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209-155
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,852 NA Casing Collapse Conductor NA Surface 3,180psi Intermediate 1 3,090psi Intermediate 2 5,410psi Liner 7,500psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NA WFT Hydrow-II Packer, WFT "NTH" Liner Top Packer, and "NE' TRSV 3,101' MD / 2,689' TVD, 10,243' MD / 6,124' TVD, and 2,150' MD / 2,057' TVD NA 13,769 10,394 3,537 See Schematic 907-777-8503 ryan.rupert@hilcorp.com Operations Manager October 1, 2025 2-7/8" Perforation Depth MD (ft): See Schematic 6,1644-1/2" 158 16" 11-3/4" 9-5/8" 3,557 7"10,356 4,452 5,830psi 5,750psi 2,938 5,284 6,139 3,557 7,853 158 158 6.4# / L-80 TVD Burst 9,939 8,430psi MD NA 7,240psi Hilcorp Alaska, LLC Length Size Proposed Pools: 6,166 13,769 6,164 2,020 KUPARUK OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355036 209-155 OOOGURUK KUP ODSK-14 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-703-20610-00-00 OOOGURUK PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Ryan Rupert Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:56 pm, Sep 10, 2025 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2025.09.10 07:21:12 - 08'00' Sara Hannegan (2519) 325-551 MGR10SEP25 SFD 9/22/2025 * BOPE test to 2500 psi. 48 hour notice to AOGCC. * SSV and SSSV system performance test within 5 days of POP. 48 hour notice. 10-404 DSR-9/10/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.22 20:25:42 -08'00'09/22/25 RBDMS JSB 092625 ESP Swap HWO Well: ODSK-14 Well Name:ODSK-14 API Number:50-703-20610-00-00 Current Status:Offline ESP producer Permit to Drill Number:209-155 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Keith Lopez (907) 903-5432 (c) Regulatory Contact:Darci Horner (907) 777-8406 Max Expected BHP:2630psi at 6106’ TVDss (8.3ppg) 9/8/25 Static survey Max. Potential Surface Pressure: 2020 psi 0.1psi/ft to surface Brief Well Summary ODSK-14 is an offline Kuparuk producer. The well has a failed ESP, and is intermittently produced on Gas Lift, but frequently is uncompetitive on a TGOR basis. Returning the well to ESP production will improve drawdown and reduce the producing TGOR of the well. The well last passed a deep MIT of the 7” casing upon initial completion in 2010. The goal of this project is install a new ESP and return the well to fulltime production Pertinent wellbore information: - TRSSSV at 2150’ MD: functional - Deviation o 58 degree sail angle from 2900 -8600’ MD o Goes > 70 degrees at 9000’ MD o Max deviation above ADV: 79 degrees at 9939’ MD (ADV) - Min ID in tubing: 2.313”: Multiple X-profiles - Recent History o 9/8/25 SL drifts to ADV at 9939’ MD SL ran caliper and Static survey o June-2013: Last RWO. ESP and new 2-7/8’ tubing installed o 2010: Drill and complete. 7” casing and LTP pass an MIT to 3500psi ESP Swap HWO Well: ODSK-14 HWO Conditions x Traditional well control approach will be implemented x KWF will be a barrier at all times during HWO operations x No snubbing operations will be conducted x BOPE in attachment will be used. This stack is currently in service at Spy island as of September-2025 x TSI Rig #102 will be new to the slope and new to the state. The rig is not fully winterized. x Hilcorp will conduct HWO operations with TSI #102 NO later than 10/31/25 RWO Procedure 1. MIRU TSI Hydraulic Workover rig #102 2. Circulate / kill well: a. Work over fluid will be injection water (8.33ppg or heavier) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 58bbls d. IA to top slot = 313bbls 3. Set BPV/TWC, ND tree, NU BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH laying down 2-7/8” ESP completion 7. Perform Deep MIT of 7” casing a. May be performed with work string / test packer, or SL test plug. TBD b. Set plug at 10,200’ MD (or deeper) c. MIT of 7” casing to 2200psi 8. Pull test plug 9. Pickup and RIH with ESP / GL completion a. Plan to run a sand separator and ±250’ of mud joints below ESP b. Bottom ESP to be set at ±9,950’ MD c. Plan to reuse existing 2-7/8” tubing d. Equip well with Packer, SSSV, and Packer vent valve (PVV) all set below permafrost e. Well to be equipped for backup GL as well 10. Land ESP / GL completion 11. Drop Ball and rod and set packer 12. Set BPV/TWC, ND BOP 13. NU tree and test, pull BPV/TWC 14. RDMO TSI #102 30 minute charted and recorded pressure test. - mgr Lubricate BPV if any risk of trapped pressure. - mgr ESP Swap HWO Well: ODSK-14 Post RWO Procedure 1. MIRU SL 2. PT PCE to 250psi low / 2500psi high 3. Pull B&R and catcher sub 4. RDMO Operations 1. Return well to production 2. Within 5 days of stabilized production, test SSV and SSSV per state guidelines (give 48hr witness notification) 3. TIFL to prove integrity of Packer Vent Valve (PVV) a. Can be conducted with well online or offline. Thermally stable is most important b. Ensure IA FL is at 500’ MD or deeper. Depress with GL, if necessary c. Close in IA at surface d. Close PVV e. Shoot IA FL and note SI IAP f. Bleed IAP down at least 200psi below shut-in IAP g. Monitor IA pressures and fluid level every hour for at least 2 hours i. Shut in IAP would be expected to build, but PVV will prevent this ii. Should be no increase in FL beyond thermal expansion / degassing or foaming effects iii. Pass / fail criteria 1. IA fluid level should inflow no more than 500’ MD over the 2 hours, and show a stabilizing trend (decreasing height gain every hour) 2. Shut in IA pressure should increase no more than 100psi over the 2 hours and show a stabilizing trend (decreasing pressure gain every hour) 4. Open PVV, open IA at surface and return well to production Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOPE schematic (TSI) 4. Fluid Flow Diagram (TSI) 5. Rig stabilization Diagram (TSI) Oooguruk Field Last Completed: 6/21/2013 PTD: 209-155 API #: 50-703-20610-00-00 Casing 16” 16" A 3 4-1/2" B Size ID Top 16"N/A Surface 2 11-3/4" 10.772" Surface 9-5/8" 8.835" 3,401' C 7"6.276" Surface 4-1/2” 3.958" 10,232' D 11-3/4" 2-7/8" 2.441” Surface No Top MD TVD Inc ID A 2,150' 2,057' 32 2.313" B 3,101' 2,689' 58 2.359" C 3,221' 2,753' 57 2.313" D 3,422' 2,864' 56 8.835" 9-5/8"E 8,975' 5,837' 69 2.313" 1 F 9,939' 6,070' 79 NA G 9,943' 6,071' 79 NA E H 10,012' 6,085' 79 NA F G St. MD (ft) TVD (ft)Inc Valve Latch Port 3 3,034 2,654 58 Dummy ? NA 2 3,154 2,717 58 Dummy ? NA 1 8,912 5,813 68 Orifice ? 20 H I 7" 4-1/2" Liner Slotted from 10,251' MD (6,125' TVD) To 13 ,724' MD (6,162 TVD)88 degrees Inc at bottom Kuparuk Formation I 13,769' 109#, H-40 60#, L-80, Hyd 521 40#, L-80, HYD-521 12.6#, L-80, IBT-M 9-5/8" x 11-3/4" Liner Top Packer Intermediate 1 Surface Conductor Type 10-5/8" hole: cemented with 77 bls (372 sx) 15.8 ppg Class 'G'. Volumetric TOC estimate assuming 10% washout @ 6,820'MD.9-5/8" Wt/ Grade/ Conn CASING DETAIL Cement Details Hole MD 24" hole, driven, no cement 10,400' Tubing Production Liner CEMENT INFORMATION Btm 158 3,557' 7,853' 7,863' 158 14-1/2" Hole: Cemented with 375 bbls (495 sx) 10.9 ppg Permafrost 'L' followed by 55 bbls (260 sx) 15.8 ppg Premium 'G' tail. Cement returned to surface. 11-3/4"3,566' 7"8-1/2" hole: cemented with 20 bbls (95 sx) 15.8 ppg lead Class 'G'. Full returns throughout. Volumetric TOC assuming 10% washout estimate @ 9,600' MD. Intermediate 2 DateGLM Type ESP Pump Assembly, Discharge gauge End of ESP Assembly, Centralizer, Intake Gauge Gas Lift Mandrels 2-7/8" x 1-1/2" 5" x 7" WFT "NTH" Liner Top Packer w/ WFT PBR & 10' 5-1/4" ID TieBack Sleeve3.958"826,124'10,243' Mar 2010 Jun 2013 Drilled & Completed ESP Swap ? 6/24/2013 ? 6/21/2013 Rig Event Well History Date CompleteEvent ? 7/31/2015 ODSK-14 Schematic Kuparuk Producer Auto Diverter Valve 6-1/8" hole, uncemented slotted liner 13,852 JEWELRY DETAIL HES "X" Nipple HES "X" Nipple 26#, L-80, BTC-M 10,394' Item 'NE' TRSV w/2.313 "X" Profile, Control line to surface 7" x 2-7/8" WFT Hydrow-II Packer, with Packer Vent Valve 9,939'6.4#, L-80,IBT-M TUBING DETAIL 00070 degree inclination @ 9,026' MD / 5,854' TVD SSSV X X ODSK-14 Schematic 8-26-2025 Last edited by: DH 8/26/2025 ODSK-14 Proposed Schematic Oooguruk Field Last Completed: 6/21/2013 PTD: 209-155 API #: 50-703-20610-00-00 Casing 16” 16" A 3 4-1/2" B Size ID Top 16"N/A Surface 2 11-3/4" 10.772" Surface 9-5/8" 8.835" 3,401' C 7"6.276" Surface 4-1/2” 3.958" 10,232' D 11-3/4"3-1/2" 2.992" Surface 2-7/8" 2.441” 15' 4-1/2" 3.958" 10000' No Top MD TVD Inc ID 9-5/8"A 2,200' 2,100' 34 2.313" B 2,475' 2,312' 44 2.441" 1 C 2,575' 2,380' 48 2.313" D 3,422' 2,864' 56 8.835" E E 9,800' 6,043' 78 2.313" F F 9,850' 6,053' 78 NA G 9,960' 6,074' 79 NA H 9,975' 6,077' 79 TBD I 10,000' 6,082' 79 TBD G H St. MD (ft) TVD (ft)Inc Valve Latch Port 3 2,400 2,257 42 Shear TBD NA I 2 2,525 2,347 47 Dummy TBD NA 1 9,350 5,946 77 Orifice TBD 20 J 7" 4-1/2" Liner Slotted from 10,251' MD (6,125' TVD) To 13 ,724' MD (6,162 TVD)88 degrees Inc at bottom Kuparuk Formation J 13,769' 109#, H-40 60#, L-80, Hyd 521 40#, L-80, HYD-521 12.6#, L-80, IBT-M 9-5/8" x 11-3/4" Liner Top Packer Tubing 6.5#, L-80 9,850' Mud Joints 12.6#, L-80 10,200' XO to 4-1/2" mud joints, bottom at 10,200' Intermediate 1 Surface Conductor Type 10-5/8" hole: cemented with 77 bls (372 sx) 15.8 ppg Class 'G'. Volumetric TOC estimate assuming 10% washout @ 6,820'MD.9-5/8" Wt/ Grade/ Conn CASING DETAIL Cement Details Hole MD 24" hole, driven, no cement 10,400' Tubing Production Liner CEMENT INFORMATION Btm 158 3,557' 7,853' 7,863' 158 14-1/2" Hole: Cemented with 375 bbls (495 sx) 10.9 ppg Permafrost 'L' followed by 55 bbls (260 sx) 15.8 ppg Premium 'G' tail. Cement returned to surface. 11-3/4"3,566' 7"8-1/2" hole: cemented with 20 bbls (95 sx) 15.8 ppg lead Class 'G'. Full returns throughout. Volumetric TOC assuming 10% washout estimate @ 9,600' MD. Intermediate 2 DateGLM Type Bottom of ESP Assembly, Centralizer 4" Sand Separator Gas Lift Mandrels 2-7/8" x 1-1/2" 5" x 7" WFT "NTH" Liner Top Packer w/ WFT PBR & 10' 5-1/4" ID TieBack Sleeve3.958"826,124'10,243' Mar 2010 Jun 2013 Drilled & Completed ESP Swap TBD TBD TBD TBD Rig Event Well History Date CompleteEvent TBD TBD Kuparuk Producer ESP Pump Assembly: Discharge Gauge, with 5-1/2" Shroud 6-1/8" hole, uncemented slotted liner 13,852 JEWELRY DETAIL HES "X" Nipple HES "XN" Nipple 26#, L-80, BTC-M 10,394' Item TRSSSV w/2.313 "X" Profile, Control line to surface 7" x 2-7/8" Retrievable Packer, with Packer Vent Valve 15'9.3#, L-80 TUBING DETAIL 00070 degree inclination @ 9,026' MD / 5,854' TVD SSSV X X ODSK-14 Proposed Schematic 8-26-2025 Last edited by: DH 9/9/2025 TEAM SNUBBINGINTERNATIONALSP-12BOP Stack Drawing54.13"33.8"33.8"24.0"13 5/8"00 PSI Annular5000 PSI Single Ga e VBR:2 7/8" - 5 1/2"5000 PSI Single Ga eBlinds5000 PSI Flow Cross5000 PSI Riser5013 5/8" 13 5/8" 13 5/8" 13 5/8" /D E^/KE^ΘdK> ZE ^ϭΣ&Zd/KE>E'h>ZϬ͘ϬϬ͘ϬϬϬ͘ϬϬϬцϬ͘ϬϯϬϬ͘ϬϭϱϬ͘ϬϬϱццццϭͬϭϲцϬ͘ϬϬϬϬ Ϭ͘ϬϬϭ(1(5*<6(59,&(6,&21ϬΗ'ZKhE> s >ϭϲ͘ϬϬĨƚϭϵϮΗϲϳ͘ϱϭĨƚϴϭϬΗtKZ<&>KKZZϱϰΖ'hz'hz'hz'hz'hz 'hz&'hz''hz,>K<^>K<^ D>DW^ D>DW^EKd ͗Z & ZdKK D^W ^&KZ'hz'/EWK> 'hzZ Yh/Z D Ed^ϯϵΣϱϬΣDy^ d/KEͲEKd ͗E,KZ>K<^Dh^d W> KE^K>/'ZKhEt/d,E,KZ> d^ D /E^K/>͘Z KDD E D/E/DhDE,KZt /',dϭϴ͕ϬϬϬ>EKd ͗>/E >K^^^hD ^dZhdhZ /^&h>>z E>K^ &KZt/E>K/E''hzt/Z ^W ^ yW d >Kd E^/KEϵ͕ϬϬϬ>^ KEϭ͕ϬϬϬ>WZ Ͳd E^/KE͘ϯͬϰ/tZ /W^ϲyϭϵt/Z ZKW 'hzϴϱ&d'hzϴϱ&d'hzϴϱ&d'hzϴϱ&d'hz ϲϱ&d'hz&ϲϱ&d'hz'ϲϱ&d'hz,ϲϱ&dZ s͗$5&+&' E Z>EKd ^͗ϭ͘h͘E͘K͘>>&/>> dt >^dK ϭͬϰΗKEd/EhKh^͘Ϯ͘h͘E͘K͘>>hddt >^dK ϭͬϰΗKEd/EhKh^͘ϯ͘^ >t >>>dh/E'͘ϰ͘^d/<E&>hyͲKZ t >/E'WZK hZ ^Z /Ed Z,E'> KEE Yh/s> Ed^/^͘ϱ͘KEKd^> Zt/E'͘ϲ͘/&/EKhd^<͘Z/'ηZtE͗d ͗DW/Z h^dKD Z͗&/> ͗d/d> ͗d D^Eh/E'^, dd/d> ͗' E Z>^^zd^ϭϬϭt'η͗ϱϬϮϯϵ͘ϵ>td͗ Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' New Plugback Esets 6/26/2024 Well Name API Number PTD Number ESet Number Date 2L-320 PB1 50-103-20627-70-00 210-166 T39025 3-8-2011 2L-320 PB2 50-103-20627-71-00 210-166 T39026 3-8-2011 CD4-23 PB1 50-103-20621-70-00 210-067 T39027 8-30-2010 CD4-23 PB2 50-103-20621-71-00 210-067 T39028 8-30-2010 ODSK-13 PB1 50-703-20607-70-00 209-146 T39029 11-18-2011 ODSK-13 PB2 50-703-20607-71-00 209-146 T39030 11-18-2011 ODSK-14 PB1 50-703-20610-70-00 209-155 T39031 3-24-2010 ODSK-14 PB2 50-703-20610-71-00 209-155 T39032 3-24-2010 OP05-06 PB1 50-029-23427-70-00 210-080 T39033 10-28-2010 OP05-06 PB2 50-029-23427-71-00 210-080 T39034 10-28-2010 P2-22A PB1 50-029-22850-71-00 209-161 T39035 6-4-2010 P2-22A PB2 50-029-22850-72-00 209-161 T39036 6-4-2010 S-129 PB1 50-029-23433-70-00 210-132 T39037 5-12-2011 S-129 PB2 50-029-23433-71-00 210-132 T39038 5-12-2011 W-219 PB1 50-029-23429-70-00 210-105 T39039 1-27-2011 W-219 PB2 50-029-23429-71-00 210-105 T39040 1-27-2011 W-220 PB1 50-029-23432-70-00 210-126 T39041 3-27-2013 W-220 PB2 50-029-23432-71-00 210-126 T39042 3-27-2013 ODSK-14 PB1 50-703-20610-70-00 209-155 T39031 3-24-2010 ODSK-14 PB2 50-703-20610-71-00 209-155 T39032 3-24-2010 IP 1 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. ,G/ - L as- Well History File Identifier Organizing (done) ❑ Two -sided II 11 11111 IIIII ❑ Rescan Needed III I11111 III I RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: gy p. r�eyscale Items: ❑ Other, No/Type: Other Items Scannable by I� a Large Scanner 11 ❑ Poor Quality Originals: Lv O 9s OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: /3 /s/ gP _IMP Project Proofing 1 I 1111 yyj p BY: Maria Date: ,g, / /3 /s/ Scanning Preparation x 30 = / 4 30 + / d = TOTAL PAGES 1 ? (Count does not include cover sheet) n� BY: (� Mari Date: a 7/1,3 /s/ FFF�F��F Production Scanning I Stage 1 Page Count from Scanned File: 1 6 11 (Count does include co sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: l t 3 /s/ j/14F 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. 1111111111H 1111 ReScanned 1111E111 OM BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc �PV OF i 7,4_ s THE STATE Alaska. *' r9 , : „. I / „/ ,,, ss �E 011 and Gas �,`"_ °f � � S� Conservation Commission t GOVERNOR SEAN PARNELL 333 West Seventh Avenue r,� OF Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alex Vaughan , s( AM Sr. Drilling Engineer �� Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -14 Sundry Number: 313 -283 Dear Mr. Vaughan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0/ 4--- Daniel T. Seamount, Jr. Commissioner DATED this v day of June, 2013. Encl. astt£ C.wd r SBr° u t... STATE OF ALASKA 1y 4 %, .1 4 ' , . '" /AKA OIL AND GAS CONSERVATION COMO `r1 ° ,r APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 1, ,/4 ,, , i 1. Type of Request: Abandon 01 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Progra Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing © Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ • Other. ESP Change -out 5 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Pioneer Natural Resources Alaska, Inc. Exploratory ❑ Development Q 0 209 -155• 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99501 50- 703 - 20610-00-00. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSK -14• Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 355036 Oooguruk - Kuparuk Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,852'+ 6166'. 13,767' b 6164', N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 3518' 11 -3/4" 3557' 2938' 5830 psi 3180 psi Intermediate 1 4452' 9 -5/8" 3401' - 7853' 2852' - 5284' 5750 psi 3090 psi Intermediate 2 10,356' 7" 10,394' 6139' 7240 psi 5410 psi Liner 3537' 4 -1/2" 10,232' - 13,769' 6122' - 6164' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 See Attachment, pg. 2 3 -1/2 ", 9.3# L -80, TSHP/TCII 9921' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): TRMAXX SSSV; Hyd II Retry Pkr; Liner Top Pkr 2022' MD/1948' TVD; 4839' MD/3637' TVD; 10,243' MD/6124' TVD 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/10/2013 Oil 0 6 Gas WDSPL ❑ ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan, 343 -2186 Email alex.vauohan(oxd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer Prepared By: Kathy Campoamor, 343 - 2183 Signature Phone Date 343 -2186 6/4/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _ ys c C 2S2, I--. ?D s X 2S rsk: An1'` r j e'1 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 " L/ L APPROVED BY // / Approved by: COMMISSIONER THE COMMISSION Date /��f A__ Submit Form and Form 10 (Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate G -(0'13 RBDMS JUN 1120 , 7 ORIGINAL • • 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 June 5 , 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 , Anchorage, AK 99501 RE: ODSK -14 Sundry Application for ESP Change -Out REF: Permit To Drill # 209 -155 Pioneer Natural Resources, Alaska (PNRA) hereby submits an Application For Sundry request to pull the existing failed ESP on ODSK -14 and replace with a new ESP. See the proposed plan attachments and supporting documentation. Sincerely, - Gaughan Senior Drilling Engineer Attachments: Form 10 -403 Supporting information cc: ODSK -14 Well File • Pioneer etural Resources Alaska Inc. ODSK -14 Page 2 AOGCC Form 10 -403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment Open to production or injection 4 -W, 12.6 #, L -80 IBT -M Slotted Liner: MD TVD 10,251' — 11,206' 6125' — 6149' 11,498' — 12,615' 6145' — 6140' 13,224' — 13,766' 6149' — 6164' • 1 ODSK -14 Production Well Completion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 0 Vent Valves Control Line 16" Conductor 158' MDrkb / 158' TVDrkb P __:_ -, ...., Casing Item # Item MD (ft) TVD (ft) 3 - 1/2 ", 9.3# L 80 A 16" Conductor 158 158 TCII or 9.3# L - B 11 -3/4" 60# L -80 Hydril 511, 10.772" ID 3557 2938 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID 7853 5284 D 7" 26# L -80 BTC -M 6.276" ID 10394 6142 9.625" x 11.750" WFRD E 4-1/2" 12.6# L -80 Hydril 521 (Slotted Liner) 13769 6164 Liner hanger /packer w/ TBS F 3 -1/2" 9.3# L -80 TSHP & TCII 9921 6067 @ 3422' MDrkb / 3222' � G 2 -7/8" 6.5# L80 IBT -M TVDrkb \�J "Estimated 9 -5/8" TOC @ 6870' MD J "Estimated 7" TOC @ 9895' MD Hyd 521, 10.772" ID 4 Upper Completion 11 -3/4 ", 60# L -80 H Y IN � Item # MDrkb (1t) TVDrkb (ft) 3557' MDrkb / 2938' TVDrkb $ � r 1 , 1 VetcoGray Tubing Hanger w/ xo\.er to 2 -7/8" 34 34 SLB 2 -7/8 TRMA)0F5E, 4.609" OD, 2.312" X Profile, i� 13Cr -80 bore w/ 2 -7/8" EUE8RD pin x pin w/ Mod Estimated Top of Cement @ r 2 Collar L-80 w/ 1/4" x .049" SS control line 2,022 1,948 6870' MD, 500' MD above Top Vanoil GLM 2 -7/8" x 1 -1/2" F0-2 w/ 1 -1/2" Dummy w/ Torok 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts ©J 3 above top Xnipple) 4,672 3,544 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 4 Mod Collar (min. 2 jts above Gas Vent Valve Packer) 4,754 3,590 WFT7" x 2 -7/8" Hydrow -II Retry. Pkrf/ Feed Thru ESP 5 (max. TVD 3800') 4,839 3,637 Vanoil GLM 2 -7/8" x 1 -1/2" F0-2 w/ 1 -1/2" Dummy w/ ■ © ■ 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts 9 - 5/8 ", 40# L - 80 Hydril 521, 8.835" ID 6 above X nipple) 8,782 5,761 7853' MDrkb / 5284' TVDrkb O gDO HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 9 Mod Collar w/ RHC -M plug installed (65 deg inc.) 8,867 5,795 10 Automatic Divert Valve (ADV) 9,816 6,046 ESP (Pump P23, Motor, and Jewelry) (9746 -9935 11 MD <1 °DLS) 9,825 6,048 O End of Assembly 9,921 6,067 Estimated Top of Cement @ 9895' MD, Lower Completion 500' MD above 7" shoe NM Callii&—:„.