0.01 6,031,057.13 469,826.13 0.61 -0.86 SR-Gyro-SS(1) 218.00 0.77 11.51 217.99 161.79 1.50 0.06 6,031,057.75 469,826.18 0.42 -1.46 SR-Gyro-SS(1) 264.00 0.67 32.05 263.99 207.79 2.03 0.27 6,031,058.28 469,826.38 0.60 -2.03 SR-Gyro-SS(1) 310.00 0.51 59.03 309.99 253.79 2.36 0.58 6,031,058.61 469,826.70 0.69 -2.43 SR-Gyro-SS(1) 356.00 1.45 98.70 355.98 299.78 2.38 1.33 6,031,058.63 469,827.45 2.41 -2.64 SR-Gyro-SS(1) 399.00 1.30 100.16 398.97 342.77 2.21 2.35 6,031,058.45 469,828.47 0.36 -2.74 SR-Gyro-SS(1) 445.00 1.49 102.67 444.95 388.75 1.99 3.45 6,031,058.23 469,829.57 0.43 -2.81 SR-Gyro-SS(1) 493.00 1.12 103.85 492.94 436.74 1.74 4.51 6,031,057.97 469,830.63 0.77 -2.85 SR-Gyro-SS(1) 10/192010 3.38:19PM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 539.00 0.59 88.47 538.94 482.74 1.64 5.19 6,031,057.87 469,831.30 1.25 -2.92 SR-Gyro-SS(1) I 585.00 0.57 339.47 584.93 528.73 1.86 5.34 6,031,058.09 469,831.46 2.05 -3.18 SR-Gyro-SS(1) 631.00 2.15 303.65 630.92 574.72 2.55 4.54 6,031,058.78 469,830.66 3.74 -3.64 SR-Gyro-SS(1) 679.00 2.89 299.16 678.87 622.67 3.64 2.74 6,031,059.88 469,828.86 1.59 -4.22 SR-Gyro-SS(1) 725.00 4.49 297.38 724.78 668.58 5.03 0.13 6,031,061.28 469,826.26 3.49 -4.89 SR-Gyro-SS(1) 775.00 5.09 297.86 774.60 718.40 6.97 -3.57 6,031,063.23 469,822.57 1.20 -5.81 SR-Gyro-SS(1) 821.00 6.25 296.89 820.38 764.18 9.06 -7.61 6,031,065.34 469,818.54 2.53 -6.78 SR-Gyro-SS(1) 870.00 6.52 296.43 869.07 812.87 11.50 -12.48 6,031,067.80 469,813.68 0.56 -7.89 SR-Gyro-SS(1) 916.00 6.47 297.18 914.78 858.58 13.85 -17.12 6,031,070.17 469,809.04 0.21 -8.95 SR-Gyro-SS(1) 964.00 6.72 300.83 962.46 906.26 16.52 -21.94 6,031,072.86 469,804.24 1.02 -10.29 SR-Gyro-SS(1) 1,010.00 7.59 303.62 1,008.10 951.90 19.58 -26.78 6,031,075.94 469,799.41 2.04 -12.00 SR-Gyro-SS(1) 1,059.00 8.84 304.73 1,056.60 1,000.40 23.52 -32.57 6,031,079.90 469,793.64 2.57 -14.31 SR-Gyro-SS(1) 1,105.00 10.33 306.26 1,101.95 1,045.75 27.97 -38.80 6,031,084.38 469,787.43 3.29 -17.00 SR-Gyro-SS(1) 1,154.91 10.97 306.14 1,151.00 1,094.80 33.42 -46.25 6,031,089.85 469,780.01 1.28 -20.34 MWD+IFR2+MS+sag(2) 1,249.75 12.79 310.01 1,243.81 1,187.61 45.49 -61.57 6,031,101.99 469,764.73 2.09 -28.04 MWD+IFR2+MS+sag(2) 1,345.36 14.25 306.47 1,336.77 1,280.57 59.29 -79.14 6,031,115.86 469,747.21 1.75 -36.84 MWD+IFR2+MS+sag(2) 1,441.50 16.46 305.59 1,429.47 1,373.27 74.25 -99.74 6,031,130.90 469,726.68 2.31 -45.97 MWD+IFR2+MS+sag(2) 1,535.55 17.50 301.22 1,519.42 1,463.22 89.34 -122.67 6,031,146.08 469,703.82 1.75 -54.62 MWD+IFR2+MS+sag(2) 1,630.45 18.59 302.17 1,609.66 1,553.46 104.79 -147.68 6,031,161.63 469,678.88 1.19 -63.09 MWD+IFR2+MS+sag(2) 1,696.70 18.80 298.73 1,672.41 1,616.21 115.54 -165.98 6,031,172.46 469,660.62 1.69 -68.75 MWD+IFR2+MS+sag(2) 1,757.05 18.77 298.18 1,729.55 1,673.35 124.80 -183.06 6,031,181.78 469,643.57 0.30 -73.28 MWD+IFR2+MS+sag(2) 1,852.52 20.92 295.54 1,819.34 1,763.14 139.41 -211.98 6,031,196.50 469,614.71 2.44 -79.92 MWD+IFR2+MS+sag(2) 1,947.56 25.06 292.03 1,906.82 1,850.62 154.28 -245.97 6,031,211.51 469,580.79 4.59 -85.51 MWD+IFR2+MS+sag(2) 2,042.11 27.21 292.05 1,991.70 1,935.50 169.91 -284.57 6,031,227.29 469,542.26 2.27 -90.63 MWD+IFR2+MS+sag(2) 2,137.05 30.84 291.63 2,074.70 2,018.50 187.03 -327.32 6,031,244.59 469,499.58 3.83 -96.13 MWD+IFR2+MS+sag(2) 2,232.35 31.42 292.38 2,156.28 2,100.08 205.50 -373.00 6,031,263.24 469,453.98 0.73 -102.17 MWD+IFR2+MS+sag(2) 2,327.45 35.63 292.98 2,235.54 2,179.34 225.76 -421.45 6,031,283.69 469,405.63 4.44 -109.23 MWD+IFR2+MS+sag(2) 2,422.51 38.40 290.54 2,311.44 2,255.24 246.93 -474.60 6,031,305.08 469,352.57 3.30 -115.95 MWD+IFR2+MS+sag(2) 2,517.34 42.48 288.71 2,383.60 2,327.40 267.55 -532.53 6,031,325.93 469,294.72 4.48 -120.90 MWD+IFR2+MS+sag(2) 2,613.42 46.37 284.64 2,452.22 2,396.02 286.75 -596.94 6,031,345.39 469,230.40 5.02 -122.82 MWD+IFR2+MS+sag(2) 2,708.38 48.97 279.31 2,516.18 2,459.98 301.24 -665.58 6,031,360.16 469,161.83 4.97 -119.09 MWD+IFR2+MS+sag(2) 2,803.28 51.29 273.38 2,577.05 2,520.85 309.22 -737.91 6,031,368.43 469,089.54 5.38 -108.11 MWD+IFR2+MS+sag(2) 2,899.43 54.08 268.08 2,635.35 2,579.15 310.13 -814.32 6,031,369.65 469,013.14 5.26 -89.25 MWD+IFR2+MS+sag(2) 2,994.43 56.77 265.45 2,689.27 2,633.07 305.69 -892.40 6,031,365.52 468,935.05 3.63 -64.79 MWD+IFR2+MS+sag(2) 3,090.16 59.62 263.56 2,739.72 2,683.52 297.88 -973.36 6,031,358.04 468,854.06 3.42 -36.33 MWD+IFR2+MS+sag(2) 3,185.33 63.02 262.45 2,785.39 2,729.19 287.70 -1,056.22 6,031,348.20 468,771.17 3.72 -5.10 MWD+IFR2+MS+sag(2) 1 3,279.10 65.81 261.16 2,825.88 2,769.68 275.63 -1,139.92 6,031,336.48 468,687.44 3.22 28.18 MWD+IFR2+MS+sag(2) 1 3,374.77 70.37 260.38 2,861.57 2,805.37 261.39 -1,227.50 6,031,322.59 468,599.80 4.83 64.56 MWD+IFR2+MS+sag(2) 3,469.87 72.08 259.20 2,892.18 2,835.98 245.42 -1,316.11 6,031,306.99 468,511.14 2.15 102.87 MWD+IFR2+MS+sag(2) 3,565.72 70.73 257.02 2,922.74 2,866.54 226.72 -1,405.00 6,031,288.64 468,422.18 2.57 143.91 MWD+IFR2+MS+sag(2) 1 10/1912010 3.38:19PM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) 1 Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) 1 Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (7) (7) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,661.41 70.08 255.90 2,954.84 2,898.64 205.61 -1,492.64 6,031,267.90 468,334.47 1.30 186.94 MWD+IFR2+MS+sag(2) 3,756.32 70.91 255.84 2,986.52 2,930.32 183.77 -1,579.40 6,031,246.41 468,247.63 0.88 230.45 MWD+IFR2+MS+sag(2) 3,851.14 71.00 256.41 3,017.47 2,961.27 162.28 -1,666.41 6,031,225.27 468,160.54 0.58 273.69 MWD+IFR2+MS+sag(2) 3,945.82 70.58 256.69 3,048.62 2,992.42 141.48 -1,753.37 6,031,204.83 468,073.51 0.52 316.24 MWD+IFR2+MS+sag(2) 4,041.02 71.21 257.51 3,079.78 3,023.58 121.40 -1,841.05 6,031,185.11 467,985.75 1.05 358.29 MWD+IFR2+MS+sag(2) 4,136.12 71.00 258.58 3,110.57 3,054.37 102.76 -1,929.07 6,031,166.83 467,897.66 1.09 399.03 MWD+IFR2+MS+sag(2) 4,231.28 70.01 259.27 3,142.33 3,086.13 85.53 -2,017.11 6,031,149.96 467,809.57 1.24 438.42 MWD+IFR2+MS+sag(2) 4,326.25 70.46 258.64 3,174.45 3,118.25 68.41 -2,104.83 6,031,133.19 467,721.79 0.78 477.62 MWD+IFR2+MS+sag(2) 4,421.27 70.63 258.51 3,206.10 3,149.90 50.66 -2,192.64 6,031,115.80 467,633.91 0.22 517.45 MWD+IFR2+MS+sag(2) 4,516.95 70.67 258.35 3,237.80 3,181.60 32.55 -2,281.09 6,031,098.06 467,545.41 0.16 557.79 MWD+IFR2+MS+sag(2) 4,612.64 70.46 259.48 3,269.64 3,213.44 15.20 -2,369.64 6,031,081.07 467,456.79 1.14 597.42 MWD+IFR2+MS+sag(2) 4,710.05 71.86 259.82 3,301.09 3,244.89 -1.36 -2,460.33 6,031,064.88 467,366.05 1.47 636.85 MWD+IFR2+MS+sag(3) 4,803.06 71.54 259.66 3,330.30 3,274.10 -17.09 -2,547.22 6,031,049.50 467,279.10 0.38 674.49 MWD+IFR2+MS+sag(3) 4,898.59 71.16 259.30 3,360.85 3,304.65 -33.61 -2,636.21 6,031,033.34 467,190.05 0.53 713.44 MWD+IFR2+MS+sag(3) 4,994.01 70.97 259.96 3,391.81 3,335.61 -49.86 -2,724.99 6,031,017.46 467,101.21 0.68 752.07 MWD+IFR2+MS+sag(3) 5,088.97 70.57 259.98 3,423.09 3,366.89 5,186.08 70.17 260.76 3,455.71 3,399.51 -65.47 -2,813.29 6,031,002.20 467,012.87 0.42 789.96 MWD+IFR2+MS+sag(3) -80.78 -2,903.46 6,030,987.27 466,922.64 0.86 828.04 MWD+IFR2+MS+sag(3) 5,278.62 70.69 260.22 3,486.71 3,430.51 -95.18 -2,989.46 6,030,973.21 466,836.59 0.79 864.17 MWD+IFR2+MS+sag(3) 5,376.29 71.16 259.12 3,518.63 3,462.43 -111.74 -3,080.26 6,030,957.03 466,745.73 1.17 903.62 MWD+IFR2+MS+sag(3) 5,469.55 70.84 256.79 3,548.99 3,492.79 -130.13 -3,166.50 6,030,938.98 466,659.43 2.39 943.67 MWD+IFR2+MS+sag(3) 