--1.) ` MO O TVD (IQ I WFT PBR Tie Back Sleeve 158 10,232 6,122 WFT "NTH" Liner Top Pkr (7" 23 -32# X5" 15 #) 10,243 6,124 WFT "PHR" Rotating Hyd Set Liner Hanger (7" 23 -32# X 5" 15 #) 10,245 6,124 4-1/2" 12.6# L -80 IBT -Mod Slotted Liner and blank pipe 10,250 6,125 Liner Shoe 13,767 6,164 0 End of Assembly 13,769 6,164 7 ", 26# L -80 BTC -M, 6.276" ID 10,394' MDrkb / 6139' TVDrkb 13,852' MDrkb / 6166' TVDrkb Date: Revision By: Comments P10 N E E R 10/14/2009 jdf Proposed Completions RESOURCES h I^ 2/25/2010 jad Lateral extension edit ODSK -14 Producer hTURRI RESOURCESAIAS� 2/26/2010 vtj Added completion detail Well Schematic 3/26/2010 jad Final schematic Workovegebjectives and Planning ipquirements Well Name: ODSK -14 I I Date: 30- May -13 Location: 1 Oooguruk Drill Site II Confidential (YIN) 1 No I Workover Type 1 RWO I I Exploratory or Development: 1 Development Well Classification: 1 Producer 11 Proposed Start Date: 1 11- Jun -13 AFE Days I 10 I I AFE Total I $3.06MM Team Members Engineer Contact Info Well Engineer Alex Vaughan Name Alex Vaughan Well Work Phone Office 907 -343 -2186 Completion Tim Crumrine Phone Cell 907- 748 -5478 Production Theresa Williams Email alex.vaughan( oxd.com DrIg Super Rob Tirpack DrIg Manager Vern Johnson Reason for Workover: ESP Installation 1. Ensure safety of all personnel involved in Pre -Riq, Riq, and Post Riq Operations. Priorities: 2. Protect environment from all spills /damage related to well operations. 3. Coordinate with Ops to return well to service within limitations of Conoco SD & Riq Schedule 1. Replace ESP 2. Minimize fluid loss, Primary RWO: Conoco Seawater w/ 50ppm SI and 0.025% No Blok C max Objectives: 3. Install OV GLV 200' TVD above ADV 4. Flowback through Pioneer test header into flowback tanks following ESP install 1. Well Control Hazards and Concerns 2. Delivery of equipment and tools necessary to perform operation 3. Excessive fluid loss 4. Slickline and jewlery optionality based on POP timing / The maximum anticipated surface pressure a Sind gas from surface to 7" shoe ✓ at 10,394' MD / 6,139' TVD is estima at 1,878 psi with a .11 psi /ft gas gradient MASP Reservoir Pressure Estimated BHP after 30 days of shut -in is 2515 psi at 6050 tvdss or 8 ppge Punch tubing below ESP packer, ODSK -35A to be shut in during ODSK -14 RWO Pre-Rig Operations: Bullhead IA and tubing with diesel, Lubricate and bleed accumulated IA gas. Well will be shut in with closed TRSV, BPV, & tubing hanger pack -off 1. AOGCC Application for Sundry Approval (10 -403) 2.ODSDW01 -44 Class 1 / Class 2 disposal well approved for disposal Permitting and /or Policy Requirements: 3. Pioneer pre -rig checklist 4. Pioneer well handover form Reservoir Engineering Manager Approval Drilling Manager Approval Operations Manager Approval ! 1 ODSK -14 ESP Replacement RWO Planned Well Head: 9 - 5/8 ", 5K, VetcoGray 16" Conductor 158 158.00 Well: ODSK -14 Baker Hughes Tree: 3 - 1/2 ", 5K, Horizontal 11 -3/4" 60# L -80 Hydril 511, 10.772" ID 3557 2938.00 Set Depth: 9,990 9-5/8" 401 L -80 Hydril 521, 8.835" ID 7853 5283.00 Job Completion Date: Weatherford AI blen 7" 26# L -80 BTC -M 6.276" ID 10394 6139.00 Vetco Gray 4 -1/2" 12.6# L-80 Hydril 521 13769 6163.00 Confirm Length Tool Description Joint Tool/Joint Cum m. Final Depth Number Length Length Top of Tool Inc ( °) TVD (uSft) DLS ( °/100 RKB 34.09 10,002.88 -12.88 Vetco Gray Tubing Hanger 1.54 9,968.79 21.21 3.5" 9.2# L -80 Pup Joint ii 7.36 9,967.25 22.75 Crosso .. ^5- ='"` -' 0.92 9,959.89 30.11 2.875" 6.5# L-80 IBT -M Joint 67 31.00 9,958.97 31.03 12.00 7,881.97 2,108.04 31.62 2021.6 1.21 6.70 7,869.97 2,120.04 31.49 2031.8 1.21 12.00 7,863.27 2,126.74 31.41 2037.6 1.21 2.875" 6.5# L -80 IBT -M Joint 10 31.00 7,851.27 2,138.74 31.27 2047.8 1.21 6.08 12.00 7,541.27 2,448.74 43.91 2292.9 - 8.67 7,529.27 2,460.74 44.63 2301.5 6.08 .75" 6.5# L-80 IBT -M Pu• 12.00 7,520.60 2,469.41 45.15 2307.6 6.08 2.875" 6.54 L -80 IBT -M Joint 1 31.00 7,508.60 2,481.41 45.73 2316 2.67 ■ ■ X mer coupling and pup joint 14.27 7,477.60 2,512.41 46.48 2337.5 2.67 WFT Hyrow II Packer 4.86 7,463.33 2,526.68 46.83 2347.3 3.96 Xovercoupling and pup joint 4.45 7,458.47 2,531.54 46.96 2350.6 3.96 2.875" 6.5# L -80 IBT -M Joint 1 31.00 7,454.02 2,535.99 47.08 2353.7 3.96 12.00 7,423.02 2,566.99 47.92 2374.6 3.96 u 8.65 7,411.02 2,578.99 48.12 2382.6 1.39 12.00 7,402.37 2,587.64 48.22 2388.4 1.39 2.875" 6.5# L -80 IBT -M Joint 1 31.00 7,390.37 2,599.64 48.36 2396.4 1.39 12.00 7,359.37 2,630.64 48.89 2416.9 3.45 1.50 7,347.37 2,642.64 49.30 2424.8 3.45 12.00 7,345.87 2,644.14 49.35 2425.7 3.45 2.875" 6.5# L-80 IBT -M Joint 201 31.00 7,333.87 2,656.14 49.77 2433.5 3.45 J 12.00 1,102.87 8,887.14 67.28 5803.1 3.33 8.65 1,090.87 8,899.14 67.50 5807.8 3.79 12.00 1,082.22 8,907.79 67.66 5811.1 3.79 2.875" 6.5# L-80 IBT -M Joint 1 31.00 1,070.22 8,919.79 67.88 5815.6 3.79 0 0 0 12.00 1,039.22 8,950.79 68.46 5827.1 3.79 1.50 1,027.22 8,962.79 68.69 5831.5 3.79 12.00 1,025.72 8,964.29 68.72 5832.1 3.79 2.875" 6.5# L -80 IBT -M Joint 30 31.00 1,013.72 8,976.29 68.94 5836.4 3.79 2 -7/8" EUE x IBT -M Handling Pup 10.00 83.72 9,906.29 78.64 6063.9 0.52 Auto Diaerter Vale 3.35 73.72 9,916.29 78.69 6065.9 0.52 2 -7/8" EUE Handling Pup 2.00 70.37 9,919.64 78.71 6066.5 0.52 Discharge Gauge 2.63 68.37 9,921.64 78.71 6066.9 0.52 2 -7/8" EUE Handling Pup 2.00 65.74 9,924.26 78.73 6067.4 0.52 Bolt on Discharge Head 0.62 63.74 9,926.26 78.74 6067.8 0.52 Pump 23.00 63.12 9,926.88 78.74 6067.9 0.52 Adapter Kit 0.14 40.12 9,949.88 78.77 6072.4 0.23 Gas Separator 5.47 39.98 9,950.02 78.77 6072.5 0.23 Upper Tandem Seal 6.90 34.51 9,955.49 78.76 6073.5 0.23 I:1 Lower Tandem Seal 6.90 27.61 9,962.39 78.76 6074.9 0.23 Motor 16.80 20.71 9,969.29 78.75 6076.2 0.23 Motor Gauge 1.91 3.91 9,986.09 78.74 6079.5 0.23 Baker 5.85" OD Centralizer 2.00 2.00 9,990.00 78.73 6080.3 0.23 •0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Date: Revision By: Comments P I 0 N E E I 5/27/2013 Alex Vaughan ESP Replacement Original Design ODSK -14 Producer NAIURAI. RESOURCES AASM Well Schematic ESP Completion • • PIONEER NATURAL RESOURCES ODSK -14 RWO Program Replace Failed ESP Completion Current Completion: 2 -7/8" ESP String at 9,921' MD / 6,067' TVD Planned Completion: 2 -7/8" ESP String at 9,990' MD / 6,080' TVD AFE# TBA, API # 50- 703 - 20610 -00 -00 AOGCC PTD # 209 -155 Prepared: Date: Alex Vaughan: Operations Drilling Engineer Reviewed: Date: Tim Crumrine: Sr. Staff Completions Engineer Reviewed: Date: Rob Tirpack: Drilling Superintendent Reviewed: Date: Gary Ross: Operations Superintendent Approved: Date: Vern Johnson: Alaska Drilling Manager ODSK -14 ESP Replacement RWO Program Version 1 1 June 5 2013 • • Pre -Rig Slickline: (Work completed with approved sundry# TBA) 1. Punch 2 -7/8" tubing in the first full joint directly below the ESP packer a. (Sundry submitted 6/4/2013 to execute the preceding tubing punch) 2. Open the PVV and bullhead into the 2 -7/8" x 7" annulus through the PVV: 160 bbls seawater followed by 60 bbl diesel. Close the PVV 3. Bullhead down the 2 -7/8" tubing: 12 bbl diesel a. All fluids injected into the well should be built with the following properties: i. Conoco Seawater filtered to sub 20 NTU's ii. 50 ppm scale inhibiter iii. 0.025% NoBlok C 4. Lubricate and bled out gas that migrates to surface in the 2 -7/8" x 7" annulus. 5. Pressure test 2 -7/8" x 7" annulus to 3,500 psi for 15 min 6. Close the TRSV and preform drawdown pressure test 7. Pressure test tubing hanger pack -off void in well head to 5,000 psi. 8. Set a BPV in the tubing hanger 9. Suspended ODSK -14 with the following well control barriers: a. Tubing: i. Closed TRSV tested via drawdown test ii. BPV b. 2 -7/8" x 7" Annulus: i. Tested 2 -7/8" x 7" ESP Packer (Closed PVV) ii. Tested Tubing hanger packoff Pre -Rig Regulatory: 1. Provide 48 hour notice for the testing of the BOPE. 2. AOGCC mandates 1 week BOPE testing periods during RWO's. 3. Post ODSK -14 Approved Sundry # TBA (see program attachments). 4. Read Approved Sundry and ensure that operations are in accordance. Rig Activity: Kill ODSK -14 1. Hold pre -job meeting a. Confirm Pre -Rig Workover Checklist has been filled out, reviewed, signed, and received from Operations b. Ensure proper handover of well from Operations c. Ensure adequate Conoco Seawater, scale inhibitor, and BLOK C product is on location ODSK -14 ESP Replacement RWO Program Version 1 2 June 5 2013 • • d. Discuss potential well control issues and ensure they are appropriately communicated to rig crew. 2. MIRU Nabors 19AC over ODSK -14 3. Lubricate and bleed the 2 -7/8" x 7" IA as required 4. Install test dart (blanking plug) 5. ND production tree with the following well control barriers in place a. Tubing: i. Closed TRSV tested via drawdown test ii. BPV w/ Test Dart b. 2 -7/8" x 7" Annulus: i. Tested 2 -7/8" x 7" ESP Packer (Closed PW) ii. Tested Tubing hanger packoff 6. NU BOPE & Test 250 psi low / 4500 psi high according to the test pressures outlined in the AOGCC Permit to Drill. a. Notify the AOGCC Field Representative 48 hours prior to the BOPE Test. 7. Retrieve the test dart and BPV 8. Open TRSV ✓ 9. Bullhead 150% 2 -7/8" tubing volume -86 bbls of Conoco seawater a. All fluids injected into the well should be built with the following properties: i. Conoco Seawater filtered to sub 20 NTU's ii. 50 ppm scale inhibiter iii. 0.025% NoBlok C 10. Monitor well for 30 min and ensure well is dead or on vacuum. Lubricate and bleed the IA as required. 11. Close the TRSV Rig Activity: POOH with 2 -7/8" ESP Completion 1. Hold pre job meeting a. Baker Fishing Hand should be on location one day prior to releasing ESP packer. b. Ensure contingency fishing equipment is inventoried and accessible. (See RWO SID). c. Drift FOSV. 2. Prep rig floor to pull 2 -7/8" ESP completion. a. Ensure FOSV is accessible and in the open position. b. Ensure ESP cable cutter is operational and accessible. c. RU HAL control line spooler. d. Identify a person to count and maintain Cannon Clamps. Note on tally location of each Cannon Clamp recovered. e. Inspect 2 -7/8" tubing for scale or corrosion and report on WellView. f. Review NORM monitoring plan with HSE. ODSK -14 ESP Replacement RWO Program Version 1 3 June 5 2013 • • 3. BOLDS, Open the TRSV, and unseat 2 -7/8" tubing hanger 4. Release 2 -7/8" x 7" ESP packer with a straight pull (See RWO SID). a. Anticipated PU String Hook Weight - Above Packer: 79,000 lbs b. Packer Shear Release: 33,000 lbs c. Anticipated Surface Overpull for Packer Shear Release: 62,000 lbs d. Anticipated Hook weight for Shear Release: 141,000 lbs e. Anticipated Hook Weight - Full String after packer release: 138,000 lbs f. Stretch: 1.6 ft g. 80% Tensile Limit: 165,000 lbs (See RWO SID) i. 165,000 lbs includes top drive and block weight ii. Contact Rig Superintendent if more than 80% is required 5. Stroke ESP packer to allow elements to relax. 6. Close annular and bullhead 150% 2 -7/8" x 7" annulus volume -450 bbls of Conoco seawater 7. Monitor well for 30 min and ensure well is dead or on vacuum. 8. POOH and LD 2 -7/8" ESP completion string as per Oooguruk specific Centrilift 2 -7/8" ESP completion string pulling procedure. (See RWO SID) a. Rack back 2,700' of 2 -7/8" tubing in good condition to be used as a work string. b. Maintain pressure on TRSV to keep it open until it is recovered. c. Clean all completion equipment at the rig floor with water and WD40. d. Fill hole with 150% tubing displacement plus 10 bbl of Conoco seawater every hour. e. If influx is observed stab FOSV, space out, close annular and bullhead 1.5 tubing volume to 7" shoe at 6 bpm. Shut down and monitor well for 30 min. If well continues to flow continue to bullhead and contact Rig Superintendent to discuss increasing fluid weight. Once well is confirmed dead continue POOH. f. If junk is left in hole contact Rig Superintendent and discuss fishing options. 9. Close blind rams, Clean rig floor and prep to run ESP completion. a. Continue filling hole with 10 bbl of Conoco seawater every hour. Riq Activity: Scraper Cleanout Run IV 1. RIH with scraper, magnet, and mule shoe 100' MD below ESP packer setting depth on 2 -7/8" tubing in good condition and POOH a. Do not rotate b. During RIH fill hole with 10 bbl of Conoco seawater every hour. c. During POOH fill hole with 150% tubing displacement plus 10 bbl of Conoco seawater every hour Riq Activity: RIH with 2 -7/8" ESP Completion 1. Hold pre job meeting a. Weatherford is responsible for tally at rig site. The Tally is to include: • Tubing measurement by joint (composite tubing tally is not acceptable) ODSK -14 ESP Replacement RWO Program Version 1 4 June 5 2013 • • • Equipment type, Length, OD, ID, Drift & Fishing neck • Clamp or band location b. Tally is to be independently confirmed by Nabors or by designation of CoMan. c. Tally is to be emailed to Alex Vaughan once compiled for confirmation. 2. Confirm zero pressure below blind ram and open ram a. Continue to fill hole with 10 bbl of Conoco seawater every hour. 3. Conduct a pre job meeting to run 2 -7/8" ESP completion. a. Review Lessons Learned from previous ESP installations (See RWO SID). b. Review Centrilift ESP running procedure. (See RWO SID) c. Review Weatherford 2 -7/8" x 7" ESP packer running procedure. (See RWO SID) 4. Pick & RIH up 2 -7/8" ESP completion as per tally. a. Continue to fill hole with 10 bbl of Conoco seawater every hour. An outline of the completion equipment is as follows. This is intended to provide an understanding of the purpose of each piece of the equipment. It is provided as supplemental information along with the provided completion tally. Halliburton Tubing retrievable safety valve • Install at -2,000' TVD • Purpose: 2 -7/8" tubing ID well control safety device Halliburton Gas Lift Valve #1 • Install one joint above X- Nipple #1 • Run with 2,500 psi shear out valve installed • Purpose: Freeze protection of the 2 -7/8" x 7" annulus Weatherford Packer • Install at -2,500' MD • Primary Purpose: 2 -7/8" x 7" annulus well control safety device • Secondary Purpose: Allows pressure test of the 2 -7/8" x 7" annulus • Note: Weatherford packer has a 3800' TVD depth limitation and should be installed no deeper than 2500' MD and above KOP due to experienced difficulties with releasing packer. Halliburton Gas Lift Valve #2 • Install one joint below ESP Packer • Run with dummy GLV installed • Purpose: Allows accumulated gas below the ESP packer to be removed for future RWO's. Halliburton X- Nipple • Install one joint below GLM #2 • Primary Purpose: Primary pressure test location for the 2 -7/8" tubing ID. • Secondary Purpose: Allows installation of XX plug as a junk catcher for GLV swap on GLM # 2 Halliburton Gas Lift Valve #3 • Install 200' TVD above ADV so as to avoid gas overshooting GLM #3 and circulating through the ADV • Run with live ' /4' OV GLV installed • Purpose: Primary gas lift location as a backup to the ESP ODSK -14 ESP Replacement RWO Program Version 1 5 June 5 2013 • Halliburton X- Nipple • Install one joint below GLM #4 • Primary Purpose: Allows installation of XX plug as a junk catcher for GLV swap on GLM # 3 • Note: An XN- Nipple was not used as the ADV and ESP is below this GLM and is therefore not required. ESP • Install as deep as possible in a location of less than 2° DLS • Purpose: Enhanced fluid lift to surface Riq Activity: Land 2 -7/8" ESP Completion 1. With 3 -1/2" landing joint and FOSV, land tubing hanger while maintaining 4,500psi on control lines and 500 psi on the gas vent control line. Once landed, RILDS for Tubing Hanger. Test both the upper and lower Tubing Hanger body seals to 5000psi. 2. Hold pre job meeting a. Double check that the RHC plug was installed in the X- Nipple below GLM #2 b. Review freeze protection procedures c. Review packer setting procedures 3. Drop ball and rod and displace down to RHC body. a. Run ball and rod on slickline if fluid level of tubing is not at surface. 4. Fill tubing with Conoco seawater set Weatherford GW packer per Weatherford rep instructions a. Slowly increase pressure on the tubing to 3,500 psi (4,000 psi max) and hold for at least 15 minutes. b. Packer slips engage at 1,500 psi. 5. Pressure test the tubing and IA to 3 500 psi for 30 min 44 a. A DCR -1 shear out valve pinned to 2500 psi is installed in GLM #1 and requires that pressure testing operations are executed in the following order: • Pressure test the tubing to 3,500 psi for 30 min. • Bleed tubing pressure down to 2,500 psi • Pressure Test 2 -7/8" x 7" annulus to 3,500 psi for 30 min. • Bleed tubing pressure down to zero. This will result in shearing the shear -out valve • Pump fluid both directions through the shear -out valve to confirm communication. 6. Install BPV and blanking plug in tubing hanger. 7. Hold pre job meeting a. Review Lessons Learned from previous ESP installations (See RWO SID). b. Review Centrilift ESP running procedure as it pertains to the wellhead & tree. (See RWO SID). 8. ND BOP's. a. Ensure Vetco Gray personnel are present prior to lifting stack and recovering control lines so as to prevent kinking. b. Note: Centrilift tech to continue to monitor cable conductivity throughout process. ODSK -14 ESP Replacement RWO Program Version 1 6 June 5 2013 • • 9. Feed control lines thru tree adaptor body, install Vetco Gray Wellhead hydraulic fittings, install needle valve, test control lines 5000psi. Vetco Gray BIW penetrator prepped for THA installation. a. Monitor ESP communications during process. 