5,564.83 70.64 255.55 3,580.42 3,524.22 -151.63 -3,253.83 6,030,917.84 466,572.02 1.25 987.00 MWD+IFR2+MS+sag(3) 5,659.60 70.97 254.92 3,611.58 3,555.38 -174.44 -3,340.38 6,030,895.38 466,485.39 0.72 1,031.39 MWD+IFR2+MS+sag(3) 5,754.46 70.75 254.41 3,642.69 3,586.49 -198.14 -3,426.80 6,030,872.04 466,398.88 0.56 1,076.61 MWD+IFR2+MS+sag(3) 5,848.47 70.70 254.77 3,673.72 3,617.52 -221.72 -3,512.35 6,030,848.81 466,313.24 0.37 1,121.49 MWD+IFR2+MS+sag(3) 5,943.87 70.12 255.24 3,705.71 3,649.51 -244.98 -3,599.17 6,030,825.91 466,226.34 0.76 1,166.38 MWD+IFR2+MS+sag(3) 6,040.89 70.30 255.87 3,738.55 3,682.35 -267.75 -3,687.57 6,030,803.50 466,137.85 0.64 1,211.21 MWD+IFR2+MS+sag(3) 6,135.45 70,37 257.19 3,770.38 3,714.18 -288.49 -3,774.17 6,030,783.11 466,051.18 1.32 1,253.62 MWD+IFR2+MS+sag(3) 6,231.22 70.89 258.90 3,802.14 3,745.94 -307.20 -3,862.55 6,030,764.76 465,962.73 1.77 1,294.53 MWD+IFR2+MS+sag(3) 6,325.15 71.08 260.28 3,832.75 3,776.55 -323.25 -3,949.89 6,030,749.07 465,875.34 1.40 1,332.59 MWD+IFR2+MS+sag(3) 6,421.02 70.77 260.20 3,864.08 3,807.88 -338.61 -4,039.19 6,030,734.07 465,785.99 0.33 1,370.49 MWD+IFR2+MS+sag(3) 6,516.19 70.75 260.29 3,895.44 3,839.24 -353.83 -4,127.74 6,030,719.21 465,697.38 0.09 1,408.08 MWD+IFR2+MS+sag(3) 6,613.33 70.35 260.71 3,927.79 3,871.59 -368.95 -4,218.08 6,030,704.46 465,606.99 0.58 1,446.02 MWD+IFR2+MS+sag(3) 6,706.26 70.37 261.96 3,959.02 3,902.82 -382.14 -4,304.60 6,030,691.63 465,520.42 1.27 1,481.10 MWD+IFR2+MS+sag(3) 6,800.98 70.63 260.84 3,990.64 3,934.44 -395.49 -4,392.89 6,030,678.63 465,432.10 1.15 1,516.81 MWD+IFR2+MS+sag(3) 6,896.38 70.76 261.31 4,022.18 3,965.98 -409.46 -4,481.83 6,030,665.03 465,343.11 0.48 1,553.28 MWD+IFR2+MS+sag(3) 6,992.18 70.91 260.31 4,053.63 3,997.43 -423.91 -4,571.16 6,030,650.94 465,253.73 1.00 1,590.31 MWD+IFR2+MS+sag(3) 7,088.03 71.15 259.90 4,084.79 4,028.59 -439.49 -4,660.45 6,030,635.73 465,164.38 0.48 1,628.43 MWD+IFR2+MS+sag(3) 7,182.18 71.35 259.30 4,115.05 4,058.85 -455.58 -4,748.14 6,030,619.99 465,076.64 0.64 1,666.63 MWD+IFR2+MS+sag(3) 7,277.41 71.34 257.39 4,145.52 4,089.32 -473.81 -4,836.50 6,030,602.13 464,988.21 1.90 1,707.06 MWD+IFR2+MS+sag(3) 7,372.56 70.96 257.20 4,176.26 4,120.06 -493.61 -4,924.35 6,030,582.68 464,900.30 0.44 1,748.88 MWD+IFR2+MS+sag(3) 10/192010 3:38:19PM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 7,468.27 70.82 257.82 4,207.59 4,151.39 -513.17 -5,012.64 6,030,563.48 464,811.93 0.63 1,790.59 MWD+IFR2+MS+sag(3) 7,563.47 70.03 257.84 4,239.49 4,183.29 -532.08 -5,100.32 6,030,544.93 464,724.19 0.83 1,831.50 MWD+IFR2+MS+sag(3) 7,658.61 70.36 258.45 4,271.72 4,215.52 -550.47 -5,187.92 6,030,526.90 464,636.52 0.70 1,871.90 MWD+IFR2+MS+sag(3) 7,754.46 70.37 258.66 4,303.93 4,247.73 -568.38 -5,276.41 6,030,509.35 464,547.97 0.21 1,912.06 MWD+IFR2+MS+sag(3) 7,848.82 70.25 259.03 4,335.72 4,279.52 -585.57 -5,363.57 6,030,492.52 464,460.75 0.39 1,951.18 MWD+IFR2+MS+sag(3) 7,945.27 70.68 259.62 4,367.98 4,311.78 -602.41 -5,452.89 6,030,476.04 464,371.37 0.73 1,990.52 MWD+IFR2+MS+sag(3) 8,038.91 70.82 259.69 4,398.85 4,342.65 -618.28 -5,539.86 6,030,460.52 464,284.34 0.17 2,028.32 MWD+IFR2+MS+sag(3) 8,134.96 70.96 260.58 4,430.29 4,374.09 -633.83 -5,629.28 6,030,445.34 464,194.88 0.89 2,066.43 MWD+IFR2+MS+sag(3) 8,230.17 71.28 260.76 4,461.10 4,404.90 -648.43 -5,718.17 6,030,431.10 464,105.93 0.38 2,103.51 MWD+IFR2+MS+sag(3) 8,324.98 71.15 260.58 4,491.63 4,435.43 -662.99 -5,806.74 6,030,416.91 464,017.31 0.23 2,140.44 MWD+IFR2+MS+sag(3) 8,420.04 70.82 260.48 4,522.60 4,466.40 -677.77 -5,895.39 6,030,402.48 463,928.61 0.36 2,177.63 MWD+IFR2+MS+sag(3) 8,515.53 70.29 260.55 4,554.39 4,498.19 -692.61 -5,984.20 6,030,388.00 463,839.75 0.56 2,214.90 MWD+IFR2+MS+sag(3) 8,609.58 70.82 260.71 4,585.70 4,529.50 -707.05 -6,071.71 6,030,373.92 463,752.20 0.59 2,251.46 MWD+IFR2+MS+sag(3) 8,705.65 71.28 260.48 4,616.90 4,560.70 -721.90 -6,161.35 6,030,359.44 463,662.51 0.53 2,288.96 MWD+IFR2+MS+sag(3) 8,801.16 71.66 259.31 4,647.26 4,591.06 -737.79 -6,250.50 6,030,343.91 463,573.30 1.23 2,327.33 MWD+IFR2+MS+sag(3) 8,896.34 70.45 258.87 4,678.16 4,621.96 -754.82 -6,338.89 6,030,327.24 463,484.84 1.34 2,366.63 MWD+IFR2+MS+sag(3) 8,991.27 70.09 258.28 4,710.20 4,654.00 -772.52 -6,426.48 6,030,309.89 463,397.20 0.70 2,406.35 MWD+IFR2+MS+sag(3) 9,086.77 70.30 258.61 4,742.56 4,686.36 -790.52 -6,514.51 6,030,292.26 463,309.10 0.39 2,446.48 MWD+IFR2+MS+sag(3) 9,182.69 70.49 258.53 4,774.75 4,718.55 -808.43 -6,603.08 6,030,274.71 463,220.47 0.21 2,486.65 MWD+IFR2+MS+sag(3) 9,277.16 70.87 258.94 4,806.00 4,749.80 -825.84 -6,690.51 6,030,257.65 463,132.98 0.57 2,526.06 MWD+IFR2+MS+sag(3) 9,372.89 69.98 259.04 4,838.07 4,781.87 -843.07 -6,779.05 6,030,240.79 463,044.38 0.93 2,565.57 MWD+IFR2+MS+sag(3) 9,467.20 70.36 259.56 4,870.07 4,813.87 -859.54 -6,866.22 6,030,224.67 462,957.15 0.66 2,604.00 MWD+IFR2+MS+sag(3) 9,563.91 71.00 259.30 4,902.06 4,845.86 -876.28 -6,955.93 6,030,208.30 462,867.38 0.71 2,643.35 MWD+IFR2+MS+sag(3) 9,659.05 71.01 258.16 4,933.03 4,876.83 -893.86 -7,044.16 6,030,191.08 462,779.09 1.13 2,683.13 MWD+IFR2+MS+sag(3) 9,752.68 70.89 257.04 4,963.59 4,907.39 -912.87 -7,130.59 6,030,172.43 462,692.59 1.14 2,723.81 MWD+IFR2+MS+sag(3) 9,849.04 71.03 257.88 4,995.03 4,938.83 -932.64 -7,219.51 6,030,153.01 462,603.60 0.84 2,765.89 MWD+IFR2+MS+sag(3) 9,943.96 71.22 258.20 5,025.73 4,969.53 -951.25 -7,307.37 6,030,134.76 462,515.67 0.38 2,806.56 MWD+IFR2+MS+sag(3) 10,039.79 70.31 256.57 5,057.31 5,001.11 -971.01 -7,395.67 6,030,115.36 462,427.31 1.87 2,848.46 MWD+IFR2+MS+sag(3) 10,134.14 71.07 253.76 5,088.51 5,032.31 -993.81 -7,481.73 6,030,092.91 462,341.16 2.92 2,892.71 MWD+IFR2+MS+sag(3) 10,229.16 71.22 250.69 5,119.23 5,063.03 -1,021.26 -7,567.34 6,030,065.82 462,255.45 3.06 2,941.35 MWD+IFR2+MS+sag(3) 10,324.49 71.07 247.66 5,150.04 5,093.84 -1,053.33 -7,651.65 6,030,034.10 462,171.02 3.01 2,994.10 MWD+IFR2+MS+sag(3) 10,419.51 70.82 244.06 5,181.07 5,124.87 -1,090.05 -7,733.60 6,029,997.71 462,088.93 3.59 3,050.74 MWD+IFR2+MS+sag(3) 10,508.96 70.45 240.96 5,210.74 5,154.54 -1,128.99 -7,808.45 6,029,959.07 462,013.93 3.30 3,107.70 MWD+IFR2+MS+sag(3) 10,610.40 70.69 236.81 5,244.49 5,188.29 -1,178.42 -7,890.32 6,029,909.99 461,931.86 3.87 3,176.60 MWD+IFR2+MS+sag(3) 10,705.79 71.54 232.94 5,275.38 5,219.18 -1,230.34 -7,964.12 6,029,858.37 461,857.86 3.94 3,245.82 MWD+IFR2+MS+sag(3) 10,800.97 70.83 229.60 5,306.08 5,249.88 -1,286.69 -8,034.40 6,029,802.31 461,787.37 3.40 3,318.42 MWD+IFR2+MS+sag(3) 10,895.62 70.57 224.59 5,337.39 5,281.19 -1,347.48 -8,099.81 6,029,741.79 461,721.72 5.00 3,394.04 MWD+IFR2+MS+sag(3) 10,949.10 70.78 223.14 5,355.08 5,298.88 -1,383.87 -8,134.78 6,029,705.55 461,686.61 2.59 3,438.22 MWD+IFR2+MS+sag(3) 11,042.53 71.73 222.09 5,385.11 5,328.91 -1,448.98 -8,194.68 6,029,640.69 461,626.45 1.47 3,516.59 MWD+IFR2+MS+sag(4) 11,088.41 71.75 221.46 5,399.48 5,343.28 -1,481.47 -8,223.70 6,029,608.32 461,597.29 1.30 3,555.48 MWD+IFR2+MS+sag(4) 10/192010 3:38:19PM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,183.91 70.74 219.27 5,430.19 5,373.99 -1,550.36 -8,282.27 6,029,539.67 461,538.45 2.42 3,637.16 MWD+IFR2+MS+sag(4) 11,279.14 71.02 215.72 5,461.39 5,405.19 -1,621.74 -8,337.02 6,029,468.53 461,483.41 3.53 3,720.26 MWD+IFR2+MS+sag(4) 11,373.84 71.41 212.82 5,491.89 5,435.69 -1,695.82 -8,387.50 6,029,394.66 461,432.64 2.93 3,804.87 MWD+IFR2+MS+sag(4) 11,469.31 71.08 209.09 5,522.60 