10. NU Vetco Gray Production ESP X -mas Tree (Tubing Head Adaptor w/ ESP port, 3- 1/8 ",5k Vertical valve, & 5 -3/4" Otis Lubricator Adaptor) 11. Test Production X -mas Tree void to 5000psi and bleed off pressure. Test X -mas Tree internals through the 3" Prod Wing Assy. Test the 2" Gas Lift Wing Assembly against shop tested closed inner valve to 5000psi. Once tests are successfully completed, bleed pressure & recover BPV via lubricator. Secure well. 12. Hold post job meeting a. Ensure proper handover of well from Drilling to Operations. b. Confirm Well Handover Document has been filled out and received by Operations. c. Email copy of the signed Well Handover Document to Kathy Campoamor. 13. RDMO Nabors 19AC a. Centrilift to install ESP pigtail to top of BIW penetrator protruding through the Tubing Head Adaptor while monitoring ESP communications. b. Centrilift to supply CoMan, Alex Vaughan with a digital copy of Tally, Pressure tests, and Post job report prior to leaving location. Post Rig: Slickline 1. RU slickline on ODSK -14 2. Hold pre job meeting 3. RU lubricator and pull BPV & blanking plug 4. Hold open TRSV 5. Circulate diesel down 2 -7/8" x 7" annulus through shearout valve and up 2 -7/8" tubing to surface 6. Pull Shearout valve from GLM #1 and install Dummy 7. Pull Ball and Rod 8. Pull RHC 9. Function test TRSV 10. Start up ESP as per Centrilift Procedures ODSK -14 ESP Replacement RWO Program Version 1 7 June 5 2013 • 0 The following information can be found in the RWO Supplemental Information Document (RWO SID). 2 -7/8" Decompletion • As -built Visio schematic • As -built WellView schematic • 2 -7/8" ESP tubing tally • ESP Packer releasing model 2 -7/8" ESP Completion Information • Planned Completion • Centrilift ESP lesson learned (Oooguruk specific) General information • WOOPR • Directional surveys • Reservoir pressure model • Baker standby fishing tool list • Operations to Drilling handover form • Drilling to operation handover form ODSK -14 ESP Replacement RWO Program Version 1 8 June 5 2013 • • , PIONEER NATURAL RESOURCES General Information (12102012 1211:49 PM) 321 psi (1/11 /20132:01:00 PM) 1267 psi K -14 Wellhead Pressure Trend 546 psi (32 days. 01:29:11) ,303 • rvq, 2o■ 12/112012 12/91 12/17/2012 1226/2012 1/32013 111113 1:56:00 PM 6:45:00 PM 11:34:00 PM 4 :23:00 AM 9:12:00 AM 2:01:00 PM • IN.S))I ANC01 PI 20115R ICw.fic - 00 01:3206 8771 • • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -00 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Drilling Services III • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' (d) 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True 1 Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB 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 ODSK -14 - Slot ODS -14 Well Position +W 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / - 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSK - 14 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 1/7/2008 22.87 80.81 57,678 Design ODSK -14 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,726.00 Vertical Section: Depth From (TVD) +N/-$ +E/-W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 Survey Program Date 3/4/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1 Kup SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4,740.90 10,669.40 ODSK -14 PB2 MWD (ODSK -14 PB2 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1: 10,726.00 13,820.93 ODSK -14 MWD (ODSK -14) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 2/20/2010 1: Survey Map Map Vertical MD Inc Az! TVD TVDSS +Nl-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 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro-SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro-SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro-SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro-SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro-SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro-SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro-SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) 3/4/2010 3 :18 :37PM Page 2 COMPASS 2003.16 Build 42B • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (it) Survey Tool Name 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro-SS (1) 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro-SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro-SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro -SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro-SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag(2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sa9 (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 • 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +Sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD+IFR2+MS+sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +Sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3/4/2010 3:18:37PM Page 3 COMPASS 2003.16 Build 42B • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5 @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E1 -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag(2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag(2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,660.00 56.62 281.79 3,537.21 3,481.01 497.65 - 2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 4,740.95 55.40 279.20 3,582.47 3,526.27 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag(3) 4,836.40 54.98 280.65 3,637.02 3,580.82 523.93 - 2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 4,879.42 55.71 280.39 3,661.48 3,605.28 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 - 2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 - 2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 - 2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 - 2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 - 2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) 5,450.50 56.87 281.90 3,966.96 3,910.76 614.98 - 3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) 5,546.29 56.76 281.72 4,019.39 3,963.19 631.39 - 3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 5,641.35 56.95 279.09 4,071.38 4,015.18 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031 , 743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 3/4/2010 3:18:37PM Page 4 COMPASS 2003.16 Build 428 • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' t 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' Q 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E!-W Northing Ea s ting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 - 3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag (3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 - 3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 - 4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 - 4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) 6,878.72 56.92 279.21 4,758.80 4,702.60 803.14 - 4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) 6,974.00 57.33 278.74 4,810.52 4,754.32 815.62 - 4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 7,070.69 58.44 280.02 4,861.92 4,805.72 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) 7,164.65 57.01 278.08 4,912.10 4,855.90 841.48 - 4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) 7,259.49 56.57 276.96 4,964.04 4,907.84 851.87 - 4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 7,354.90 56.92 277.34 5,016.36 4,960.16 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) 7,451.12 57.52 279.93 5,068.46 5,012.26 873.95 - 4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) 7,545.34 57.71 279.62 5,118.93 5,062.73 887.46 - 4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 1 7,640.14 57.14 280.28 5,169.97 5,113.77 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 - 4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) 7,819.80 57.61 281.36 5,265.98 5,209.78 929.54 - 5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 7,892.32 58.60 282.43 5,304.29 5,248.09 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 - 5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032 , 114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032,154.95 464,244.87 2.51 5,576.60 MWD +IFR2 +MS +sag (3) 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032,242.53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032,318.39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032 , 362.71 463,771.84 2.61 6,093.25 MWD +IFR2 +MS +sag (3) 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD +IFR2 +MS +sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 3/4/2010 3:18:37PM Page 5 COMPASS 2003.16 Build 42B • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E! -W Northing Fasting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Nam 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD +IFR2 +MS +sag (3) 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6,032,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD +IFR2 +MS +sag (3) 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) 10,726.00 92.79 316.72 6,148.20 6,092.00 2,370.07 - 7,249.21 6,033,470.31 462,602.06 1.98 7,602.30 MWD +IFR2 +MS +sag (4) 10,766.12 90.31 317.66 6,147.12 6,090.92 2,399.48 - 7,276.47 6,033,499.83 462,574.93 6.61 7,638.79 MWD +IFR2 +MS +sag (4) 10,797.83 89.47 317.75 6,147.18 6,090.98 2,422.94 - 7,297.80 6,033,523.37 462,553.69 2.66 7,667.53 MWD +IFR2 +MS +sag (4) 10,830.72 88.97 316.86 6,147.63 6,091.43 2,447.11 - 7,320.11 6,033,547.63 462,531.49 3.10 7,697.43 MWD +IFR2 +MS +sag (4) 10,853.73 89.33 317.61 6,147.97 6,091.77 2,464.00 - 7,335.73 6,033,564.58 462,515.94 3.62 7,718.36 MWD +IFR2 +MS +sag (4) 10,895.73 91.42 319.05 6,147.69 6,091.49 2,495.37 - 7,363.65 6,033,596.06 462,488.15 6.04 7,756.22 MWD +IFR2 +MS +sag (4) 10,928.96 89.36 317.27 6,147.47 6,091.27 2,520.13 - 7,385.81 6,033,620.90 462,466.09 8.19 7,786.22 MWD +IFR2 +MS +sag (4) 10,958.52 88.95 316.64 6,147.90 6,091.70 2,541.73 - 7,405.99 6,033,642.58 462,446.00 2.54 7,813.17 MWD +IFR2 +MS +sag (4) 10,991.76 89.68 316.41 6,148.30 6,092.10 2,565.85 - 7,428.85 6,033,666.79 462,423.24 2.30 7,843.57 MWD +IFR2 +MS +sag (4) 11,024.17 91.03 318.21 6,148.10 6,091.90 2,589.67 - 7,450.83 6,033,690.70 462,401.36 6.94 7,873.04 MWD +IFR2 +MS +sag (4) 11,055.41 89.88 318.65 6,147.85 6,091.65 2,613.04 - 7,471.55 6,033,714.15 462,380.73 3.94 7,901.18 MWD +IFR2 +MS +sag (4) 11,088.59 89.44 320.28 6,148.05 6,091.85 2,638.25 - 7,493.12 6,033 , 739.45 462,359.27 5.09 7,930.80 MWD +IFR2 +MS +sag (4) 11,120.48 89.88 321.08 6,148.24 6,092.04 2,662.92 - 7,513.32 6,033,764.20 462,339.17 2.86 7,958.96 MWD +IFR2 +MS +sag (4) 11,151.77 89.91 321.48 6,148.30 6,092.10 2,687.33 - 7,532.90 6,033 , 788.69 462,319.70 1.28 7,986.44 MWD +IFR2 +MS +sag (4) 11,201.20 89.31 323.11 6,148.63 6,092.43 2,726.44 - 7,563.13 6,033,827.91 462,289.63 3.51 8,029.42 MWD +IFR2 +MS +sag (4) 11,248.49 89.27 323.35 6,149.22 6,093.02 2,764.32 - 7,591.43 6,033,865.90 462,261.48 0.51 8,070.15 MWD +IFR2 +MS +sag (4) 11,280.78 89.11 323.67 6,149.67 6,093.47 2,790.28 - 7,610.63 6,033,891.94 462,242.39 1.11 8,097.88 MWD +IFR2 +MS +sag (4) 11,308.60 89.89 324.83 6,149.92 6,093.72 2,812.85 - 7,626.88 6,033,914.58 462,226.23 5.02 8,121.59 MWD +IFR2 +MS +sag (4) 11,344.71 90.80 323.60 6,149.70 6,093.50 2,842.14 - 7,648.00 6,033,943.95 462,205.24 4.24 8,152.37 MWD +IFR2 +MS +sag (4) 11,376.32 91.90 323.30 6,148.96 6,092.76 2,867.53 - 7,666.82 6,033,969.41 462,186.52 3.61 8,179.53 MWD +IFR2 +MS +sag (4) 11,409.34 91.77 322.69 6,147.90 6,091.70 2,893.89 - 7,686.68 6,033,995.84 462,166.77 1.89 8,208.02 MWD +IFR2 +MS +sag (4) 11,441.10 92.04 323.43 6,146.84 6,090.64 2,919.26 - 7,705.76 6,034,021.29 462,147.80 2.48 8,235.41 MWD +IFR2 +MS +sag (4) 11,472.44 92.74 324.01 6,145.54 6,089.34 2,944.50 - 7,724.29 6,034,046.60 462,129.37 2.90 8,262.25 MWD +IFR2 +MS +sag (4) 11,506.38 90.48 322.43 6,144.58 6,088.38 2,971.67 - 7,744.60 6,034,073.85 462,109.17 8.12 8,291.47 MWD +IFR2 +MS +sag (4) 11,538.93 89.83 323.81 6,144.49 6,088.29 2,997.70 - 7,764.13 6,034,099.96 462,089.75 4.69 8,319.54 MWD +IFR2 +MS +sag (4) 11,570.08 90.54 322.31 6,144.39 6,088.19 3,022.60 - 7,782.85 6,034,124.93 462,071.13 5.33 8,346.42 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 6 COMPASS 2003.16 Build 42B • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wel!bore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (T) ( ?) (ft) (ft) (ft) (R) (ft) (ft) (11001 (ft) Survey Tool Name 11,602.99 90.88 324.84 6,143.99 6,087.79 3,049.08 - 7,802.39 6,034,151.49 462,051.70 7.76 8,374.66 MWD +IFR2 +MS +sag (4) 11,634.79 90.50 323.56 6,143.60 6,087.40 3,074.87 - 7,820.99 6,034,177.35 462,033.21 4.20 8,401.77 MWD +IFR2 +MS +sag (4) 11,666.24 90.70 323.06 6,143.27 6,087.07 3,100.08 - 7,839.78 6,034,202.64 462,014.52 1.71 8,428.84 MWD+IFR2+MS+sag (4) 11,699.18 89.89 321.58 6,143.10 6,086.90 3,126.15 - 7,859.91 6,034,228.79 461,994.50 5.12 8,457.47 MWD +IFR2 +MS +sag (4) 11,731.14 89.95 320.74 6,143.15 6,086.95 3,151.05 - 7,879.96 6,034,253.76 461,974.56 2.63 8,485.57 MWD +IFR2 +MS +sag (4) 11,764.74 89.85 319.25 6,143.21 6,087.01 3,176.78 - 7,901.56 6,034,279.58 461,953.06 4.44 8,515.42 MWD +IFR2 +MS +sag (4) 11,796.76 89.88 320.92 6,143.28 6,087.08 3,201.34 - 7,922.10 6,034,304.22 461,932.62 5.22 8,543.86 MWD +IFR2 +MS +sag (4) 11,828.02 90.05 319.08 6,143.30 6,087.10 3,225.29 - 7,942.19 6,034,328.24 461,912.63 5.91 8,571.63 MWD +IFR2 +MS +sag (4) 11,877.21 91.14 318.95 6,142.79 6,086.59 3,262.42 - 7,974.45 6,034,365.50 461,880.52 2.23 8,615.72 MWD +IFR2 +MS +sag (4) 11,923.73 92.03 320.54 6,141.50 6,085.30 3,297.90 - 8,004.50 6,034,401.11 461,850.62 3.92 8,657.14 MWD +IFR2 +MS +sag (4) 11,972.44 90.41 321.07 6,140.47 6,084.27 3,335.64 - 8,035.28 6,034,438.97 461,820.00 3.50 8,700.09 MWD +IFR2 +MS +sag (4) 12,020.17 89.77 321.45 6,140.39 6,084.19 3,372.87 - 8,065.14 6,034,476.31 461,790.29 1.56 8,742.01 MWD +IFR2 +MS +sag (4) 12,063.52 90.58 323.16 6,140.26 6,084.06 3,407.17 - 8,091.65 6,034 , 510.72 461,763.93 4.36 8,779.70 MWD +IFR2 +MS +sag (4) 12,117.29 89.77 322.38 6,140.10 6,083.90 3,449.98 - 8,124.18 6,034,553.66 461,731.57 2.09 8,826.24 MWD +IFR2 +MS +sag (4) 12,152.67 90.55 322.20 6,140.00 6,083.80 3,477.97 - 8,145.82 6,034,581.73 461,710.05 2.26 8,857.00 MWD +IFR2 +MS +sag (4) 12,212.57 89.38 321.03 6,140.03 6,083.83 3,524.93 - 8,183.01 6,034,628.83 461,673.05 2.76 8,909.43 MWD +IFR2 +MS +sag (4) 12,258.08 90.26 321.06 6,140.18 6,083.98 3,560.32 - 8,211.63 6,034,664.33 461,644.58 1.93 8,949.48 MWD +IFR2 +MS +sag (4) 12,308.31 89.22 320.19 6,140.40 6,084.20 3,599.14 - 8,243.49 6,034,703.28 461,612.88 2.70 8,993.86 MWD +IFR2 +MS +sag (4) 12,359.63 89.70 319.74 6,140.89 6,084.69 3,638.43 - 8,276.50 6,034,742.70 461,580.03 1.28 9,039.48 MWD +IFR2 +MS +sag (4) 12,407.33 89.52 318.40 6,141.21 6,085.01 3,674.47 - 8,307.75 6,034,778.86 461,548.93 2.83 9,082.21 MWD +IFR2 +MS +sag (4) 12,455.47 89.34 318.54 6,141.69 6,085.49 3,710.51 - 8,339.67 6,034,815.02 461,517.17 0.47 9,125.56 MWD+IFR2+MS+sag (4) 12,501.85 90.69 318.84 6,141.68 6,085.48 3,745.34 - 8,370.28 6,034,849.98 461,486.70 2.98 9,167.25 MWD +IFR2 +MS +sag (4) 12,549.95 89.74 317.06 6,141.50 6,085.30 3,781.06 - 8,402.50 6,034,885.82 461,454.63 4.19 9,210.76 MWD +IFR2 +MS +sag (4) 12,600.39 92.49 317.48 6,140.52 6,084.32 3,818.10 - 8,436.71 6,034,923.00 461,420.57 5.52 9,256.61 MWD +IFR2 +MS +sag(4) 12,631.70 91.92 317.57 6,139.31 6,083.11 3,841.17 - 8,457.84 6,034,946.16 461,399.54 1.84 9,285.01 MWD +IFR2 +MS +sag (4) 12,664.00 91.87 318.74 6,138.24 6,082.04 3,865.22 - 8,479.38 6,034,970.29 461,378.10 3.62 9,314.16 MWD +IFR2 +MS +sag (4) 12,695.76 91.37 318.58 6,137.35 6,081.15 3,889.06 - 8,500.35 6,034,994.21 461,357.23 1.65 9,342.70 MWD +IFR2 +MS +sag (4) 12,727.69 90.01 318.97 6,136.96 6,080.76 3,913.07 - 8,521.39 6,035,018.30 461,336.29 4.43 9,371.38 MWD +IFR2 +MS +sag (4) 12,761.32 89.52 317.89 6,137.10 6,080.90 3,938.23 - 8,543.70 6,035,043.55 461,314.08 3.53 9,401.67 MWD +IFR2 +MS +sag (4) 12,792.94 89.33 319.80 6,137.42 6,081.22 3,962.04 - 8,564.51 6,035,067.44 461,293.37 6.07 9,430.06 MWD +IFR2 +MS +sag (4) 12,823.21 88.34 319.17 6,138.03 6,081.83 3,985.04 - 8,584.17 6,035,090.52 461,273.81 3.88 9,457.07 MWD +IFR2 +MS +sag (4) 12,856.63 87.39 321.22 6,139.28 6,083.08 4,010.70 - 8,605.55 6,035,116.26 461,252.53 6.76 9,486.70 MWD +IFR2 +MS +sag (4) 12,888.97 88.04 319.33 6,140.57 6,084.37 4,035.55 - 8,626.20 6,035,141.20 461,231.99 6.18 9,515.34 MWD +IFR2 +MS +sag (4) 12,920.88 88.14 320.10 6,141.63 6,085.43 4,059.88 - 8,646.82 6,035,165.60 461,211.47 2.43 9,543.75 MWD +IFR2 +MS +sag (4) 12,953.27 88.71 320.61 6,142.52 6,086.32 4,084.81 - 8,667.48 6,035,190.62 461,190.91 2.36 9,572.43 MWD +IFR2 +MS +sag (4) 12,985.46 89.68 319.11 6,142.97 6,086.77 4,109.42 - 8,688.22 6,035,215.30 461,170.27 5.55 9,601.07 MWD +IFR2 +MS +sag (4) 13,017.27 89.45 318.91 6,143.21 6,087.01 4,133.43 - 8,709.09 6,035 ,239 .40 461,149.50 0.96 9,629.58 MWD +IFR2 +MS +sag (4) 13,049.30 89.28 319.13 6,143.57 6,087.37 4,157.60 - 8,730.09 6,035,263.66 461,128.60 0.87 9,658.29 MWD +IFR2 +MS +sag (4) 13,081.70 88.71 319.02 6,144.14 6,087.94 4,182.08 - 8,751.31 6,035,288.22 461,107.48 1.79 9,687.31 MWD +IFR2 +MS +sag (4) 13,112.24 88.39 320.53 6,144.91 6,088.71 4,205.39 - 8,771.03 6,035,311.60 461,087.86 5.05 9,714.49 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 7 COMPASS 2003.16 Build 42B • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB 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) MOO') (ft) Survey Tool Name 13,146.15 87.86 319.67 6,146.02 6,089.82 4,231.39 - 8,792.77 6,035,337.69 461,066.23 2.98 9,744.58 MWD +IFR2 +MS +sag (4) 13,178.84 87.65 321.50 6,147.30 6,091.10 4,256.63 - 8,813.51 6,035,363.01 461,045.59 5.63 9,773.45 MWD +IFR2 +MS +sag (4) 13,210.20 88.39 320.08 6,148.38 6,092.18 4,280.91 - 8,833.32 6,035,387.37 461,025.88 5.10 9,801.10 MWD +IFR2 +MS +sag (4) 13,242.64 89.83 320.08 6,148.89 6,092.69 4,305.79 - 8,854.13 6,035,412.33 461,005.17 4.44 9,829.90 MWD +IFR2 +MS +sag (4) 13,274.38 89.27 321.66 6,149.14 6,092.94 4,330.40 - 8,874.16 6,035,437.02 460,985.24 5.28 9,857.88 MWD +IFR2 +MS +sag (4) 13,308.10 89.46 320.85 6,149.51 6,093.31 4,356.70 - 8,895.27 6,035,463.40 460,964.25 2.47 9,887.50 MWD +IFR2 +MS +sag (4) 13,340.47 89.41 321.04 6,149.83 6,093.63 4,381.84 - 8,915.66 6,035,488.62 460,943.96 0.61 9,916.01 MWD +IFR2 +MS +sag (4) 13,371.95 88.87 319.41 6,150.30 6,094.10 4,406.03 - 8,935.80 6,035,512.89 