5,466.40 -1,773.33 -8,433.99 6,029,317.35 461,385.84 3.72 3,891.75 MWD+IFR2+MS+sag(4) 11,565.32 70.57 205.46 5,554.14 5,497.94 -1,853.91 -8,475.54 6,029,236.94 461,343.97 3.61 3,980.33 MWD+IFR2+MS+sag(4) 11,660.83 72.20 201.49 5,584.64 5,528.44 -1,936.91 -8,511.57 6,029,154.10 461,307.60 4.29 4,069.83 MWD+IFR2+MS+sag(4) 11,755.15 72.84 198.69 5,612.98 5,556.78 -2,021.39 -8,542.47 6,029,069.75 461,276.37 2.91 4,159.43 MWD+IFR2+MS+sag(4) 11,850.51 73.61 195.85 5,640.51 5,584.31 -2,108.57 -8,569.57 6,028,982.69 461,248.92 2.96 4,250.64 MWD+IFR2+MS+sag(4) 11,946.56 73.95 192.22 5,667.34 5,611.14 -2,198.03 -8,591.93 6,028,893.34 461,226.20 3.65 4,342.84 MWD+IFR2+MS+sag(4) 12,042.13 73.74 188.24 5,693.94 5,637.74 -2,288.34 -8,608.23 6,028,803.10 461,209.53 4.01 4,434.30 MWD+IFR2+MS+sag(4) 12,136.56 73.79 184.72 5,720.35 5,664.15 -2,378.41 -8,618.46 6,028,713.08 461,198.94 3.58 4,523.95 MWD+IFR2+MS+sag(4) 12,231.94 74.12 183.17 5,746.72 5,690.52 -2,469.86 -8,624.76 6,028,621.67 461,192.26 1.60 4,613.92 MWD+IFR2+MS+sag(4) 12,326.15 73.47 181.03 5,773.01 5,716.81 -2,560.26 -8,628.08 6,028,531.29 461,188.58 2.29 4,702.11 MWD+IFR2+MS+sag(4) 12,421.45 73.28 179.34 5,800.28 5,744.08 -2,651.57 -8,628.38 6,028,439.99 461,187.91 1.71 4,790.40 MWD+IFR2+MS+sag(4) 12,516.10 74.76 177.01 5,826.34 5,770.14 -2,742.50 -8,625.47 6,028,349.05 461,190.45 2.84 4,877.50 MWD+IFR2+MS+sag(4) 12,612.64 75.21 175.12 5,851.35 5,795.15 -2,835.52 -8,619.07 6,028,256.02 461,196.47 1.95 4,965.71 MWD+IFR2+MS+sag(4) 12,707.53 74.31 172.56 5,876.30 5,820.10 -2,926.54 -8,609.25 6,028,164.97 461,205.92 2.77 5,051.10 MWD+IFR2+MS+sag(4) 12,797.87 74.71 170.43 5,900.43 5,844.23 -3,012.63 -8,596.38 6,028,078.84 461,218.44 2.31 5,130.95 MWD+IFR2+MS+sag(4) 12,897.12 74.83 166.63 5,926.51 5,870.31 -3,106.47 -8,577.34 6,027,984.94 461,237.10 3.70 5,216.68 MWD+IFR2+MS+sag(4) 12,993.65 75.07 163.20 5,951.58 5,895.38 -3,196.46 -8,553.08 6,027,894.86 461,260.99 3.44 5,297.35 MWD+IFR2+MS+sag(4) 13,090.13 76.50 158.81 5,975.28 5,919.08 -3,284.86 -8,522.64 6,027,806.34 461,291.07 4.65 5,374.89 MWD+IFR2+MS+sag(4) 13,183.84 76.56 155.90 5,997.12 5,940.92 -3,368.96 -8,487.55 6,027,722.11 461,325.81 3.02 5,447.07 MWD+IFR2+MS+sag(4) 13,278.88 76.22 153.10 6,019.48 5,963.28 -3,452.32 -8,447.79 6,027,638.59 461,365.23 2.89 5,517.33 MWD+IFR2+MS+sag(4) 13,373.87 76.86 151.23 6,041.60 5,985.40 -3,534.01 -8,404.66 6,027,556.74 461,408.03 2.03 5,585.10 MWD+IFR2+MS+sag(4) 13,468.91 77.43 149.40 6,062.74 6,006.54 -3,614.50 -8,358.77 6,027,476.07 461,453.58 1.97 5,651.01 MWD+IFR2+MS+sag(4) 13,564.20 77.50 146.25 6,083.43 6,027.23 -3,693.22 -8,309.24 6,027,397.16 461,502.78 3.23 5,714.27 MWD+IFR2+MS+sag(4) 13,658.27 78.51 143.53 6,102.98 6,046.78 -3,768.48 -8,256.32 6,027,321.69 461,555.39 3.03 5,773.31 MWD+IFR2+MS+sag(4) 13,753.68 78.76 142.94 6,121.78 6,065.58 -3,843.42 -8,200.34 6,027,246.54 461,611.07 0.66 5,831.23 MWD+IFR2+MS+sag(4) 13,848.63 79.02 142.71 6,140.08 6,083.88 -3,917.66 -8,144.04 6,027,172.08 461,667.06 0.36 5,888.41 MWD+IFR2+MS+sag(4) 13,944.20 79.65 142.01 6,157.77 6,101.57 -3,992.03 -8,086.68 6,027,097.48 461,724.11 0.98 5,945.44 MWD+IFR2+MS+sag(4) 14,038.97 80.15 139.71 6,174.39 6,118.19 -4,064.38 -8,027.79 6,027,024.89 461,782.70 2.45 6,000.13 MWD+IFR2+MS+sag(4) 14,070.86 80.28 139.78 6,179.81 6,123.61 -4,088.37 -8,007.49 6,027,000.83 461,802.91 0.46 6,018.05 MWD+IFR2+MS+sag(4) 14,156.32 80.88 139.42 6,193.80 6,137.60 -4,152.57 -7,952.84 6,026,936.41 461,857.28 0.82 6,065.96 MWD+IFR2+MS+sag(5) 14,180.00 81.81 139.36 6,197.36 6,141.16 -4,170.34 -7,937.61 6,026,918.58 461,872.44 3.94 6,079.20 MWD+IFR2+MS+sag(5) 14,219.23 80.07 138.64 6,203.54 6,147.34 -4,199.58 -7,912.19 6,026,889.24 461,897.74 4.79 6,100.87 