460,923.92 5.45 9,943.93 MWD +IFR2 +MS +sag (4) 13,402.04 88.85 318.95 6,150.90 6,094.70 4,428.80 - 8,955.46 6,035,535.73 460,904.35 1.53 9,970.85 MWD +IFR2 +MS +sag (4) 13,435.95 88.96 320.36 6,151.55 6,095.35 4,454.63 - 8,977.41 6,035,561.66 460,882.51 4.17 10,001.07 MWD +IFR2 +MS +sag (4) 13,466.68 88.78 318.76 6,152.16 6,095.96 4,478.02 - 8,997.34 6,035,585.12 460,862.68 5.24 10,028.48 MWD +IFR2 +MS +sag (4) 13,499.18 88.24 319.65 6,153.00 6,096.80 4,502.61 - 9,018.57 6,035,609.80 460,841.56 3.20 10,057.56 MWD +IFR2 +MS +sag (4) 13,531.82 88.76 320.22 6,153.86 6,097.66 4,527.58 - 9,039.57 6,035,634.85 460,820.66 2.36 10,086.57 MWD +IFR2 +MS +sag (4) 13,564.08 88.04 320.55 6,154.76 6,098.56 4,552.43 - 9,060.13 6,035,659.77 460,800.20 2.45 10,115.12 MWD +IFR2 +MS +sag (4) 13,595.33 88.51 322.45 6,155.70 6,099.50 4,576.87 - 9,079.57 6,035,684.29 460,780.86 6.26 10,142.49 MWD +IFR2 +MS +sag (4) 13,627.87 88.32 322.81 6,156.60 6,100.40 4,602.72 - 9,099.32 6,035,710.22 460,761.22 1.25 10,170.68 MWD +IFR2 +MS +sag (4) 13,661.68 87.10 324.70 6,157.95 6,101.75 4,629.96 - 9,119.29 6,035,737.54 460,741.36 6.65 10,199.62 MWD +IFR2 +MS +sag (4) 13,693.77 85.86 323.59 6,159.92 6,103.72 4,655.92 - 9,138.05 6,035,763.58 460,722.71 5.18 10,226.95 MWD +IFR2 +MS +sag (4) 13,725.27 86.24 323.78 6,162.09 6,105.89 4,681.25 - 9,156.66 6,035,788.97 460,704.20 1.35 10,253.89 MWD +IFR2 +MS +sag (4) 13,757.98 87.49 323.82 6,163.88 6,107.68 4,707.60 - 9,175.95 6,035,815.40 460,685.02 3.82 10,281.85 MWD +IFR2 +MS +sag (4) 13,790.30 87.95 325.42 6,165.16 6,108.96 4,733.93 - 9,194.65 6,035,841.81 460,666.43 5.15 10,309.26 MWD +IFR2 +MS +sag (4) 13,820.93 89.70 324.82 6,165.79 6,109.59 4,759.05 - 9,212.16 6,035,866.99 460,649.02 6.04 10,335.11 MWD +IFR2 +MS +sag (4) 13,852.00 89.70 324.82 6,165.95 6,109.75 4,784.45 - 9,230.06 6,035,892.46 460,631.23 0.00 10,361.43 PROJECTED to TD 3/4!2010 3:18:37PM Page 8 COMPASS 2003.16 Build 42B • • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 PB1 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -70 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Drilling Services • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Weilbore: ODSK - 14 PB1 Survey Calculation Method: . Minimum Curvature Design: ODSK - 14 PB1 KupB 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 ODSK -14 - Slot ODS -14 Well Position +NI - 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / - 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK - 14 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 1/6/2009 22.43 80.81 57,719 Design ODSK -14 PB1 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 Survey Program Date 3/2/2010 From To (ft) (ft) Survey ( Wellbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.85 7,812.94 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °I1(0') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro-SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro-SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro-SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro-SS(1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS(1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro-SS(1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro-SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro-SS (1) 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro-SS (1) 3/4/2010 3:38:35PM Page 2 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Welibore: ODSK - 14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB1 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azl ND TVDSS +Ni-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ff) (It) (ft) (ft) ( °/100') (ft) Survey Tool Name 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro-SS(1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR-Gyro-SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro-SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag(2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 3 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB1 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,696.47 56.26 282.43 3,557.37 3,501.17 504.03 - 2,455.72 6,031,585.03 467,387.46 1.75 2,460.00 MWD +IFR2 +MS +sag (2) 4,795.92 55.38 283.19 3,613.24 3,557.04 522.27 - 2,535.94 6,031,603.59 467,307.32 1.09. 2,541.05 MWD +IFR2 +MS +sag (2) 4,888.73 56.43 282.13 3,665.27 3,609.07 539.11 - 2,610.93 6,031,620.73 467,232.41 1.47 2,616.72 MWD +IFR2 +MS +sag (2) 4,985.32 57.16 281.02 3,718.16 3,661.96 555.32 - 2,690.10 6,031,637.26 467,153.32 1.22 2,696.02 MWD +IFR2 +MS +sag (2) 5,083.15 57.86 278.93 3,770.72 3,714.52 569.61 - 2,771.37 6,031,651.88 467,072.12 1.94 2,776.50 MWD +IFR2 +MS +sag (2) 5,177.31 57.67 277.08 3,820.94 3,764.74 580.70 - 2,850.23 6,031,663.29 466,993.31 1.67 2,853.54 MWD +IFR2 +MS +sag (2) 5,273.02 57.15 277.99 3,872.50 3,816.30 591.27 - 2,930.17 6,031,674.18 466,913.42 0.97 2,931.37 MWD +IFR2 +MS +sag (2) 5,368.00 57.45 277.58 3,923.81 3,867.61 602.10 - 3,009.36 6,031,685.33 466,834.28 0.48 3,008.60 MWD +IFR2 +MS +sag (2) 5,463.25 56.12 278.80 3,975.99 3,919.79 613.44 - 3,088.24 6,031,696.99 466,755.46 1.76 3,085.74 MWD +IFR2 +MS +sag (2) 5,558.44 55.81 280.01 4,029.26 3,973.06 626.33 - 3,166.06 6,031,710.20 466,677.70 1.10 3,162.51 M1ND +IFR2 +MS +sag (2) 5,654.03 58.44 280.69 4,081.15 4,024.95 640.76 - 3,245.02 6,031,724.94 466,598.80 2.82 3,240.93 MWD +IFR2 +MS +sag (2) 5,748.48 58.02 281.56 4,130.88 4,074.68 656.25 - 3,323.81 6,031,740.75 466,520.08 0.90 3,319.59 MWD +IFR2 +MS +sag (2) 5,843.77 57.68 281.07 4,181.58 4,125.38 672.08 - 3,402.92 6,031,756.90 466,441.05 0.56 3,398.68 MWD +IFR2 +MS +sag (2) 5,938.67 56.64 280.79 4,233.05 4,176.85 687.20 - 3,481.21 6,031,772.34 466,362.83 1.12 3,476.74 MWD +IFR2 +MS +sag (2) 6,034.66 56.29 280.93 4,286.08 4,229.88 702.28 - 3,559.79 6,031,787.73 466,284.32 0.38 3,555.05 MWD +IFR2 +MS +sag (2) 6,129.07 55.43 280.95 4,339.06 4,282.86 717.10 - 3,636.51 6,031,802.87 466,207.67 0.91 3,631.55 MWD +IFR2 +MS +sag (2) 6,224.45 56.14 280.30 4,392.69 4,336.49 731.64 - 3,714.03 6,031,817.72 466,130.22 0.93 3,708.67 MWD +IFR2 +MS +sag (2) 6,319.42 55.74 280.69 4,445.88 4,389.68 745.98 - 3,791.39 6,031,832.36 466,052.92 0.54 3,785.57 MWD +IFR2 +MS +sag (2) 6,415.19 55.12 280.91 4,500.22 4,444.02 760.75 - 3,868.85 6,031,847.45 465,975.53 0.67 3,862.74 MWD +IFR2 +MS +sag (2) 6,502.10 54.78 279.48 4,550.14 4,493.94 773.35 - 3,938.87 6,031,860.33 465,905.57 1.40 3,932.20 MWD +IFR2 +MS +sag (2) 6,597.96 55.78 279.06 4,604.73 4,548.53 786.04 - 4,016.63 6,031,873.34 465,827.86 1.10 4,008.83 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 4 COMPASS 2003.16 Build 42B • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 PB1 Survey Calculation Method: Minimum Curvature . Design: ODSK - 14 PB1 KupB 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) ( °I100') (ft) Survey Tool Name 6,692.29 57.01 278.23 4,656.94 4,600.74 797.84 - 4,094.30 6,031,885.45 465,750.25 1.50 4,085.04 MWD +IFR2 +MS +sag (2) 6,788.05 58.28 277.61 4,708.19 4,651.99 808.98 - 4,174.42 6,031,896.92 465,670.18 1.43 4,163.26 MWD +IFR2 +MS +sag (2) 6,883.73 57.65 278.16 4,758.94 4,702.74 820.11 - 4,254.77 6,031,908.37 465,589.90 0.82 4,241.67 MWD +IFR2 +MS +sag (2) 6,978.84 57.20 278.05 4,810.15 4,753.95 831.41 - 4,334.11 6,031,919.99 465,510.60 0.48 4,319.23 MWD +IFR2 +MS +sag (2) 7,073.56 58.55 276.57 4,860.52 4,804.32 841.61 - 4,413.67 6,031,930.51 465,431.09 1.94 4,396.56 MWD +IFR2 +MS +sag (2) 7,168.75 57.36 277.30 4,911.02 4,854.82 851.35 - 4,493.77 6,031,940.57 465,351.05 1.41 4,474.21 MWD +IFR2 +MS +sag (2) 7,264.19 58.45 277.16 4,961.73 4,905.53 861.52 - 4,573.98 6,031,951.07 465,270.89 1.15 4,552.13 MWD +IFR2 +MS +sag (2) 7,359.11 57.98 278.70 5,011.73 4,955.53 872.65 - 4,653.89 6,031,962.53 465,191.03 1.47 4,630.15 MWD +IFR2 +MS +sag (2) 7,454.19 56.86 279.20 5,062.93 5,006.73 885.11 - 4,733.03 6,031,975.31 465,111.95 1.26 4,707.97 MWD +IFR2 +MS +sag (2) 7,548.93 56.20 280.22 5,115.18 5,058.98 898.44 - 4,810.93 6,031,988.95 465,034.11 1.14 4,784.97 MWD +IFR2 +MS +sag (2) 7,644.32 57.23 280.20 5,167.53 5,111.33 912.57 - 4,889.40 6,032,003.40 464,955.70 1.08 4,862.83 MWD +IFR2 +MS +sag (2) 7,737.27 57.17 279.72 5,217.88 5,161.68 926.09 - 4,966.36 6,032,017.22 464,878.81 0.44 4,939.03 MWD +IFR2 +MS +sag (2) 7,812.94 57.58 279.59 5,258.68 5,202.48 936.77 - 5,029.18 6,032,028.17 464,816.04 0.56 5,001.12 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 5 COMPASS 2003.16 Build 42B • • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 PB2 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -71 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Drilling Services • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB 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 ODSK -14 - Slot ODS -14 Well Position +NI-S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Welibore ODSK -14 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSK -14 PB2 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,660.00 Vertical Section: Depth From (TVD) +WS +F-/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 Survey Program Date 3/4/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4,740.90 11,539.05 ODSK -14 PB2 MWD (ODSK -14 PB2) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1: Survey Map Map Vertical MD Inc Az! TVD TVDSS +NIS +EI-W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro-SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro-SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro-SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro-SS(1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS(1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro-SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro-SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro-SS (1) 3/4/2010 3 :40 :41PM Page 2 COMPASS 2003.16 Build 428 III • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Welibore: ODSK - 14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E! -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) MOO') (ft) Survey Tool Name 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro-SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro-SS(1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro-SS(1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro-SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag(2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag(2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 , 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 ' 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3/4/2010 3:40:41 PM Page 3 COMPASS 2003.16 Build 42B • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Weilbore: ODSK - 14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +W-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °I100') (ft) Survey Tool Name 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,660.00 56.62 281.79 3,537.21 3,481.01 497.65 - 2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 4,740.95 55.40 279.20 3,582.47 3,526.27 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag (3) 4,836.40 54.98 280.65 3,637.02 3,580.82 523.93 - 2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 4,879.42 55.71 280.39 3,661.48 3,605.28 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 - 2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 - 2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 - 2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 - 2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 - 2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) 5,450.50 56.87 281.90 3,966.96 3,910.76 614.98 - 3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) 5,546.29 56.76 281.72 4,019.39 3,963.19 631.39 - 3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 5,641.35 56.95 279.09 4,071.38 4,015.18 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031,743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41 PM Page 4 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wel!bore: ODSK - 14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB2 KupB 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 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 - 3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag(3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 - 3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 - 4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 - 4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) 6,878.72 56.92 279.21 4,758.80 4,702.60 803.14 - 4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) 6,974.00 57.33 278.74 4,810.52 4,754.32 815.62 - 4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 7,070.69 58.44 280.02 4,861.92 4,805.72 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) 7,164.65 57.01 278.08 4,912.10 4,855.90 841.48 - 4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) 7,259.49 56.57 276.96 4,964.04 4,907.84 851.87 - 4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 7,354.90 56.92 277.34 5,016.36 4,960.16 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) 7,451.12 57.52 279.93 5,068.46 5,012.26 873.95 - 4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) 7,545.34 57.71 279.62 5,118.93 5,062.73 887.46 - 4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 7,640.14 57.14 280.28 5,169.97 5,113.77 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 - 4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) 7,819.80 57.61 281.36 5,265.98 5,209.78 929.54 - 5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 7,892.32 58.60 282.43 5,304.29 5,248.09 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 - 5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032,114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032 ,154 .95 464,244.87 2.51 5,576.60 MWD +IFR2 +MS +sag (3) 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032 ,242 .53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032 ,318 .39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032,362.71 463,771.84 2.61 6,093.25 MWD +IFR2 +MS +sag (3) 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD +IFR2 +MS +sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41PM Page 5 COMPASS 2003.16 Build 428 • . Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Welibore: ODSK - 14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E1 -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD+IFR2+MS+sag (3) 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6,032,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD +IFR2 +MS +sag (3) 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) 10,765.16 93.44 316.30 6,146.08 6,089.88 2,398.43 - 7,276.13 6,033,498.78 462,575.27 1.98 7,638.07 MWD +IFR2 +MS +sag (3) 10,862.85 90.30 314.19 6,142.89 6,086.69 2,467.75 - 7,344.86 6,033,568.37 462,506.82 3.87 7,728.23 MWD +IFR2 +MS +sag (3) 10,964.23 86.00 312.52 6,146.16 6,089.96 2,537.30 - 7,418.52 6,033,638.21 462,433.46 4.55 7,823.02 MWD +IFR2 +MS +sag (3) 11,056.05 90.61 319.69 6,148.88 6,092.68 2,603.38 - 7,482.09 6,033,704.54 462,370.16 9.28 7,907.17 MWD +IFR2 +MS +sag (3) 11,151.70 86.98 318.44 6,150.89 6,094.69 2,675.61 - 7,544.73 6,033,777.02 462,307.82 4.01 7,992.83 MWD +IFR2 +MS +sag (3) 11,247.97 85.96 319.38 6,156.82 6,100.62 2,748.03 - 7,607.88 6,033,849.68 462,244.97 1.44 8,079.04 MWD +IFR2 +MS +sag (3) 11,345.12 86.46 317.68 6,163.24 6,107.04 2,820.66 - 7,672.07 6,033,922.57 462,181.08 .1.82 8,166.29 MWD +IFR2 +MS +sag (3) 11,440.88 86.76 316.50 6,168.91 6,112.71 2,890.67 - 7,737.16 6,033,992.83 462,116.28 1.27 8,253.35 MWD +IFR2 +MS +sag (3) 11,539.05 86.21 314.71 6,174.93 6,118.73 2,960.68 - 7,805.70 6,034,063.12 462,048.03 1.90 8,343.60 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41 PM Page 6 COMPASS 2003.16 Build 428 Completion NEER - Fishing Tool List • 5/24/13 9:22 AM Initials of Update Person St -By Tools f/ 7" 26# Casing Updating Date OTY ITEM Weight Lengt VYtdth CONTACT PHONE NO. Baker Fishing Tools lbs ft ft Tools Overshots, Upper /Lower Extensions, O'er -Size Gtides 5 3/4" Bowen Series 150 Overshot 2 Bowen 5 3/4" Overshot, 3 1/2" IF Box 2 Bowen 5 3/4" Upper Extension, Box x Pin 1 Bowen 5 3/4" Lower Extension, Box x Pin Hollow Mill Inserts: for 5 3/4" Bowen OverShot 1 3 1/2" ID Hollow Mill Insert (3 1/2" pipe body) Grapples, Controls, Packoffs: for 5 3/4" Bowen OverShot 2 3 1/2" Grapple, 1 4 3/4" Grapple w/ Control 2 2 7/8" Grapple w/ Control 1 3 1/4" Grapple w/ Control 1 3 3/8" Grapple w/ Control 1 4 1/4" Grapple w/ Control Parts 1 Stop Ring for 5 3/4" Overshot JARS 1 Lubricated Bumper Jar- 43/4" OD x 2 " ID - 3 1/2" IF B xP 1 Hyd Fishinq Jar - 43/4" OD x 2" ID - 3 1/2" IF BxP 1 Accelerator /Intensifier Jar - 43/4" OD x 2" ID - 3 1/2" IF B xP Junk Mills / Dress Off mills 1 6 -1/8" SOD Junk Mill, 3 1/2" Req Pin X -Overs 1 X -Over, 3 1/2" IF Pin x DC Conn Box 1 X -Over, DC Conn Pin x 3 1/2" IF Box 1 Pump -out Sub, w/ 3 1/2" IF Box x Pin Spears & Grapples Itco Spear 1 Spear Ext. 2 Spear Grapple f/ 4 1/2 Tubing 2 Wireline Rope Spear w/ 3 1/2 IF Box 1 Wireline Rope Spear Stop Sub 5 7/8 to 6 -1/8" OD Well Dynamics Packer Mill Over Equipment 1 Boot Baskets, 4.750" OD, 3 1/2" Reg Box x Pin 1 Downhole Inline Magnets, 4 3/4" OD, 3 1/2" IF Box x Pin 1 Bit Sub 3 1/2 Req x 3 1/2 IF 1 5 3/4 Globe Basket 3 1/2 Req Conn. 1 7" Ultra -Clean Casing Scraper w/ 3 1/2 Conn. NOTE: Primary VACS BHAs to have 4 1/2" XTM 50 pup It (from Allis Chalmers) for handling Page 1 Prepared by: James Sonnier 6 Standby Fishing Pkg.] G [ HYDRIL ANNULAR (5K) - GK, LATCHED HYDRIL 47q STUD /FLANGE CONNECTIONS APPROX WEIGHT = 8,200 LBS 95 , , , I� I ,..., " N ° IM HYDRIL SINGLE RAM I N • ` q0 35 APPROX WEIGHT C 6,000 LBS '1 ° I _III MEN 157 I II w I -■ II HY ' RIL OEM HYDRIL SINGLE RAM 2I STUD /STUD CONNECTIONS r� APPROX WEIGHT = 6,000 LBS I 3" 5000 1 HCR VALVE Vim!) f 3" 50001 HCR VALVE / 3" CHOKE LINE um in .■n n / n 2" KILL UNE MUD CROSS ■ / '.' ) �■> n 24 APPROX WEIGHT /F GE CONNECTIONS APPROX WEIGHT = 1,800 LBS I r 50001 GAE VALVE ��wm in iiw 3" 50001 GATE VALVE SWING RADIUS — MIMI HY�RIL 'II - HYDRIL SINGLE RAM 44 -5/8" 24 FLANGE/STUD CONNECTIONS .® = L APPROX WEIGHT = 6,000 LBS • HYDRIL 11 " 5,0O0PSI BOP STACK 95 PLAN VIEW HYDRIL 11 " 5,O00PSI BOP STACK ELEVATION O Nabors A sia moo ""°a' RIG 19-AC "" BOP STACK HYDRIL II'; 5,000PSI wwx m ZM om ®x _ wnam n r 116, A 'ME 'B° °k'" I" cecorIDI 90NE ILLS ah 14 2013 p616 ISILBOP_S '" 1 OF 1 • • PIONEER NATURAL RESOURCES Decompletion Information • I Well ODSN -37 ODSN -17 ODSK -14 Hydrow II Packer Depth (ft-MD) 4045 2638 4838 Angle @ Packer 27° 47° 55 ESP Depth (ft-MD) 7307 13753 9921 Block Weight (kips) 50 50 50 Anticipated PU String Hook Weight - Above Packer (kips) 72 64 79 Stretch (ft) 1.7 0.5 1.6 Packer Shear Release (kips) 33 33 33 Anticipated Surface Overpull for Packer Shear Release 55 47 62 (kips) Anticipated Hook weight for Shear Release (kips) 127 111 141 Anticipated Hook Weight - Full String after packer release 103 132 138 (kips) Stretch - Full string (ft) 6 9 6.4 80% Tensile Limit (kips) 165 165 165 90% Tensile Limit (kips) 180 180 180 100% Tensile Limit (kips) 195 195 195 Previous ESP Run @ TD; PU Previous ESP Run @ TD; PU Previous ESP Run @ TD; PU Comments 100 / SO 85 - total losses 122 / SO 65 115 / 50 90 1980 bbls ! • RECOMMENDED PRACTICES Pulling an ESP Completion Issue Date: February 2008 Revision Date: April 02, 2013 SCOPE & BACKGROUND Electric Submersible Pumps (ESP) are a commonly utilized form of artificial lift. The standard practice is for a drilling rig to drill and case the well and then move off. A workover rig then moves on to perforate, stimulate, and complete the well. At Oooguruk, the drilling rig will handle all of these procedures. This recommended practice covers pulling an ESP completion. PREPARATION Confirm spooling unit is aligned to provide a straight pull on the cable, and to provide operator clear view. ESP power cable may be damaged if rig is not positioned properly. Spooler to be spotted far enough back from the rig to allow adequate slack in the cable i.e. (Being able to see the entire derrick). Confirm Baker Hughes technician has reviewed operation of unit with operator and has signed operator off as qualified on Baker Hughes check off sheet. Confirm sheave is 54" in diameter. Confirm safety cable is attached to sheave. Normal running height shall not exceed 40' above floor. Confirm power to the ESP is locked out and cable is disconnected. All locks shall be attached in accordance with lock -out tag -out procedures. A pre job safety/planning meeting shall be held prior to pulling the pump and during crew changes to identify risks and mitigations. A Baker Hughes representative will be on the rig floor at all times during the ESP pull. Refer to previous install records and tally sheets for a list previously installed clamps. Keep an accurate count of all small parts pulled from the well. A Baker Hughes representative shall be on the rig floor to disconnect penetrator, make down -hole electrical checks, and to disassemble and inspect ESP. A Baker Hughes representative will check and record phase -to -phase and phase -to- ground conductivity for all three ESP cable legs at each electrical connection/splice. PULLING PROCEDURE 1. RU ESP cable spooling unit with empty cable spool installed. Ensure that the rig is properly centered over the well to prevent damage to the cable when pulling the ESP - remember that the tree is off center on the ESP wells and the rig must be centered with the tubing head adapter. 2. Notify Baker Hughes representative prior to releasing the hanger. A Baker Hughes representative shall be on location when the hanger penetrator is pulled. Close annular preventor. Slowly PU assembly until hanger is off tubing spool. If well is stable, open annular preventer. Record pick up and slack off weights. Continue PU until hanger is at rig floor. LD landing joint and hanger. • Check and record ESP conductivity phase -to -phase and phase-to- ground for all three Version 2.2 Page 1 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2013 • • RECOMMENDED PRACTICES HUGHES phases below the hanger penetrator. • High -pot the hanger penetrator prior to reusing. This test shall be performed and recorded in accordance with manufacturer's recommended procedures. • Confirm ESP cable sheave is 54" in diameter. Confirm safety cable is attached to sheave. 3. Pull ESP completion. Spool the ESP cable onto the spooling unit while pulling out of hole. Wipe the cable with absorbent to prevent oil contamination. Depending on well conditions, it may be possible to keep some diesel cap as solvent in the annulus to aid in pulling the tubing with less residual crude oil. However, under no circumstance should the well be under- balanced. • Verbal acknowledgement between driller and spooler operator is required each time the completion is moved. • Portable gas detectors shall be available on the rig floor and in the spooling shed. Detectors shall be tested for proper operation prior to pulling cable. Gas checks shall be made periodically on the rig floor. Checks shall be made in the spooling unit whenever personnel enter the unit. • The entire length of the ESP cable shall be visually inspected as it comes out of the hole • by the spooler operator. Flag visible bad spots in ESP cable and record approximate depths and cut out any damaged cable 5 foot above and 5 foot below the damage. Label each piece with the well, source, and depth - these will be sent to Baker Hughes at the end of the well for analysis. If there are several bad spots send the entire reel to Baker Hughes for analysis. • When bands are used they should be cut off, not twisted off as they come out of the hole. Record the number of bands suspected of being lost. • The hole shall be covered at all times when bands are being removed. • Cut out all pigtails and examine for signs of damage. Pigtails shall not be reused. 4. Pull ESP assembly but DO NOT lay it down. The ESP assembly must be inspected by section in the vertical position while on the rig floor by a Baker Hughes representative and a Pulling Inspection Report completed. 5. Lay down ESP 5.1. Discharge Assembly and Pump 5.1.1. All findings of the pump removal will be documented on the field service pull report. 5.1.2. Install the proper clamp on top of the pump. 5.1.3. Check the inside surface of the pump discharge for debris or wear. If shaft can be reached, rotate shaft(s) to check for side play and smooth shaft can be reached, rotate shaft(s) to check for side play and smooth rotation; record results on pull report. 5.1.4. Observe the pump as it is being lifted from well and look for paint scrapes, dings, scale, scratches, corrosion and scars. Check for indication of sand or scale behind protectors, flat cable and flat cable guards. Record findings on the pull report. 5.1.5. Place an additional clamp on the lower pump and set on the work table. Cover the wellbore and carefully separate the pump, be ready to catch Version 2.2 Page 2 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. © 2013 • • �.r RECOMMENDED PRACTICES WKS the coupling. 5.1.6. After the two pumps are separated check shaft rotation of both pumps and check the condition of o- rings, coupling and shaft. 5.1.7. Put the shipping cap on upper pump and carefully lay down upper pump. 5.1.8. Check the top shaft of lower pump for shaft side play, plugging, scale, corrosion, erosion, shaft rotation. 5.1.9. Lift the lower pump to the intake and visually check the intake/gas sep. 5.1.10. Install a lifting clamp on the seal head. 5.1.11. Cover the wellhead and disconnect the pump from the seal, catch the coupling. Check shaft for side play. 5.1.12. Place the coupling on the pump shaft and then shipping cap. 5.1.13. Carefully lay down the pump and intake. 5.1.14. The procedure for checking the rotary gas separator and recirculation pump is the same as checking the pump. 5.2. Seal Section 5.2.1. Check the shaft rotation of the seal and motor coupled together using the proper coupling wrench. 5.2.2. Remove the plug from the head vent. Note: Use caution when removing the vent plug, as the oil inside the seal section could be under pressure. 5.2.3. Remove the vent plug from the upper guide drain and drain off the well fluid. The fluid that drains from this area should be well fluids. 5.2.4. Remove the vent plug from the center guide drain and drain off the contents (should be motor oil only). Record the type and quantity of fluid drained from all chambers on the pulling report. 5.2.5. Remove the vent plugs from the lower guide drain and drain the fluid from the chamber. 5.2.6. Reinstall the vent plugs in the center guide and lower guide drains. 5.2.7. Reinstall the vent plug in head vent and the upper guide drain. 5.2.8. Clean and dry off the pothead motor connection area plus about 18 5.2.9. inches above the motor head with solvent, motor oil, rags or other means. Version 2.2 Page 3 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc 02013 • • Mkt RECOMMENDED PRACTICES RNIBMS 5.2.10. Tie a rag around the bottom of the seal to prevent contamination of the pothead connection. 5.2.11. Disconnect the pothead by removing the socket head cap screws. 5.2.12. Remove the pothead with a straight pull, do not twist or bend back and forth. CAUTION: WHILE YOU ARE DISCONNECTING THE POTHEAD, MAKE SURE NO WELL FLUID, WATER, OR OTHER FOREIGN MATERIAL GETS INTO THE OPEN TERMINAL INSULATION BLOCK. 5.2.13. Use the oil pump assembly to flush any foreign material out of the terminal insulation block area. Put the pothead shipping cap on the motor head. CAUTION: The motor electrical tests must always be done a safe distance from the wellhead as a safety precaution to prevent sparks generated by a megohmmeter igniting gasses emitted from the wellhead. 5.2.14. Always perform the megohmeter test last; residual voltage charge left in the motor windings can damage motor rotation indicator and/or ohmmeter. Electrical test performed after a megohmmeter test should only be performed after the item has been shorted to ground for one (1) minute through the meter. 5.2.15. Put the correct clamp and lifting sling on the motor and set it on the wellhead. 5.2.16. Cover the wellhead to prevent fasteners or couplings from being dropped down the well. 5.2.17. Unbolt the seal section and lift it off the motor. 5.2.18. Capture a sample of the oil draining from the bottom of the seal section; note the condition of the oil on the pulling report. 5.2.19. Set the motor shipping cap on the motor head and install two hex head cap screws to hold it temporarily in place while checking the seal section shaft rotation. 5.2.20. Shaft rotation of seal section. 5.2.21. Check the seal shaft for side play the same way the pump shaft was checked. 5.2.22. With the assistance of a rig hand, hold the seal section to one side while you pull the shipping cap off and check the motor shaft rotation. 5.2.23. Flush the motor to seal coupling with clean oil and put it back on the shaft. 5.2.24. It is important to put the couplings back in the same location as shipped from the service center. Version 2.2 Page 4 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or m whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. 02013 • • Ea II RECOMMENDED PRACTICES "S 5.2.25. Install a clean shipping cap on the seal base flange and bolt it securely with two bolts and two nuts. Carefully lay the seal down. 5.3. Motor 5.3.1. Put the shipping cap on the top of the motor and secure with bolts. 5.3.2. Lift the motor from the well and look for drag marks and corrosion. 5.3.3. Remove the lower drain from the base of the motor to remove an oil sample for inspection. 5.3.4. Note the condition of the oil on the pulling report; dark, water, brass, steel,black, etc. 5.3.5. Replace the lower drain in the base and carefully lay the motor down. 5.3.6. After the equipment has been laid down and the motor has been moved a safe distance from the wellhead, perform the following electrical tests: 5.3.7. Use an ohmmeter and measure the motor phase to phase resistance (A to B, A to C and B to C), record the results on the pulling report. 5.3.8. Use a megohmmeter to measure the motor phase to ground resistance (A to ground, B to ground, and C to ground). The megohmmeter D.C. test voltage should be 1,000 volts for one minute, record readings on pulling report. 6. Ensure Baker Hughes ESP checklists are completed. a Ensure the Baker Hughes ESP Checklist has been • • completed. Version 2.2 Page 5 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2013 • • FR II RECOMMENDED PRACTICES BAKER HUMES 000GURUK ESP CHECKLIST PULLING THE ESP ASSEMBLY PART 1 OF 2 WELL: BAKER HUGHES REP (INITIAL ITEMS AS THEY ARE COMPLETED) Confirm spooler operator is qualified to operate spooler. Confirm all power is disconnected and properly locked out. Safety /planning meeting held at beginning of job describing all work to be done and safety procedures to be followed. Entire length of cable visually inspected. Bad spots flagged. Depths of bad spots: ' Identify any junk left in hole while pulling ESP completion. Number of cable bands suspected lost in hole = Phase conductivity checked at the hanger penetrator and recorded on Baker Hughes pulling report. Phase conductivity checked below the hanger penetrator pigtail and recorded on Baker Hughes pulling report. Phase conductivity checked at the motor pothead and recorded on Baker Hughes pulling report. Examine areas for solids, metal, vibration, or drag marks and record: Pump Discharge: Pump Intake: Pump Body: Seal Body: Motor: Motor Pothead: Version 2.2 Page 6 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ® 2013 • • RECOMMENDED PRACTICES Motor Body: III Version 2.2 Page 7 of 8 This document is the property of Baker Hughes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2013 • Hie RECOMMENDED PRACTICES HUGHES 000GURUK ESP CHECKLIST PULLING THE ESP ASSEMBLY PART2OF2 WELL: BAKER HUGHES REP -- (INITIAL ITEMS AS THEY ARE COMPLETED) Attempt to manually turn. Check shaft play and coupling integrity for: Pump Discharge - Results: Pump Intake - Results: Gas Separator - Results: Seal Sections - Results: Motor - Results: Confirm Baker Hughes pulling report is completely filled out and is legible. Equipment boxed in shipping crates and ready to ship. Give completed form to Company Representative. Date: Comments: Version 2.2 Page 8 of 8 This document is the property of Baker Hugbes and the information contained herein is Pulling an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2013 • • PIONEER NATURAL RESOURCES Completion Information 1 / (24.88) ■ (18.239) O 8 (11.869) © 0 0 © 0 A-..— . © A 1 ir`air�r► 1 4 111 1 / 0 (� 4341 ______- ----______--'—'— // \ \ (3.250) 0 C ∎�i — _ `\ _ MA I N 411.1r— �'�� 4 C — � 1 � - -I — (010.9161 (�i II / (1.250) 732.953) ( 2 96 1 � O) �N.. \ \�� / / — ___ —_ —_ — — _— _— ___ —___ _ I l¢4 625) ' 1�/ " / \--OFFSET t - +I (3.725 -6TPI MCA 1 Amor AIWA i <1 © Q�� MOD BUTTRESS 2 80 % (3 H -BPV) A. 8 SECTION A -A 6 ; i r . . , (g ((((((r � o ,, SCALE 1/4 (25vetco Vetco Gray A ASSEMBLY / SWE _ / \ MARKING LOCATION. M TUBING HGR, MB -233, OFFSET, r A A. LESIKAR 10 -3/4 0 3 -1/2, 3 -1/2 OD 9.2 PPF A i MOD BUTTRESS 008 BIM, 3.725-6TPI MCA 1. DIMENSIONS ARE IN INCHES. 11 L860 300 TOP, 3H -OPV, W /HORIZONTAL OUTLET, NOTES: J. HWANG A/F 131W FEEDTHRU MANDREL AND LOWER CONNECTOR, W/3- CONTROL LINES 14- SEP -D6 onuiw gmcw €. - 3 D IRRrorR H 148570 -I X[ NO NOT VA, BRAVING .... 1 0RU a 1 8 I 7 Pro /I MODEL PARAMS REV.VER: - 1 5 REL LEVEL: - Released BRANCH:- morn 3 I 2 1 31 / Pro /I DRAWING PARAMS REV.VER: - 1.5 REL LEVEL: - Released BRANCH:- main 1 000SL 0000 - 810570-1 I RRO /E • c MAJOR O.D.: 5.500" SWAGE MINOR O.D.: 4.593" II i - CONNECTION O.D.: 3.625" ORIENTING SLEEVE WEIGHT: 6.4# IL MINIMUM I.D.: 2.365" DRIFT I.D.: 2.347" OVERALL LENGTH: 108" CONNECTION(S): TYPE: OVAL MATERIAL: 4130 80 KSI INTERNAL YIELD PRESSURE: 6,000 PSI EXTERNAL YIELD PRESSURE: 4,000 PSI BODY YIELD STRENGTH: 250,000 LBF BODY PIPE BRINELL: 217 -235 ROCKWELL C: 18 -22 KICKOVER TOOL: KOT -2, OM -1 RUNNING TOOL: RK -1 POCKET PULLING TOOL: 1 -5/8 JDS LATCH: RK, RKP VALVE: 1.5" O.D. �— 1.556" SEAL BORE 1.494" SEAL BORE M, i Ira I Zo NV GSv L EMON SI lir DESCRIPTION :-...,_____ 2.8 FO -2 SWAGE MAN ASSEMBLY SCALE SHT OF DWG NO N/A 1 1 2112S101 • S Page 1 of 1 HALLIBURTON September 19, 2012 Engineering Data Sheet EQUIPMENT MATERIAL NO.: 100005672 LN 2.313 X 9CR BLNK PART NUMBER: 11X23160 -A DESIGN SPECIFICATIONS LOCK PROFILE X SIZE 2.313 MAXIMUM OD 3.240 inch LENGTH 14.60 inch MATERIAL 9CR -1 MO SERVICE H2S SERVICE REMARKS H2S AND /OR CO2 SERVICE BASED ON CUSTOMER DEFINED, WELL SPECIFIC CONDITIONS. APPLICATIONS MUST BE REVIEWED FOR SPECIFIC ENVIRONMENTAL COMPATIBILITY MEETS MATERIAL SERVICE REQUIREMENTS OF NACE MR -01 -75 TOP THREAD BLANK BOTTOM THREAD BLANK CONNECTION TYPE BLANK (END) (Unless specified, Dim - inches, pres -psi, weight -Ibs, temp -deg F) NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. Halliburton, Dallas, Texas, U.S.A. • Page 1 of 3 HALLIBURTON September 19, 2012 Engineering Data Sheet EQUIPMENT MATERIAL NO.: 102066106 TRSV,NE,4.65 2.313,H2S,5K PART NUMBER: 478LXE11 DESIGN SPECIFICATIONS VALVE MODEL NE CLOSURE TYPE FLAPPER SIZE 2 7/8 LOCK PROFILE X MINIMUM INSIDE DIAMETER WITHOUT PACKING BORE 2.350 inch TOP SEAL BORE ID- MINIMUM 2.313 inch BOTTOM SEAL BORE ID- MINIMUM 2.313 inch MAXIMUM OD 4.65 inch LENGTH 62.95 inch MATERIAL 9CR -1 MO /410 STAINLESS STEEL/17 -4 PH STAINLESS STEEL SERVICE H2S SERVICE REMARKS H2S SERVICE BASED ON CUSTOMER DEFINED, WELL SPECIFIC CONDITIONS. APPLICATIONS MUST BE REVIEWED FOR SPECIFIC ENVIRONMENTAL COMPATIBILITY. MEETS MATERIAL SERVICE REQUIREMENTS OF NACE MR0175 /ISO 15156 TOP THREAD 2 7/8 -6.40 DB BOTTOM THREAD 2 7/8 -6.40 DB CONNECTION TYPE BOX -PIN PRESSURE RATING 5000 pounds /sq. inch BURST PRESSURE 11541 pounds /sq. inch API COLLAPSE PRESSURE AT AMBIENT 9155 pounds /sq. inch API COLLAPSE PRESSURE AT MAX TEMPERATURE RATING 8225 pounds /sq. inch EXTERNAL PRESSURE RATING 5000 pounds /sq. inch TENSILE WITH WORK PRESS, WITHOUT TBG THD, AT AMBIENT, 144 pound CALC /1000 TENSILE WITHOUT WORK PRESS, WITHOUT TBG THD, AT 209 pound AMBIENT, CALC /1000 TENSILE WITH WORK PRESS, WITHOUT TBG THD, AT MAX 117 pound TEMPERATURE RATING, CALC /1000 TENSILE WITHOUT WORK PRESS, WITHOUT TBG THD, AT MAX 182 pound TEMPERATURE RATING, CALC /1000 TEMPERATURE RATING 40 TO 300 Deg. F MAXIMUM FULL OPEN PRESSURE 2000 pounds /sq. inch • Page 2 of 3 MINIMUM CLOSING PRESSURE 875 pounds /sq. inch PISTON DISPLACEMENT VOLUME .66 cu. inch EQUALIZING FEATURE YES MAXIMUM PRESSURE DIFFERENTIAL AT VALVE OPENING 5000 pounds /sq. inch CONTROL LINE PRESSURE TO EQUALIZE AT PRESSURE RATING 4000 pounds /sq. inch CONTROL