MWD+IFR2+MS+sag(6) 14,315.03 85.35 136.60 6,215.69 6,159.49 -4,269.74 -7,848.16 6,026,818.83 461,961.48 5.90 6,152.11 MWD+IFR2+MS+sag(6) 14,412.28 90.36 136.54 6,219.33 6,163.13 -4,340.29 -7,781.37 6,026,748.02 462,027.97 5.15 6,203.02 MWD+IFR2+MS+sag(6) 14,508.63 90.30 129.73 6,218.77 6,162.57 -4,406.13 -7,711.10 6,026,681.90 462,097.97 7.07 6,248.47 MWD+IFR2+MS+sag(6) 14,539.96 90.24 127.31 6,218.62 6,162.42 -4,425.64 -7,686.59 6,026,662.30 462,122.40 7.73 6,260.99 MWD+IFR2+MS+sag(6) 14,572.04 90.11 124.94 6,218.53 6,162.33 -4,444.55 -7,660.68 6,026,643.28 462,148.23 7.40 6,272.56 MWD+IFR2+MS+sag(6) 10/1912010 3:38:19PM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,605.35 89.74 121.34 6,218.57 6,162.37 -4,462.76 -7,632.79 6,026,624.96 462,176.04 10.86 6,282.95 MWD+IFR2+MS+sag(6) 14,636.51 89.93 119.87 6,218.66 6,162.46 -4,478.62 -7,605.98 6,026,608.99 462,202.79 4.76 6,291.34 MWD+IFR2+MS+sag(6) 14,669.14 89.99 117.83 6,218.68 6,162.48 -4,494.36 -7,577.40 6,026,593.13 462,231.30 6.25 6,299.17 MWD+IFR2+MS+sag(6) 14,700.74 90.24 117.02 6,218.62 6,162.42 -4,508.92 -7,549.35 6,026,578.47 462,259.29 2.68 6,305.99 MWD+IFR2+MS+sag(6) 14,797.43 92.09 119.50 6,216.65 6,160.45 -4,554.68 -7,464.21 6,026,532.36 462,344.23 3.20 6,328.21 MWD+IFR2+MS+sag(6) 14,893.76 91.35 125.17 6,213.76 6,157.56 -4,606.16 -7,382.89 6,026,480.56 462,425.33 5.93 6,356.93 MWD+IFR2+MS+sag(6) 14,990.76 90.67 128.86 6,212.05 6,155.85 -4,664.54 -7,305.46 6,026,421.87 462,502.51 3.87 6,393.33 MWD+IFR2+MS+sag(6) 15,087.17 89.25 130.69 6,212.12 6,155.92 -4,726.21 -7,231.37 6,026,359.90 462,576.35 2.40 6,433.77 MWD+IFR2+MS+sag(6) 15,183.95 90.11 135.01 6,212.66 6,156.46 -4,792.02 -7,160.44 6,026,293.82 462,647.01 4.55 6,479.02 MWD+IFR2+MS+sag(6) 15,279.90 87.14 136.50 6,214.96 6,158.76 -4,860.72 -7,093.52 6,026,224.85 462,713.64 3.46 6,528.10 MWD+IFR2+MS+sag(6) 15,376.12 86.71 140.58 6,220.12 6,163.92 -4,932.71 -7,029.92 6,026,152.61 462,776.94 4.26 6,581.22 MWD+IFR2+MS+sag(6) 15,472.70 89.19 142.34 6,223.58 6,167.38 -5,008.20 -6,969.79 6,026,076.89 462,836.76 3.15 6,638.61 MWD+IFR2+MS+sag(6) 15,569.44 90.85 142.14 6,223.54 6,167.34 -5,084.67 -6,910.55 6,026,000.18 462,895.68 1.73 6,697.19 MWD+IFR2+MS+sag(6) 15,665.85 91.04 138.06 6,221.95 6,165.75 -5,158.61 -6,848.73 6,025,926.00 462,957.19 4.24 6,752.65 MWD+IFR2+MS+sag(6) 15,762.67 91.53 137.47 6,219.78 6,163.58 -5,230.28 -6,783.67 6,025,854.08 463,021.96 0.79 6,805.08 MWD+IFR2+MS+sag(6) 15,859.02 90.54 138.46 6,218.04 6,161.84 -5,301.83 -6,719.16 6,025,782.27 463,086.16 1.45 6,857.54 MWD+IFR2+MS+sag(6) 15,955.65 90.48 137.69 6,217.18 6,160.98 -5,373.72 -6,654.60 6,025,710.13 463,150.42 0.80 6,910.31 MWD+IFR2+MS+sag(6) 16,050.92 91.10 138.45 6,215.87 6,159.67 -5,444.59 -6,590.95 6,025,639.01 463,213.78 1.03 6,962.33 MWD+IFR2+MS+sag(6) 16,147.19 88.63 138.41 6,216.09 6,159.89 -5,516.61 -6,527.07 6,025,566.74 463,277.36 2.57 7,015.41 MWD+IFR2+MS+sag(6) 16,241.79 86.90 139.96 6,219.78 6,163.58 -5,588.14 -6,465.29 6,025,494.96 463,338.84 2.45 7,068.56 MWD+IFR2+MS+sag(6) 16,338.30 87.64 141.67 6,224.38 6,168.18 -5,662.86 -6,404.39 6,025,420.00 463,399.44 1.93 7,125.01 MWD+IFR2+MS+sag(6) 16,437.25 88.26 141.62 6,227.92 6,171.72 -5,740.40 -6,343.03 6,025,342.22 463,460.48 0.63 7,184.07 MWD+IFR2+MS+sag(6) 16,533.51 87.08 140.09 6,231.83 6,175.63 -5,814.99 -6,282.31 6,025,267.39 463,520.88 2.01 7,240.45 MWD+IFR2+MS+sag(6) 16,629.54 87.21 140.64 6,236.62 6,180.42 -5,888.86 -6,221.13 6,025,193.29 463,581.76 0.59 7,296.00 MWD+IFR2+MS+sag(6) 16,726.75 87.82 143.00 6,240.83 6,184.63 -5,965.19 -6,161.10 6,025,116.71 463,641.47 2.51 7,354.24 MWD+IFR2+MS+sag(6) 16,822.82 88.88 142.27 6,243.60 6,187.40 -6,041.52 -6,102.82 6,025,040.16 463,699.43 1.34 7,412.91 