LINE CONNECTION 7/16 -20 HIF HIF KIT 101085853 (93F1499) LOCKOUT TYPE NE COMMUNICATION TYPE NE LOCKOUT TOOL, PERMANENT 101597423 (42LOX23107) LOCKOUT TOOL REMARKS LOCKOUT ONLY, NO COMMUNICATION PRESSURE TO LOCK OUT 2000 pounds /sq. inch EXERCISE TOOL 101060088 (427L252) COMMUNICATION TOOL 101328568 (42CTX23101) INSTALLATION EXTENSION PENDING WIRELINE REPLACEMENT VALVE 120056522 (22FXE23112) RUNNING /PULLING PRONG EXTENSION PENDING ISOLATION ASSEMBLY LOCK MANDREL TYPE 2.313 X ISOLATION ASSEMBLY EQUALIZING VALVE TYPE 2.313 XO ISOLATION ASSEMBLY EXTENSION MANDREL PENDING ISOLATION SLEEVE 101073451 (78D2219) ISOLATION SLEEVE 0-RING 100006603 (91QV1328 -H) SPECIAL FEATURE EXERCISE PROFILE SEAT INSERT INSTALLATION TOOL 101281950 (83M2057) SEAT INSERT TORQUE -MIN 1800 foot pound BODY TORQUE 1900 foot pound SHOULDER BOLT TORQUE 90 inch pound SPRING COMPRESSION TOOL 101673426 (83M2681), 101678655 (83M2682) DRIFT BAR 101088123 (81R104) DRIFT BAR OUTSIDE DIAMETER 2.303 inch DRIFT BAR LENGTH 24.00 inch TEST FIXTURE -BOX END 101905249 (81724475), 101090611 (81T12199), 101090612 (81T12200) TEST FIXTURE -PIN END 101905250 (81T24476), 101090610 (81T12198),101090612 (81T12200) API /ISO TYPE SCTRSV MEETS QUALITY REQUIREMENTS API -Q1 /ISO 9001 MEETS INDUSTRY SPECIFICATION(S) API 14A/ISO 10432 API /ISO SPECIFICATION EDITION ELEVENTH API /ISO VALIDATION LEVEL /SERVICE CLASS 1,3S API /ISO VALIDATION DATE 08 -12 -11 API /ISO VALIDATION METHOD VARIATION • Page 3 of 3 API /ISO VALIDATION REFERENCE 78001213 OPERATING ENVELOPE 478LXE11 BDMI/TECHNICAL OPERATIONS MANUAL 478LXE11 (END) (Unless specified, Dim-inches, pros-psi, weight -Ibs, temp -deg F) NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. HalMburton, Dallas, Texas, U.S.A. • Page 1 of 1 HALLIBURTON May 23, 2013 Engineering Data Sheet EQUIPMENT MATERIAL NO.: 101052771 HYDR CONTRL LINE,1/4,.049,3000,316L PART NUMBER: 22SXX31300 DESIGN SPECIFICATIONS TUBING MATERIAL 316L STAINLESS STEEL TUBING TYPE WELDED AND SUNK TUBING OUTSIDE DIAMETER .25 inch TUBING WALL THICKNESS .049 inch LENGTH 3000 foot FITTING MATERIAL 316L STAINLESS STEEL CONNECTION 1/4 TBG X 1/8 MP PRESSURE RATING 17000 pounds /sq. inch TEST PRESSURE 18000 pounds /sq. inch SPOOL -OFF DEVICE 7 X 20 X 36 (END) (Unless specified, Dim - inches, pres -psi, weight-Ibs, temp -deg F) NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. Halliburton, Dallas, Texas, U.S.A. • • RECOMMENDED PRACTICES Running an ESP Completion with 2 -7/8" tubing Issue Date: February 2008 Revision Date: April 02, 2013 SCOPE & BACKGROUND Electric Submersible Pumps (ESP) are a commonly utilized form of artificial lift. The standard practice is for a drilling rig to drill and case the well and then move off. A workover rig then moves on to perforate, stimulate, and complete the well. At Oooguruk, the drilling rig will handle all of these procedures. This recommended practice covers running an ESP completion. PREPARATION AND HANDLING PRECAUTION A pre job safety /planning meeting will be held prior to running the pump and at any crew change to ensure good communication between all parties on location. A Baker Hughes representative will be on the rig floor at all times during the running of the ESP and will be responsible for ensuring that cable is kept free when setting the slips. Bring cable, motor oil and pump equipment into a heated location at least 48 hours prior to running. Handle ESP assemblies in original shipping boxes until ready to PU to floor. Do not allow any cable or pigtails to stick out of spooling shed until ready to run to the rig floor if temperature is below 30 °F. Do not allow cable to drag in dirt or gravel or across rough edges while TIH. Lay plywood between the cable spooler and the rig to protect cable from dragging. Verify rig is centered over hole. ESP power cable will be damaged if rig is off center of hole. Exercise extreme caution when bringing motor and pump up to rig floor to avoid jarring or bending equipment. Do not handle cable spool with forks or slings in direct contact with the cable. RUNNING PROCEDURE A Baker Hughes A representative shall be on the rig floor at all times during the running of the ESP Verify the size and horse power of ESP motor as per proposed program for the well. Verify that the length of motor lead flat cable will place the splice on the handling pup above the discharge assembly. A Baker Hughes rep shall be on the rig floor at all times during the running of the ESP. 1. Install ESP cable in the spooling unit. The completion will be run with a new motor lead extension, seal section and motor. On rig workovers it may be permissible to use an existing pump and/or cable - Baker Hughes representative will advise. Pump assembly is as follows - refer to ESP Assembly Schematic with well plan for details: Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 1 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2012 • • RECOMMENDED PRACTICES �K� • CENTRALIZER • MOTOR GAUGE UNIT • MOTOR • TANDEM SEAL SECTION • PUMP INTAKE /GAS SEPARATOR 1 • PUMP(S) • DISCHARGE HEAD • DISCHARGE GAUGE UNIT • AUTO DIVERTER VALVE 2. Confirm spooling unit is aligned to provide a straight pull on the cable, and to provide operator clear view. Spooler to be spotted far enough back from the rig to allow adequate slack in the cable (i.e. able to see the entire derrick). 2.1. Confirm Baker Hughes technician has reviewed operation of unit with operator and has signed operator off as qualified on Baker Hughes check off sheet. 2.2. Confirm sheave is 54" in diameter. Confirm safety cable is attached to sheave. Normal running height shall not exceed 40' above floor. The flat MLE cable should be hand fed to the floor and the round cable tied off at the floor until the flat round splice is secured to the tubing to minimise stress on the flat/round splice Note: The MLE is to be connected to the ESP motor and secured to the ESP equipment prior to splicing it to the round cable. In preparation of the splice the round cable should be brought over the sheave and secure with rope in such a way that it cannot be pulled back over. The cable should remain secured until after the splice is completed and the round cable is secured to the tubing with a Cannon clamp at the next tubing collar. If a Gator Splice connector is being used, a gator splice clamp should be placed over the connector. Note: Pothead/Motor Lead Extension Handling: • Do not bend the motor lead near the base of the pothead. • Never bend the motor lead sideways. This causes relative movement of the conductors. • Never allow the pothead pins to be pushed into the pothead. • Never pull directly on a pothead, especially when unreeling or running over a sheave. Pull on the cable at least 1' away. • Do not apply tension to the motor lead during installation. Have it and the cable above it completely banded prior to applying any cable tension. • Use small sheave for MLE 3. Record the dimensions and nameplate of each piece of equipment prior to RIH. 4. Pick up the ESP motor with attached MGU and centralizer. 5. Attach MGU TEC connection 6. Slowly lower the motor assembly into the well and lower lifting clamp onto the wellhead slips. Assemble the tandem seals to motor assembly. Line up assembly alignment marks at the seal. 6.1. Service the seal and the motor as per standard servicing procedures outlined in the Technical Service Manual. 7. Attach pump intake or gas separator Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 2 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. © 2012 • • SUS RECOMMENDED PRACTICES BAKKER 8. Attach pump(s). 8.1. When running 4" pumps, secure MLE to pump housing using 4000- B- 03PG1.40 clamps. Do not use protectolizers with 4" pumps. 8.2. When running 5" pumps, secure MLE to pumps using protectolizers. Do not use pump housing clamps on 5" pumps. The running OD of the MLE flat cable clamps over Baker Hughes 538 series ESP is 6.23 ". This design has been tested and is NOT approved for install. Additionally, no 1 1/4 Stainless Steel Bands are to be used on the pump sections. 9. Attach Discharge Assembly 10. Perform TEC wire splice to discharge gauge unit. 11. Secure MLE to 2" handling pup joints using 2875 -C -03 clamps. Note: It is absolutely essential that all clamps and bands used to install the ESP cable be counted and reported accurately so that there can be no confusion concerning the number in the well if the completion needs to be pulled in the future. A count of all clamps, bands, and protectolizers used should be recorded on the running tally and any deviations from the original ESP schematic should be noted. Note: The hole shall be covered at all times when cable bands or clamps are being installed. Exercise caution to insure slips will not be set on either the ESP or cable. Damage to the cable will require that the installation is stopped and the cable repaired. Assign one man on the rig floor to be responsible for watching the cable when lowering into well HAND SLIPS. HAND SLIPS shall be used while RIH with ESP assembly to minimize the risk of cable damage. 12. A Customer representative shall witness free rotation of completely assembled ESP unit on rig floor. 13. Confirm again that all serial numbers and equipment clamp numbers have been recorded before TIH. 14. Perform round to flat cable splice as per equipment diagram. 15. Confirm gauge readings. 16. RIH the ESP with Baker Hughes #1 round CELR cable and 2 -7/8" tubing. Go in hole no faster than 1 joint per minute (1800 ft/hr). Verbal acknowledgement between driller and spooler operator is required each time the completion is moved. Ensure ESP cable is properly placed on the minor OD of each GLM. Refer to "Correct placement of ESP cable alongside GLM.doc" for details. 17. If distance from MLE splice to packer is greater than 7000', a taped cable splice or gator splice must be performed before reaching the packer. Splice location to be determined by Baker Hughes personnel based on available cable quantities on reels. Land splice at the middle of a joint. 18. Install packer feed thru and cable connectors: After the packer is in place and feed through is installed the round cable should be secured with rope so that it cannot be pulled back over the sheave prior to cutting the cable. The cable should remain secure until after the connection to the packer feed through has been made and a Cannon clamp has been installed at the next tubing collar above the packer. 19. Check the conductivity of the electric cable and downhole gauge readings every 2,000' and every new splice while running in hole. Use a Cannon cable clamp on every other joint on the round cable, use the Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 3 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. C2012 • • PI RECOMMENDED PRACTICES s half 2 -7/8" clamp (2875- C -24P) on the GLM pup. Space out the ESP at the setting depth as per completion diagram. Monitor the trip tank for proper hole fill while running the completion. Notes: • Review and mark on the directional survey areas where the dogleg is more than 6 °. Reduce RIH rate as the ESP assembly passes through these sections. The ESP assembly must be placed in the wellbore at less than 3° /100' DLS to prevent ESP failure. Baker Hughes recommends placing the ESP at less than 2° /100' DLS for optimal performance. • Exercise caution when TIH to avoid sudden starts and stops which may damage ESP cable, especially while setting the slips or spider. 20. Space out the ESP to proposed setting depth as per program. Install the Cable extension on the ESP penetrator. Record the readings using Commissioner during the landing of the tubing hanger, the setting of the packer assembly and the pressure testing of the IA. Land tubing with extreme care to minimize damaging the ESP penetrator, pigtail and alignment pin. Run in lock down screws. Test tubing hanger. A The ESP penetrator can be damaged when the tubing hanger is landed. ND BOPs and NU lock down flange, tubing head adapter, and tree. Pressure test tubing head adapter and tree. Use umbilical cord to continuously check run in hole panel readings until after packer is set. Note: Hold safety meeting with crews to review proper procedure for nippling down the bell nipple. To prevent injuries, it must not be removed by hand. 21. Pull TWC with lubricator. If cost effective, salvage (via circulation) as much of clean brine as possible for next rig workover. To prevent bringing fines into the tubing, do not reverse. Do not exceed 3,000 psi as it may damage the ESP. 22. Freeze protect the well with diesel to 2,000 -ft TVD by circulating (or bullheading if needed) diesel down tubing annulus. Do not exceed 3,000 psi surface pressure. Also bullhead diesel down tubing. Set BPV and close all valves. Note: Calculate the actual volume of diesel for freeze protection based on measured depth corresponding to 2,000 -ft TVD. 23. Make a final check and record ESP conductivity phase to phase and phase to ground for all three phases at the hanger penetrator. Confirm the balanced conductivity by Baker Hughes field representative. 24. Confirm that the Baker Hughes ESP Checklist has been completed. Version 2.1 This document is the property of Baker Hugles and the information contained herein is Page 4 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. 02012 • • RECOMMENDED PRACTICES WES 0 Ensure appropriate checklists are completed. Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 5 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. 02012 • • .r BAICER RECOMMENDED PRACTICES wows 000GURUK ESP CHECKLIST • RUNNING THE ESP ASSEMBLY PART 1 OF 3 • WELL BAKER HUGHES REP (INITIAL ITEMS AS THEY ARE COMPLETED) Confirm spooler operator is qualified to operate spooler. Baker Hughes representative witness final cleanout returns prior to installing ESP. All ESP equipment inspected, serial numbers and models confirmed as being correct and proper for this well prior to rigging up. Safety /planning meeting held with rig crew at beginning of job describing all work and safety procedures to be followed. Confirm the flat/round splice is across the ESP handling pup between two couplings. Review all ESP handling procedures and precautions for moving equipment around location with rig crews. Review all ESP handling procedures and precautions for moving equipment in the pipe shed and up to the floor with rig crew. All cable and equipment visually inspected and approved when TIH. Confirm motor dielectric oil is in new. Confirm gauge is operational and resistivity readings are proper. Check height of motor shaft = ". Verify with gauge CO203410401. Confirm within acceptable limits. Measure shaft extension for upper seal and confirm acceptable. Verify with gauge CO201670101 Shaft Extension = " Acceptable Limits = II Confirm free rotation of ESP unit as a completely assembled unit. Version 2.1 Tlus document rs the property of Baker Hughes and the information contained herein is Page 6 of 9 Running an ESP Completion confidential and may not be distributed, either m part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. © 2012 • • RECOMMENDED PRACTICES MMUS Parts Installed #On Floor # Installed # Remaining Baker Hughes representative will note the location of any installed materials. NOTES • Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 7 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ® 2012 • • RECOMMENDED PRACTICES BAIMES 000GURUK ESP CHECKLIST RUNNING THE ESP ASSEMBLY PART 2 OF 3 WELL BAKER HUGHES REP (INITIAL ITEMS AS THEY ARE COMPLETED) Instruct rig crews on proper banding procedures. Number flat electrical cable clamps run = Number round electrical cable clamps run = Number cable bands run = Phase resistivities checked at the motor pothead and recorded on Baker Hughes running report. Phase resistivities checked after the flat/round splice and recorded on Baker Hughes running report. • Phase resistivities checked every 2,000' minimum while TIH and after each electrical connection. Confirm the ESP setting depth is correct before landing the tubing hanger. Phase resistivities checked before the hanger penetrator pigtail and recorded on Baker Hughes running report. Phase resistivities checked above the hanger and recorded on Baker Hughes running report. Phase resistivities checked when the hanger is landed and recorded on Baker Hughes running report. Final resistivity check after tree is RU and tested, prior to RD. Confirm Baker Hughes running report is completely filled out and is legible. Give this form to PNRA Rig Supervisor when completed. Date: Comments: Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 8 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor communicated to any competitor or potential competitor of Baker Hughes Inc. ©2012 • • RECOMMENDED PRACTICES WES 000GURUK ESP CHECKLIST RUNNING THE ESP ASSEMBLY WELL: Send original of the following reports to Well Files: Baker Hughes running report Baker Hughes Checklist Date: Baker Hughes Rep: Comments: Version 2.1 This document is the property of Baker Hughes and the information contained herein is Page 9 of 9 Running an ESP Completion confidential and may not be distributed, either in part or in whole, nor commumcated to any competitor or potential competitor of Baker Hughes Inc. ©2012 • • INSTALLATION ISSUES ;Category Install Date Problems Cause Lessons Learned/ Solution K - 33 412512008 Flawless Install N-40 Packer Vent Valve 7/25/2008 Cable Armor Damage Damaged POOH for Packer Vent Valve Failure K-41 Clamp, DLS 1/3/2009 MLE Damage (a 2300' Over drift 5.38" pump housing Do not run pump clamps on pumps clamps. Clamp running OD was over 20' 6.23 ". A 5.23 degree dogleg at failure depth. N -31 Clamp, slips 8/18/2009 MLE Damage @ Surface' 5.13" clamps caught in slips Do not catch clamps in slips N -37 Packer, tension 11/30/2009 Packer Connector Parted g Pull from cable caused it to come Change in install procedure to tie off Surface apart. connector N -36 12/2/2009 Flawless Install K -14 Lower Connector? 3/4/2010 Electrical failure before start TBD- suspected connector assembly, Use umbilical cord and test readings up, Rig on different well manufacture or design flaw every 30 min until startup. Do not when problem discovered move rig away from well until ESP is started N -31 (2) 4/5/2010 Flawless Install N -16 Packer 8/3/2010 MLE Damage POOH @ After Packer failure, 5.38" clamps Do not run 5.38" clamps in 7" casing 12000' parted MLE. Clamp running OD was 6.23" N -16 Lower Connector 8/6/2010 Lower WH Connector Improper BIW Lower Connector Recertify technicians with BIW Failure after packer set Assembly Connector N -16 Packer Pentrator, 0-ring 8/10/2010 Packer Connecter Failure i 0-rings cut on lip seal causing leak, Store connectors indoors to avoid 2500' extreme temperature caused Orings extreme temperature changes to dry out and become brittle N -16 Packer Pentrator 8/11/2010 Packer Connector Failure LRi 1000' of cable packer connector Use tarp to cover splicing area to 2500' tested wet. 1 leg of packer lower ensure rain will not disturb making up connector grounded connectors K-41 (2) 8/23/2010 Flawless Install N -17 Cable, GLM 10/21/2010 Cable Failure at Gas Lift Cable was placed on thick side of Procedures for proper GLM cable Mandrel 3987'. DLS 0.58. GLM and was crushed RIH installation sent out. K -33 (2) Clamp 3/24/2011 Lost Comms with DGU Christolizer had been twisted RIH Attempt to limit rotation and attempt to 4000' and parted TEC wire and damaged land mle on upper side of esp in the MLE. Cable put on wrong side of lateral. Put cable on minor OD of GLM. SS bands tom off. GLM's. Do no use SS bands. K -33 (2) ADV 3/24/2011 ADV came unbucked Pins sheared and ADV bucked loose, ADV sent to Pumptools for analysis did not cause damage but had to make up new upper ESP assembly K-41 (3) Lower Connector 4/6/2011 Electrical failure at wellhead Crack in BIW Lower connector PEEK Sent to BIW for manufacture analysis. lower connector @ surface insulator found BIW will change edge curvature to reduce likelihood of crack formation when subject to stress. K-41 (3) Cable, GLM 4/7/2011 Armor Damaged at GLM @ Cable placed on wrong side of GLM Sent out GLM cable installation 6940'. DLS 1.38. procedures ! • INSTALLATION ISSUES Well Category Install Date Problems Cause Lessons Learned/ Solution T-45A 4/13/2011 Flawless Install N -18 5/13/2011 Flawless Install K -13 Clamp 10/7/2011 Christolizer clamp damaged Loose casing joints, clamps missing Use a clamp with a longer profile. ESP assembly bevel. Quality check parts during fit testing. K -13 Clamp 10/7/2011 Lost Comms with DGU Loosened christolizer crimped tech Replace christolizers. Ensure clamps wire. are fastened securely before RIH. In restricted or high dogleg areas, reduce ESP RIH rate. Measure all clamps with OD tape to make sure they are fully tightened and under drift. T-45A (2) Slips 10/9/2012 Air slips damaged cable just ESP cable and the 3 control lines Use hand slips instead of airslips to above the packer were not properly secured when minimize the risk of equipment airslips were engaged. damage. • • OF Th w w �� \ I /%j s� THE STATE Alaska Oil and Gas tLAs ® KA Conservation Commission wR, I GOVERNOR SEAN PARNELL 333 West Seventh Avenue O Q• Anchorage, Alaska 99501 -3572 ALAS U t' 1 1 qfl Main: 907.279.1433 O 1 Ltl Fax: 907.276.7542 SCK Alex Vaughan G Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 0 1S5- 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -14 Sundry Number: 313 -281 Dear Mr. Vaughan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. /4/. Commissioner DATED this/V day of June, 2013. Encl. . STATE OF ALASKA` eSKA OIL AND GAS CONSERVATION COKOSION r\ °A APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ` 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ 1 Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Pioneer Natural Resources Alaska, Inc. Exploratory ❑ Development © ' 209 - 155 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99501 50 703 - 20610 - 00 - 00 t 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA ODSK -14 Will planned perforations require a spacing exception? Yes ❑ No le 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 355036 , Oooguruk - Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ' 13,852' . 6166' 13,767' 6164' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 3518' 11 -3/4" 3557' 2938' 5830 psi 3180 psi Intermediate 1 4452' 9 -5/8" 3401' - 7853' 2852' - 5284' 5750 psi 3090 psi Intermediate 2 10,356' 7" 10,394' 6139' 7240 psi 5410 psi Liner 3537' 4-1/2" 10,232' - 13,769' 6122' - 6164' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 ' See Attachment, pg. 2 3 - 1/2 ", 9.3# L - 80, TSHP/TCII 9921' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): . TRMA O( SSSV; Hyd II Retry Pkr; Liner Top Pkr ,, 2022' MD/1948' TVD; 4839' MD/3637' TVD; 10,243' MD/6124' TVD 12. Attachments: Description Summary of Proposal ©, 13. Well Class after proposed work: Detailed Operations Program le BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development s ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Operations: 6/7/2013 Commencing Oil g p ©• Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan, 343 - 2186 Email alex.vaughan(d Dxd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer Prepared By: Kathy Campoamor, 343 -2183 Signature Phone Date 343 - 2186 6/4/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 OC II % 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: / O - -1 d Ll • y' APPROVED BY a/ Approved b COMMISSIONER THE COMMISSION Date: Submit Form and Form 10 -403 (Revised 10/2012) Approved ap lication is a R i f ei of approval. Attachments in Duplicate RBDMS JUN 11 20 7 6-6-13 -0 .6- 3 -�� ' • 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 June 4 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: ODSK -14 Sundry Application to Punch Tubing REF: Permit To Drill # 209 -155 Pioneer Natural Resources, Alaska (PNRA) is submitting a proposal to perforate the tubing of ODSK -14 to prep well for a forthcoming ESP Workover. The proposed plan is as follows: Pre -Riq Work: 1. RU slickline over ODSK -14 2. Tubing punch 2 -7/8" tubing using 4 spf (45 holes total) from 4,858'- 4,869' MDrkb. 3. Sweep tubing with 1.5 tubing volume filter seawater. 4. Close ScSSSV 5. Install BPV Re- Complete ODSK -14 with ESP 1. (Sundry to recomplete ESP will be provided prior to ESP workover) • Alaska Oil & Gas Conser (ion Commission June 4 2013 Page 2 of 2 Please find attached information for your review: 1) Form 10 -403 Application for Sundry. 2) ODSN -37 Schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) (907) 343 -2186 alex.vaubhan 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343 -2134 Paul. daggettna.pxd. com Sincerely, / Alex Vaughan Senior Drilling Engineer Attachments: Form 10 -403 Supporting information cc: ODSK -14 Well File ODSK* Production Well Co . Ietion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 0 Vent Valves Control Line 16" Conductor 158' MDrkb / 158' TVDrkb P Casing Item # Item MD (ft) TVD (ft) 3-1/2", 9.3# L -80 A 16" Conductor 158 158 TCII or TSHP B 11 -3/4" 60# L-80 Hydril 511, 10.772" ID 3557 2938 C 9-5/8" 40# L-80 Hydril 521, 8.835" ID 7853 5284 D 7" 26# L-80 BTC-M 6.276" ID 10394 6142 9.625" x 11.750" WFRD E 4 12.6# L-80 Hydril 521 (Slotted Liner) 13769 6164 Liner hanger /packer w/ TBS F 3-1/2" 9.3# L-80 TSHP & TCII @ 3422' MDrkb / 3222' G 2 -7/8" 6.5# L-80 IBT-M 9921 6067 TVDrkb n *Estimated 9-5/8" TOC @ 6870' MD J *Estimated 7" TOC @ 9895' MD Hyd 521, 10.772" ID • 4 Upper Completion 11 3/4 ", 60# L -80 H v ■ 0 • Item # Item MDrkb (ft) TV (ft) 3557' MDrkb / 2938' TVDrkb $ { �.,, 1 VetcoGray Tubing Hanger w/ x -o er to 2 -7/8" 34 34 u SLB 2 -7/ TRMA)0F5E 4. " OD, 2.312" X Profile 8 609 0 3 , 13Cr -80 bore w/ 2 -7/8" EUE8RD pin x pin w/ Mod Estimated Top of Cement © 2 Collar L-80 w/ 1/4" x .049" SS control line 2,022 1,948 6870' MD, 500' MD above Top Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ Torok 2 -7/8" IBT pin x pin w/ Mod L 80 Collar (min. 2 jts 0_1 3 above top X nipple) 4,672 3,544 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L-80 EUE8RD 4 Mod Collar (min. 2 jts aboee Gas Vent Valee Packer) 4,754 3,590 WFT 7" x 2 -7/8" Hydrow -II Retry. Pkr f/ Feed Thai ESP 5 (max. TVD 3800) 4,839 3,637 Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ IN 0 ■ 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts 9 -5/8 ", 40# L -80 Hydril 521, 8.835" ID 6 above Xnipple) 8,782 5,761 7853' MDrkb / 5284' TVDrkb 0g0 88 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L-80 EUE8RD 9 Mod Collar w/ RHC-M plug installed (65 deg inc.) 8,867 5,795 10 Automatic Dieert Vale (ADV) 9,816 6,046 ESP (Pump P23, Motor, and Jewelry) (9746 -9935 11 MD<1 °DLS) 9,825 6,048 0 End of Assembly 9,921 6,067 Estimated Top of Cement @ 9895' MD, n 500' MD above 7" shoe MD (ft) TVD (ft) WFT PBR Tie Back Sleeve 15ft 10,232 6,122 WFT "NTH" Liner Top Pkr (7" 23-32# X 5" 15#) 10,243 6,124 WFT "PHR" Rotating Hyd Set Liner Hanger (7" 23-32# X5" 15#) 10,245 6,124 4 -1/2" 12.6# L-80 IBT-Mod Slotted Liner and blank pipe 10,250 6,125 Liner Shoe 13,767 6,164 End of Assembly 13,769 6,164 7 ", 26# L - 80 BTC - M, 6.276" ID 10,394' MDrkb / 6139' TVDrkb 13,852' MDrkb / 6166' TVDrkb Date: Revision By: Comments PIONEER 10/14/2009 jdf Proposed Completions 2/25/2010 jad Lateral extension edit ODSK -14 Producer NATURAL RESOURCES SA _AS JIU1 2/26/2010 vtj Added completion detail Well Schematic NATURAL C U 3/26/2010 jad Final schematic DATA SUBMITTAL COMPLIANCE REPORT 8/15/2012 Permit to Drill 2091550 Well Name /No. 000GURUK KUP ODSK -14 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20610 -00 -00 MD 13852 TVD 6166 Completion Date 3/4/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Logs Run: GYRO, GR, DIR, GABI, EWR, PWD, ABI, ADR, SGR, ALD, CTN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Mid /Frmt Number Name Scale Media No Start Stop CH Received Comments EDW Las 19488 Induction /Resistivity 108 13852 Open 3/24/2010 OH LAS, DLIS EWR Data (PB1 & PB2 included) With PDF CGM, EMF, & TIFF graphics Logy/ Induction /Resistivity 2 Col 158 13852 Open 3/24/2010 MD DGR, EWR, ADR, CTN ALD 1 Log Induction /Resistivity 2 Col 157 6166 Open 3/24/2010 TVD DGR, EWR, ADR, CTN ALD Log • Induction /Resistivity 5 Col 158 13852 Open 3/24/2010 MD DGR, EWR, ADR, CTN ALD Log Induction /Resistivity 5 Col 157 6166 Open 3/24/2010 TVD DGR, EWR, ADR, CTN ALD Log ,/ Induction /Resistivity 2 Col 158 7853 Open 3/24/2010 PB1 MD DGR, EWR Log / Induction /Resistivity 2 Col 157 5280 Open 3/24/2010 PB1 TVD DGR, EWR III Log °' Induction /Resistivity 5 Col 158 7853 Open 3/24/2010 PB1 MD DGR, EWR Log or Induction /Resistivity 5 Col 157 5280 Open 3/24/2010 PB1 TVD DGR, EWR ' Log ----- Induction /Resistivity 2 Col 158 11574 Open 3/24/2010 PB2 MD DGR, EWR, ADR, CTN, ALD Log J Induction /Resistivity 2 Col 157 6177 Open 3/24/2010 PB2 TVD DGR, EWR, ADR, CTN, ALD Log f Induction /Resistivity 5 Col 158 11574 Open 3/24/2010 PB2 MD DGR, EWR, ADR, ` CTN, ALD Log / Induction /Resistivity 5 Col 157 6177 Open 3/24/2010 PB2 TVD DGR, EWR, ADR, CTN, ALD Rpt.,....—.--- Report: Final Well R 0 13582 Open 5/18/2010 Final Well Report, Well Details, Morn Reps, Bit & Mud Reps, Formation Top, Survey Reps, Days /Depth i DATA SUBMITTAL COMPLIANCE REPORT 8/15/2012 Permit to Drill 2091550 Well Name /No. 000GURUK KUP ODSK -14 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20610 -00 -00 MD 13852 TVD 6166 Completion Date 3/4/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N ED C Pdf 19666 Report: Final Well R 0 13852 Open 5/18/2010 Final Well Report, Well Details, Morn Reps, Bit & Mud Reps, Formation Top, Survey Reps, Days /Depth w /3D PDS Mud Logs and PB2 logs Log c . , ,,- Mud Log 2 Col 10400 13852 Open 5/18/2010 MD Engineering Log Log/ Mud Log 2 Col 10400 13852 Open 5/18/2010 MD Gas Ratio Log — Mud Log 2 Col 10400 13852 Open 5/18/2010 MD Combo • Log / Mud Log 5 Col 10400 13852 Open 5/18/2010 MD Combo Log..- Mud Log 2 Col 10400 11574 Open 5/18/2010 PB2 MD Engineering Log Log Mud Log 2 Col 10400 11574 Open 5/18/2010 PB2 MD Gas Ratio Log /' Mud Log 2 Col 10400 11574 Open 5/18/2010 PB2 MD Combo Log — Mud Log 5 Col 10400 11574 Open 5/18/2010 PB2 MD Combo Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttingsf 10400 13852 3/12/2010 1260 Cuttings �/ 10700 11574 3/12/2010 1260 PB 2 ADDITIONAL INFORMATION Well Cored? Y Daily History Received? J Chips Received? 1- 44L .- Formation Tops l • Analysis Y.1.111-- Received? Comments: Compliance Reviewed By: Date: i _ i'1.... i r • • oiT 6 a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brandon Peltier Staff Drilling Engineer 15- Pioneer Natural Resources Alaska, Inc. cc�� 700 G Street, Suite 600 pC Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -14 Sundry Number: 312 -012 Dear Mr. Peltier: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 Daniel T. Seamount, Jr. Chair DATED thisday of January, 2012. Encl. STATE OF ALASKA 1' ` ,fa'V.` I'VE D ALASKA OIL AND GAS CONSERVATION COMMISSION` JAN G $ ?012. APPLICATION FOR SUNDRY APPROVALS � 20 AAC 25.280 - :. 1 : 0- ::: '.°;, ..i UPS 1,CflSJ. Lo�nislIIff 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChatigirApproyEl Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 ' Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Re-Run Tubing & ESP El • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development p Exploratory ❑ 209 -155 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99501 50- 703 - 20610 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No El ODSK - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 Oooguruk - Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,852' • 6166' . 13,767' 6164' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3518' 11 -3/4" 3557' 2938' 5830 psi 3180 psi Intermediate 4452' 9 -5/8" 3401' - 7853' 2852' - 5284' 5750 psi 3090 psi Production 10,356' 7" 10,394' 6139' 7240 psi 5410 psi - Liner 3537' 4 -1/2" 10,232' - 13,769' 6122' - 6164' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 See Attachment, pg. 2 3 -1/2 ", 9.3# L -80, TSHP/TCII 9921' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): TRMAXX SSSV; Hyd II Retry Pkr; Liner Top Pkr 2022' MD/1948' TVD; 4839' MD/3637' TVD; 10,243' MD/6124' TVD 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ig • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 1/16/2012 Commencing Operations: • Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brandon Peltier, 343 -2116 Printed Name Brandon Peltier Title Staff Drilling Engineer Signature ��� - - one 343 -2116 Date 1/3/2012 Prepared By: Kathy Campoamor, 343 -2183 7 -. J - �, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 Z' Ot , Plug Integrity ❑ BOP Test IV Mechanical Integrity Test ❑ Location Clearance ❑ Other: 91`1S®6 Q.St, 56 l 7 - & Subsequent Form Required: /f L1LI • i APPROVED BY I/ I I I Approved by: / COMMISSIONER THE COMMISSION Date: Z nn Form 10 -403 KeYfse §1/2114 13 20 1 • q • �O R I G I N A L Submit in Duplicate � 'ry 1 Pionee r N atu a Resources Alaska Inc. ODSK -14 Page 2 AOGCC Form 10 -403, Application For Sundry Approvals Box #11, Present Well Condition Summary Perforation Depth Attachment 11. Perforation Depth (MD/TVD) 4 -W, 12.6 #, L -80 Slotted Liner: MD TVD 10,251' — 11,206' 6125' — 6149' 11,498' — 12,615' 6145' — 6140' 13,224' — 13,766' 6149' — 6164' 1 • ODSK -14 Production Well Completion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 0 Vent Valves Control Line 16" Conductor A ■ 158' MDrkb / 158' TVDrkb ©� Casing Item # Item MD (ft) TVD (ft) 3 - 1/2 ", 9.3# L - A 16" Conductor 158 158 TCII or TSHP B 11 -3/4" 60# L -80 Hydril 511, 10.772" ID 3557 2938 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID 7853 5283 D 7" 26# L -80 BTC -M 6.276" ID 10394 6139 9.625" x 11.750" WFRD E 4 -1/2" 12.6# L -80 Hydril 521 (Slotted Liner) 13769 6163 Liner hanger /packer w/ TBS ; -. F 3 -1/2" 9.3# L -80 TSHP & TCII 9920 6066 ; © 3422' MDrkb / 3222' G 2 - 7/8" 6.5# L - 80 IBT - TVDrkb ' l °l *Estimated 9 -5/8" TOC @ 6870' MD J *Estimated 7" TOC @ 9895' MD Upper Completion 11 -3/4 ", 60# L -80 Hyd 521, 10.772" ID • 4 � Q • Item # Item MDrkb (ft) TVDrkb (ft) 3557' MDrkb / 2938' TVDrkb $ 1 VetcoGray Tubing Hanger 34 34 Schlumberger 2 -7/8 TRMAXX -5E, 4.609" OD, 2.312" X Profile, 13Cr -80 Bore w/ 2 -7/8" EUE8RD pin x pin w/ Estimated Top of Cement @ 2 Mod Collar L -80 w/ 1/4" x .049" SS control line 2,022 1,942 6870' MD, 500' MD above Top Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ Torok 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts ©J 3 above top X nipple) 4,672 3,538 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 4 Mod Collar (min. 2 jts above Gas Vent Valve Packer) 4,754 3,589 WFT 7" x 2 -7/8" Hydrow -II Retry. Pkr f/ Feed Thru ESP 5 (max. TVD 3800') 4,838 3,637 Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ II 0 M 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts 9 - 5/8 ", 40# L - 80 Hydril 521, 8.835" ID 6 above X nipple) 8,782 5,760 7853' MDrkb / 5283' TVDrkb 8 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 7 Mod Collar w/ RHC -M plug installed (65 deg inc.) 8,867 5,794 8 Automatic Divert Valve (ADV) 9,816 6,045 ESP (Pump P75, Motor, and Jewelry) (9746 -9935 9 MD <1 °DLS) 9,825 6,047 p End of Assembly 9,920 6,872 Estimated Top of Cement @ 9895' MD, Lower Completion 500' MD above 7" shoe Item # Item MD (ft) TVD (ft) WFT PBR Te Back Sleeve 156 10,232 6,121 WFT "NTH" Liner Top Pkr (7" 23 -32# X 5" 15 #) 10,242 6,122 WFT "PHR" Rotating Hyd Set Liner Hanger (7" 23 -32# X 5" 15 #) 10,245 6,123 4 -1/2" 12.6# L -80 IBT -Mod Slotted Liner and blank pipe 10,250 6,123 Liner Shoe 13,767 6,163 End of Assembly 13,769 6,163 7 ", 26# L -80 BTC -M, 6.276" ID 10,394' MDrkb / 6139' TVDrkb 13,852' MDrkb / 6165' TVDrkb Date: Revision By: Comments I' I O N E E R 10/14/2009 jdf Proposed Completions 2/25/2010 jad Lateral extension edit ODSK -14 Producer NATUR I UNiL RESO A S 2/26/2010 vtj Added completion detail Well Schematic RESOURCES U1JIV1 3/26/2010 jad Final schematic 4 ODSK -14 RWO PrOosed - Production WM Completion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 0 Vent Valves Control Line 16" Conductor I ■ 158' MDrkb / 158' TVDrkb © Casing Item # Item MD (ft) TVD (ft) 2 -7/8 ", 6.5ppf, L- A 16" Conductor 158 158 80, IBT -M B 11 -3/4" 60# L -80 Hydril 511, 10.772" ID 3557 2938 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID 7853 5283 D 7" 26# L -80 BTC -M 6.276" ID 10394 6139 9.625" x 11.750" VVFRD E 4 -1/2" 12.6# L -80 Hydril 521 (Slotted Liner) 13769 6163 Liner hanger /packer w/ TBS F 3 -1/2" 9.3# L -80 TSHP & T CII @ 3422' MDrkb / 3222' � G 2-7/8" 6.5# L -80 IBT -M 9920 6066 TVDrkb l3) "Estimated 9 -5/8" TOC @ 6870' MD "Estimated 7" TOC @ 9895' MD J 11 -3/4 ", 60# L -80 Hyd 521, 10.772" I D • ® • 3557' MDrkb / 2938' TVDrkb 1 VetcoGray Tubing Hanger w/ x -over to 2 -7/8" 34 34 c 2 HES ScSSSV - Wellstar 2,022 1,942 Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts Estimated Top of Cement @ 3 above top X nipple) 2,540 estimated 6870' MD, 500' MD above Top HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L-80 EUE8RD Torok ©J 4 Mod Collar (min. 2jts above Gas Vent Valve Packer) 2,620 estimated WFT 7" x 2 -7/8" Hydrow -II Retry. Pkr f/ Feed Thru ESP 5 (max. TVD 3800') 2,700 estimated Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ 2 -7/8" IBT pin x pin w/ Mod L-80 Collar (min. 2 jts 6 below packer) 2,780 estimated II © 0' HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD '// 7 Mod Collar (min. 2 jts below 2nd GLM) 2,860 estimated 9 - 5/8 ", 40# L - Hydril 521, 8.835" ID IWC Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ 7853' MDrkb / 5283' TVDrkb ,v�°J 2 -7/8" IBT pin x pin w/ Mod L-80 Collar (min. 2jts 0 D,. 