MWD+IFR2+MS+sag(6) 16,919.83 89.62 138.83 6,244.87 6,188.67 -6,116.41 -6,041.20 6,024,965.03 463,760.75 3.63 7,469.35 MWD+IFR2+MS+sag(6) 17,016.37 91.16 137.83 6,244.21 6,188.01 -6,188.52 -5,977.02 6,024,892.67 463,824.62 1.90 7,522.43 MWD+IFR2+MS+sag(6) 17,112.58 93.33 138.82 6,240.44 6,184.24 -6,260.32 -5,913.10 6,024,820.62 463,888.24 2.48 7,575.28 MWD+IFR2+MS+sag(6) 17,207.86 92.40 138.80 6,235.68 6,179.48 -6,331.93 -5,850.43 6,024,748.76 463,950.61 0.98 7,628.27 MWD+IFR2+MS+sag(6) 17,304.97 91.78 139.00 6,232.14 6,175.94 -6,405.06 -5,786.64 6,024,675.38 464,014.11 0.67 7,682.44 MWD+IFR2+MS+sag(6) 17,402.92 89.80 138.06 6,230.79 6,174.59 -6,478.44 -5,721.78 6,024,601.74 464,078.66 2.24 7,736.58 MWD+IFR2+MS+sag(6) 17,498.27 92.95 138.26 6,228.50 6,172.30 -6,549.45 -5,658.21 6,024,530.48 464,141.94 3.31 7,788.76 MWD+IFR2+MS+sag(6) 17,594.02 89.31 137.60 6,226.61 6,170.41 -6,620.50 -5,594.07 6,024,459.18 464,205.78 3.86 7,840.83 MWD+IFR2+MS+sag(6) 17,691.58 87.45 136.52 6,229.37 6,173.17 -6,691.89 -5,527.64 6,024,387.53 464,271.91 2.20 7,892.64 MWD+IFR2+MS+sag(6) 17,787.04 83.92 135.15 6,236.55 6,180.35 -6,760.16 -5,461.34 6,024,319.00 464,337.93 3.97 7,941.46 MWD+IFR2+MS+sag(6) 17,883.33 84.85 140.05 6,245.98 6,189.78 -6,830.90 -5,396.74 6,024,248.00 464,402.23 5.16 7,993.12 MWD+IFR2+MS+sag(6) 17,980.12 88.20 143.96 6,251.85 6,195.65 -6,907.02 -5,337.29 6,024,171.65 464,461.36 5.31 8,051.30 MWD+IFR2+MS+sag(6) 18,076.70 89.19 142.40 6,254.05 6,197.85 -6,984.31 -5,279.43 6,024,094.13 464,518.91 1.91 8,111.02 MWD+IFR2+MS+sag(6) 18,173.14 90.36 139.86 6,254.43 6,198.23 -7,059.38 -5,218.92 6,024,018.82 464,579.11 2.90 8,167.91 MWD+IFR2+MS+sag(6) 10119/2010 3.38:19PM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-17 -Slot ODS-17 Project: Oooguruk Development TVD Reference: WELL @ 56.20ft(Original Well Elev) Site: Oooguruk Drill Site MD Reference: WELL @ 56.20ft(Original Well Elev) Well: ODSN-17 North Reference: True Wellbore: ODSN-17 L1 Survey Calculation Method: Minimum Curvature Design: ODSN-17 L1 PN13 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18,269.89 93.08 141.32 6,251.52 6,195.32 -7,134.09 -5,157.53 6,023,943.87 464,640.19 3.19 8,224.23 MWD+IFR2+MS+sag(6) 18,365.72 93.82 139.93 6,245.76 6,189.56 -7,208.03 -5,096.85 6,023,869.69 464,700.57 1.64 8,279.99 MWD+IFR2+MS+sag(6) 18,462.13 92.71 136.43 6,240.26 6,184.06 -7,279.75 -5,032.67 6,023,797.72 464,764.44 3.80 8,332.69 MWD+IFR2+MS+sag(6) 18,558.62 91.04 133.64 6,237.11 6,180.91 -7,347.98 -4,964.53 6,023,729.23 464,832.30 3.37 8,381.00 MWD+IFR2+MS+sag(6) 18,655.38 91.47 133.37 6,234.99 6,178.79 -7,414.57 -4,894.37 6,023,662.35 464,902.18 0.52 8,427.21 MWD+IFR2+MS+sag(6) 18,751.33 86.83 134.17 6,236.41 6,180.21 -7,480.92 -4,825.11 6,023,595.73 464,971.17 4.91 8,473.42 MWD+IFR2+MS+sag(6) 18,848.17 87.27 136.42 6,241.39 6,185.19 -7,549.65 -4,757.08 6,023,526.73 465,038.91 2.36 8,522.24 MWD+IFR2+MS+sag(6) 18,944.77 87.15 136.11 6,246.10 6,189.90 -7,619.37 -4,690.38 6,023,456.75 465,105.32 0.34 8,572.36 MWD+IFR2+MS+sag(6) 19,040.81 86.65 135.73 6,251.29 6,195.09 -7,688.26 -4,623.66 6,023,387.60 465,171.75 0.65 8,621.68 MWD+IFR2+MS+sag(6) 19,137.97 85.84 135.04 6,257.65 6,201.45 -7,757.27 -4,555.57 6,023,318.32 465,239.55 1.09 8,670.77 MWD+IFR2+MS+sag(6) 19,234.67 87.39 135.97 6,263.36 6,207.16 -7,826.13 -4,487.92 6,023,249.19 465,306.91 1.87 8,719.81 MWD+IFR2+MS+sag(6) 19,330.50 89.80 136.28 6,265.71 6,209.51 -7,895.18 -4,421.53 6,023,179.88 465,373.02 2.54 8,769.37 MWD+IFR2+MS+sag(6) 19,426.67 91.66 135.67 6,264.49 6,208.29 -7,964.32 -4,354.70 6,023,110.47 465,439.56 2.04 8,818.90 MWD+IFR2+MS+sag(6) 19,522.98 92.16 132.30 6,261.28 6,205.08 -8,031.16 -4,285.45 6,023,043.36 465,508.53 3.54 8,865.58 MWD+IFR2+MS+sag(6) 19,619.59 90.91 131.14 6,258.69 6,202.49 -8,095.43 -4,213.37 6,022,978.81 465,580.34 1.76 8,909.05 MWD+IFR2+MS+sag(6) 19,715.94 89.80 131.63 6,258.09 6,201.89 -8,159.12 -4,141.08 6,022,914.83 465,652.36 1.26 8,951.91 MWD+IFR2+MS+sag(6) 19,811.89 90.36 133.43 6,257.96 6,201.76 -8,223.98 -4,070.38 6,022,849.69 465,722.80 1.96 8,996.30 MWD+IFR2+MS+sag(6) 19,908.75 92.58 134.72 6,255.47 6,199.27 -8,291.33 -4,000.82 6,022,782.07 465,792.07 2.65 9,043.39 MWD+IFR2+MS+sag(6) 20,005.66 92.15 134.88 6,251.47 6,195.27 -8,359.55 -3,932.11 6,022,713.57 465,860.49 0.47 9,091.56 MWD+IFR2+MS+sag(6) 20,101.60 93.14 133.20 6,247.05 6,190.85 -8,426.17 -3,863.23 6,022,646.68 465,929.11 2.03 9,138.12 MWD+IFR2+MS+sag(6) 20,132.81 90.60 130.82 6,246.03 6,189.83 -8,447.05 -3,840.05 6,022,625.71 465,952.19 11.15 9,152.30 MWD+IFR2+MS+sag(6) 20,165.99 87.02 128.94 6,246.72 6,190.52 -8,468.31 -3,814.60 6,022,604.34 465,977.56 12.19 9,166.27 MWD+IFR2+MS+sag(6) 20,198.58 86.90 128.59 6,248.44 6,192.24 -8,488.69 -3,789.22 6,022,583.87 466,002.85 1.13 9,179.40 MWD+IFR2+MS+sag(6) 20,230.18 86.90 129.37 6,250.15 6,193.95 -8,508.54 -3,764.70 6,022,563.92 466,027.29 2.46 9,192.24 MWD+IFR2+MS+sag(6) 20,294.32 86.15 129.77 6,254.04 6,197.84 -8,549.32 -3,715.35 6,022,522.94 466,076.47 1.32 9,218.89 MWD+IFR2+MS+sag(6) 20,390.67 85.23 131.37 6,261.28 6,205.08 -8,611.80 -3,642.37 6,022,460.17 466,149.19 1.91 9,260.40 MWD+IFR2+MS+sag(6) 20,487.78 86.77 135.46 6,268.06 6,211.86 -8,678.37 -3,572.02 6,022,393.33 466,219.26 4.49 9,306.54 MWD+IFR2+MS+sag(6) 20,583.93 87.39 136.11 6,272.96 6,216.76 -8,747.19 -3,505.05 6,022,324.24 466,285.93 0.93 9,355.73 MWD+IFR2+MS+sag(6) 20,680.93 88.32 135.47 6,276.59 6,220.39 -8,816.67 -3,437.47 6,022,254.49 466,353.23 1.16 9,405.39 MWD+IFR2+MS+sag(6) 20,777.24 86.90 133.03 6,280.60 6,224.40 -8,883.81 -3,368.55 6,022,187.08 466,421.87 2.93 9,452.45 MWD+IFR2+MS+sag(6) 20,873.16 86.47 131.60 6,286.15 6,229.95 -8,948.28 -3,297.74 6,022,122.34 466,492.41 1.55 9,496.43 MWD+IFR2+MS+sag(6) 20,917.84 87.45 131.30 6,288.52 6,232.32 -8,977.81 -3,264.30 6,022,092.67 466,525.73 2.29 9,516.33 MWD+IFR2+MS+sag(6) 20,952.00 87.45 131.30 6,290.04 6,233.84 -9,000.33 -3,238.66 6,022,070.04 466,551.27 0.00 9,531.46 PROJECTED to TD 10/192010 3.38:19PM Page 8 COMPASS 2003.16 Build 42F HALLIBURTON Sperry Drilling Oooguruk ODSN-17 L1 2000 t____3000 - �____._ _ �` me_ P I.3� I E lZ 4000 - - - N _ 5000 - - _, — ..i 6000 - - 7000 __ 8000 - N. 9000 . _L 10000 - -- - t 4-1 CD11000 - ifl _ 12000 L - g I Begin drillingODSN-17L1 Oct U) 13000 - -- .- 11th,2010 from kick-off at a siiiiii 14180'MD,6197'TVD C� c 14000 __ ,...--,-J. ..._---2_1_, I \__..._.-. 15000 16000 i I imi — Em 17000imm 18000 -- __ r i 1 TD 6 1/8"ODSN-17L1 Production 19000 Section 20952'MD,6290'TVD, Oct 14th,2010 1 ii 20000 - Run 4 1/2" i /Liner 21000 - I�/ 1 22000 - i 0 10 20 30 40 50 60 Rig Days HALLIBURTON Sperry Drilling Surface Data Logging After Action Review Employee Name: Tom Mansfield Date: 10/18/2010 Well: ODSN-17 L1 Hole Section: Production What went as, or better than, planned: Difficulties experienced: After a failure of the MADI machine, a temporary fix was made where the Primary computer data exchanged to MADI. Problem occurred when the data exchange failed and had to be restarted on the Primary. When restarting the Primary's exchange SDL's records were not restricted leading to SDL records being overwritten in the MADI machine. Recommendations: No data exchanges to Madi Innovations and/or cost savings: None L 8ELART*R9 I Sperry traitarag ODSN-17L1 API 50-703-20622-60-00 Digital Data EMF & PDF Logs ADI End of Well Report Halliburton Log Viewer EMF Viewer PIONEER OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