8 above X nipple) 8,782 5,760 4 ' ." 1 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 9 Mod Collar w/ RHC-M plug installed (65 deg inc.) 8,867 5,794 10 Automatic Divert Valve (ADV) 9,816 6,045 O ESP (Pump P23, Motor, and Jewelry) (9746 -9935 Estimated Top of Cement @ 9895' MD, 11 MD <1 °DLS) 9,825 6,047 500' MD above 7" shoe End of Assembly 9,920 6,872 1 WFT PBR Tie Back Sleeve 158 10 6,121 W FT "NTH" Liner Top Pkr (7" 23 -32# X 5" 15 #) 10,242 6,122 6,123 6,123 6,163 W FT "PHR" Rotating Hyd Set Liner Hanger (7" 23 -32# X 5" 15#) 10 4 - 1/2" 12.6# L - 80 IBT - Mod Slotted Liner and blank pipe 10,250 Liner Shoe 13,767 End of Assembly 13,769 6,163 7 ", 26# L -80 BTC -M, 6.276" ID 10,394' MDrkb / 6139' TVDrkb 13,852' MDrkb / 6165' TVDrkb Date: Revision By: Comments PIONEER 10/14/2009 jdf Proposed Completions ODSK -14 RWO h7IIphI p C ^ ^ 2/25/2010 jad Lateral extension edit ATUR�I RESIIRCESA_ASKA 2/26/2010 vtj Added completion detail Proposed - Producer N Well Schematic 3/26/2010 jad Final schematic 11/17/2011 bjp Draft RWO schematic • • ODSK -14 Proposed Rig Work -over Summary Well background and work -over scope: ODSK -14 was completed in March of 2010 with an ESP completion. The ESP failed immediately and the completion was converted to gas lift. The well has been producing on gas lift since June 2010. Due to gas lift supply constraints, this well must be worked -over to change - out the failed ESP. The current 3.5" ESP completion will be changed to a 2 -7/8" ESP completion. Well Status: 1. 3/4/2010 - Bullhead 140 bbls diesel freeze protect down OA (2150') at 2500 psi. 2. 3/6/2010 - Set packer and pressure test tubing to 3500 psi 3. ESP failed immediately after rig release 4. 6/1/2010 - MITIA Passed to 2150 psi (requirements for production MITIA is 1500psi) 5. 6/4/2010 - Orifice valve set in GLM at 4672' 6. 10/22/11 - producing 664 bopd, 32 bwpd, 848 mscfpd, GL gas at 818 mscfd o BHP: 1460 psi (4.8 ppge @ 5849' tvd) o BHT: -155F Pre Rig: 1. Perform pre -rig check -list tasks (grease valves and test voids). 2. Shut off gas lift support 1 -3 day prior to MIRU of Nabors 19AC. 3. Open PW and vent gas from below packer into IA. Bleed IA and tubing as necessary. 4. Add a second swab valve for e-line and slick -line work. o Set and pull BPV as needed for this work 5. RU E/L and perforate, 10' of the 3.5 ", 9.3# tubing using 4 SPF tubing punches just below the production packer at 4838' MDrkb. o Perform gauge ring run below perforation depth o Note this step may be omitted based on ability to vent gas with the PW 6. RU S/L and pull OV from GLM at 4672' MDrkb. / 7. Fluid pack the IA and tubing with seawater (20NTU) o Circulate annulus volume + tubing volume ( -123 bbls + 41 bbls = 164bb1) down to GLM at 4672' MDrkb at 2 -3 bpm. Record the pump pressure and WHP while pumping. Bullhead as needed. o Should well go on a vacuum during pumping note the bbls away at that point. / 8. RU Slick -line and o Install test plug in x- nipple at 4754' and for testing SSSV and MIT. Remove when testing is completed. o Verify ScSSSV actuation, close and test from below to 1000psi, monitor control line pressure. o MIT TxIA to 2150 psi (3500psi when 4.5" liner hanger was set, only holding 2150 on 6/1/10) 9. Freeze protect TxIA to 2000' with diesel (well may be on vacuum) Page 1 of 3 PIONEER NATO .AL REs'UUR(.'Ei ALASW 10. Monitor WHP and IAP via operator's daily reading schedule until rig moves on location, Prep surface equipment for rig move. Lubricate and bleed trapped gas off the IA as needed. Nabors 19AC Rig Operation: 1. MIRU Nabors 19AC. 2. Monitor TxIAxOA pressures 3. Ensure that the ScSSSV is open. 4. Bleed off pressure and bullhead seawater as needed. Monitor well and ensure static conditions. 5. Install a BPV into the tubing hanger profile. 6. ND swab valve and NU BOP a. Barriers are (a minimum of 2): i. Tubing side 1. BPV in the tubing hanger 2. Closed ScSSSV ii. Annulus 1. Wellhead and tubing hanger (tested during pre -rig) 7. Test BOP's as per standard AOGCC requirements. With low (250 psi) an igh (3500 psi) 5 minutes each. State will need to be notified to witness test. a. Have FOSV available and drifted to 2.25" minimum to ensure a -line cutting tools can pass through I.D. 8. Pull BPV from tubing hanger. a. If trapped pressure is observed below BPV, bullhead KWF 2x tubing volume down - tubing 9. Pull to release packer a. Gas may be present below the packer, so be looking for a gas bubble once the . packer is released. b. Note: If the packer does not pull to release, the contingency plan would be to jet cut the tubing above the packer, pull the tubing, then spear and pull the packer with 4" drill pipe. 10. Pull 3 -1/2" completion string out of the hole filling hole as needed. a. The Echometer is available through OPS to monitor fluid levels in the well as needed. b . Joint with FOSV should be in the mouse hole as a contingency. - 11. PU used 6 1/8" bit, scraper, and 4" DP for clean -out run if the well is not on losses. 12. PU & RIH 2 -7/8 ", 6.5 ppf, L -80, I -BTCM tbg consisting of: a. ESP - P23 b. X nipple w/ RHCM plug body c. Vanoil 2 7/8" GLM - with dummy d. X nipple one joint below packer e. Packer - Hydrow I I Retrievable (set at -2500' MD) f. X nipple one joint above GW Packer g. Vanoil 2 7/8" GLM - w /shear valve for circ in FP '/ h. TRSSV 13. PU LJ w/ Production Tubing Hanger. Page 2 of 3 PIONEER NATURAL RESOURCES ALASI A • • 1 14. Land Tubing Hanger. RILDS for Tubing Hanger. Test both the upper and lower Tubing Hanger body seals to 5000psi. 15. Drop ball and rod down tubing. a. Ensure the tubing is fluid packed prior to dropping the ball and rod. b. Spot corrosion inhibitor c. Monitor SCSSSV control line pressure to ensure adequate hold open pressure during ball drop 16. Pressure set the packer with 3500 psi. 17. Test tubing to 3500 psi for 30 minutes. 18. Pressure test IA to 2500 psi. a. Bleed tubing pressure to 1500psi and maintain less than 2500 pressure differential between TxIA to prevent shearing shear - valve. 19. Shear out shear -valve a. Reverse circulate SW to confirm shear 20. Install BPV with blanking plug and test from above and below. 21. ND BOPE a. Barriers are (a minimum of 2): iii. Tubing side 1. BPV in the tubing hanger .S SS 51/ 2. Ball witl{KWF ) — Flo+ iv. Annulus Lbw- Bar(r�o✓s 1. Wellhead and tubing hanger 22. NU Vetco Swab valve and cap a. Test tree to 5000 psi. Post Rig: 1. Pull BPV w/ blanking plug. 2. Circulate 75 bbls of diesel and allow time for u -tube for TxIA freeze protection to 2000' TVD. 3. MIRU HES Slick -line a. Retrieve ball /rod assy from RHCM plug body b. Install valves in GLM per completion engineer I/ 4. Rig down slickline 5. Function Test TRSSSV Page 3of3 PIONEER NATURAL REa'OUR(ES AL SI 1 PIONEER RECEIVE NATURAL RESOURCES ALASKA mAY fi 2410 Letter of Transmittal Date: May 17, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Mahnken 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Report X Other - logs ❑ Agreement DETAIL QTY DESCRIPTION ODSK- 14 (API: 50- 703 - 20610 -0000) ODSK -14 PB2 (API: 50- 703 - 20610 -7100) JO 4 1 `1 ODSK -35Ai (API: 50- 703 - 20560 -0100) 2 Reports 2 Reports 9 �� ODSK -14 and ODSK -35Ai End of Well O I D - ()la reports 12 Well Logs 12 Well Logs 3- 2" MD Combination Mud Log 3- 2" MD Engineering Log 3- 2" MD Gas Ratio Log 3- 5" MD Combination Mud Log We request that all data be treated as confidential info o . ��Y�t i � 2U IQ Received by: e_g. Date: Please sign and retum one copy to Pioneer Natural Resou Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907 - 343 -2190 fax 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION la. Well Status: � ❑ ❑ Other ❑ ❑ n ❑ WELL COMPLETION OR RECOMPLETION REPORT AND LOG , 1b. Well Class: I° 20AAC 25.105 20AAC 25.110 Development 0 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.: 3/4/2010 209 -155 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number: P82 Anchorage, AK 99501 1/9/2010 50- 703 - 20610 -00 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2955' FSL, 1157' FEL, Sec. 11, T13N, R7E, UM 2/27/2010 ODSK - Top of Productive Horizon: 8. KB (ft above MSL): 56.2' 15. Field/Pool(s): 5077' FSL, 2902' FEL, Sec. 10, T13N, R7E, UM GL (ft above MSL): 13.5' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk - Kuparuk Oil Pool 2454' FSL, 5103' FEL, Sec. 3, 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- 469840.87 y- 6031071.09 Zone -AsP4 13,852' MD / 6166' TVD ADL 355036 TPI: x- 462823.78 y 6033225.18 Zone -Asa 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 460631.23 y- 6035892.46 Zone -AsP4 2022' MD / 1948' TVD 417497 18. Directional Survey: Yes el No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 839' MD / 801' 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: Gyro, GR, DIR, GABI, EWR, PWD, ABI, ADR, SGR, ALD, CTN N/A 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 FT PULLED 16" 109# H -40 Surface 158' Surface 158' 24" Driven 11 -3/4" 60# L - 85 ;YD Surface 3557' Surface 2938' 14 -1/2" 495 sx PF 'L; 260 sx Class 'G' 9 -5/8" 40# L 3401' 7853' 2852' 5284' 12 -1/4" 372 sx Class G' HYD 521 7" 26# L Surface 10,394' Surface 6139' 8 - 1/2" 95 sx Class 'G' BTC - M 4 -1/2" 12.6# L-80 10,232' 13,769' 6122' 6164' 6 -1/8" Uncemented Slotted IBT -M 24. Open to production or injection? Yes j Noll 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) Hydrow II Retry Pkr 3 -1/2 ", 9.3 #, 4839 MD / 3637' TVD; L -80, TSHP/TCII 9921' Liner Top Packer 4-1/2", 12.6 #, L -80 Slotted Liner 10,243'MD / 6124' TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10,251' - 11,206' 6125' - 6149' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11,498' - 12,615' 6145' - 6148' 9921' Freeze protect tubing & annulus w/344 Bbls diesel 13,224' - 13,766' 6149' - 6164' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 3/9/2010 Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 3/9/2010 6 Test Period .-► 531.7 456.8 289.1 3" 860 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 371 237.6 24 -Hour Rate - 2127 1827.3 1156.5 25.1 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 12 Sidewall Cores Acquired? Yes ❑ No el 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 a I D 0 AAC 25.071. COMPLETION L . 4 None MAR , 0 2010 , z; :r pp,&Ga6mss.0 m scion Qp�Ny�� Anthem R PDMS MAR � 1 2011 . Su Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE c ° original only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes -' No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top 868' 867' and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1707' 1668' Top West Sak 2450' 2294' Top Tuffaceous Shale 3458' 2883' None Top Torok 7370' 5025' Base Torok 7798' 5254' Top HRZ 9006' 5847' Base HRZ 9515' 5982' Kalubik 9912' 6065' Top Kuparuk 10,395' 6142' LCU 13,780 6165' Formation at total depth: 13,852' 6166' 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: Very': ns.� Title: Sr. Staff Drilling Engineer 3 /z6 /c6 Signature: Phone: 343 -2111 Date: 3/25/2010 Well Name: ODSK -14 Permit No.: 209 -155 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 1 Operations Summary Report IP NATURAL RESOURCES Well Name: ODSK -14 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 1/8/2010 End Date: Depth Start FooV'Meters Last Mud Stan Date End gate fttKB) (ft) Dens (tb/gal) Summary 1/8/2010 1/9/2010 0.0 8.85 RIH w - '.. 2 004'. MU Tubing Hanger and Landing Jt. La, - • - 'n Multibowl and RILDS. B/O and LD . n. r . . - _ • • _ .. . -r "anger Seals t/ 5000 psi. NU Production Tree. Tes - - . • - - . . ree to 5000 psi. Freeze pr. - - = • - . •a y Rig 11 ODSK -13i t/ ODSI`14. Set all EXIT stairs. Build spill berms under CCU, Cellar and MPD Pump Skid. Connect service lines in PUTZ. NU Starting Head and Drilling Riser. Slip and Cut Drilling Line. Riq accepted ODSK -14 on 01/08/10 @ 00:00 hrs. 1/9/2010 :1/10/2010 158.0 237.00 8.90 Slip 9 Gyro. pipeshed and Cut Drilling Line. RU G ro. Load i shed w/ 11-3/4" casing and 135 Jts 5" DP. PU DP and starufback in derrick. PU 14 -1/2" Clean Out BHA. Clean out 16" Conductor 1/158'. Drill t/233'. Run Gyro. POOH w/ Clean Out 14 -1/2" BHA. PU 14 -1/2" Drilling BHA #1 and RIH 1/233'. Drill f/233' '#1395'. 1/10/2010 1/11/2010 395.0 1,120.00 8.90 Drill 14 -1/2" hole f/395' 0450'. Repair hydraulic leak in CCU. Drill 14 -1/2" hole f/450' t/1,515'. 1/11/2010 1/12/2010 1,515.0 1,550.00 9.00 Drill 14 -1/2" hole f11,515` 1/2,583'. CIO shaker screens due to clay blinding. Drill 14 -1/2" hole ,a3' 1/3.065_,. 1/12/2010 1/13/2010 3,065.0 501.00 9.35 Drill f/3,065' t13,566'. Circulate and condition mud /hole for wiper trip. POOH f/3,566' 1/192', top of Jars. RIH f/192' 1/3,566'. Circulate and condition mud /hole for Surface Casing. POOH f/3,566' 1/1,106'. 1/1312010 1/14/2010 3,566.0 0.00 9.50 POOH f/1,105' 1/632' (BHA). Rack back HWDP and DC. LD remainder of BHA. ND drill riser, remove drilling spacer, install landing ring, and RU fill up tool. RU WFT 11 -3/4" casing equipment and hold pre job safety meeting with all personnel,,RIHyv/ 11 -3/4" 60#.L -80 Hvdri( 1 Surfa - .• .1 • K ' - U and MU 11 -3/4" Casing Hanger, MU 2 piece Landing J1 and land 11 -3/4" Hanger w/ 110k casing weight, shoe depth 3,556.8'. RU cement head and lines. Break circulation utilizing step rate method starting at 1/2 bpm. Increase pump rate in 1/2 bbl increments until 11 bpm established w/ 2600 psi without losses, 1/14/2010 1/15/2010 3,566.0 0.00 9.60 Circulate and cond while having pre -job safety meeting. Test cement lines to 4000 psi. Pump 60 bbls 10.0 ppg Dual Spacer. Pump 375 bbls (495 sx) 10.9 ppq PF 'L' Lead cement, followed by 55.3 bbls (260 sx) 15.8 ppq Class G' Tail cement. Drop Top Cement Plug, pump 20 bbls seawater.Displaced cement w/ 375.6 bbls mud, bump plug w/ 3500 psi, held pressure 30 min on chart - Good test. CIP @ 03:48 hrs. 55 bbls cement returns to surface, floats held. RD cement head and lines and casing elevators. ND Drilling Riser and Starting Flange. Install 5M drilling spool and test same to 5000 psi held 10 min - Good test. NI l all BOPE, RU test equipment and test Annular to 250 psi low / 2500 psi high. Test Upper 2 -7/8" x 5" VBR's, Lower 5" Single Bore � Rams, Blind Rams, Choke and Kill Line HCR's, Choke and Kill Line Manual valves, Floor Safety valve, Dart valve, Upper 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 3000 psi, ` W After Closer 2100 psi, Initial 200 psi recovery 20 sec's, Full recovery 1 min 33 sec's. AOGCC representative Jeff Jones on location to witness test. RD test equipment and blow down test pump and lines. 1/1512010 1/16/2010 3,566.0 260.00 9.80 PU 10 -5/8" BHA #2. Shallow pulse test MWD /LWD, break in Geo -Pilot bearings. TtH 11661' 1/3,432'. Wash down (/3,432' - tag cement at 3,467'. Drill cement and float equipment 113,467' 113,554'. Displace hole to 9.8 ppg LSND mud. Drill casing shoe and clean out rathole (/3,554' 1/3,566'. Drill 1/3,566' t/3,586'. Perform L.O.T. at 3556' and / 2,943' tvd with 9.8 DOD leaked off at 930 psi EMW= 15.8 000 1/3,586' t/3,676'. Drop 1 5/8" ball, pressure up and sheer ball seat at 1400 psi to engage under reamer cutters. Drill 10 -5/8" hole and open same to 11 -3/4" with under reamer V3,676'1/3,826'. 1/16/2010 1/17/2010 3,826.0 420.00 9.80 Drill 1/3,826' t/4246'. MWD lost detection - Trouble shoot same with no success. POOH f/4,246' 1/661'. LD BHA up to the MWD /LWD tools. Plug in and troubleshoot MWD tools - found bad pulser on TM -HOC, changed out same, and upload MWD soft ware files. Shallow pulse test MWD /LWD - Good test. TIH 1/642' 1/4,163'. MWD not working on bottom - Troubleshoot same unsuccessfully. Page 1/6 Report Printed: 3/3W2010 PIONEER Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date End Date (ttKB) (ft) Dens (lb/gal) Summary 1/17/2010 1/18/2010 4,246.0 899.00 9.80 CBU at 4,163'. POOH 1/4,163' to the BHA at 642'. Change out all directional tools on BHA and test same - Good test. TIH f/639' t/3,494', fill pipe and test MWD - Good test. Slip and cut drill line. TIH f13,494' 1/4,246'. Drill f/4,246' V5,145'. 1/18/2010 1/1912010 5,145.0 1,299.00 9.80 Drill f /5,145' 1/6,444` 1/19/2010 1/20/2010 6,444.0 49.00 9.80 CBU at 6,444'. POOH 1/6,444' V BHA. Rack back HWDP, flex collars, plug into MWD tools, and download same. PU new Geo -Pilot and MWD tools for BHA #5 and MU same. Shallow pulse test MWD /LWD - Good test. TIH (/642' 1/6,444'. CBU at 6,444'. Drill f/6,444' 1/6,493'. POOH f/6,493' 113,401'. 1/2012010 1/21/2010 6,493.0 431.00 9.80 POOH f/3,401' 1/642'. Rack back HWDP, flex collars, plug into MWD tools, and download same. Finish laying down remainder of BHA. Function test BOP per AOGCC requirment (ok). PU new bit, mud motor, and MWD tools for BHA #6 and MU same. Upload I)IWD /LWD software files, PU remainder of BHA #6 to 643'. Shallow pulse test MWD /LWD • Good test, TIH f/643 t/6,354'. Wash and ream in the hole 1/6,354' 1/6,493'. Drillpnd slide (16,493' V6,924'. 1/21/2010 1/22/2010 6,924.0 929.00 9.80 Drill and slide 1/6,924' 117,853' (Geologist call Base of Torok @ 7,798'md). Pump 60 bbl hi -vis LCM pill and circulate out same & 2x BU's. POOH (/7,853' V BHA at 643'. Rack back HWDP, LD flex collars, plug into MWD tools, and download same. Finish LD remainder of BHA. 1/2212010 1/23/2010 3,556.0 1,104.00 9.80 MU 10 -518" bit, x-o, stab., Rhino Reamer, (Thread lock all connections below Rhino reamer). MU 8" Spiral DC's & Drig. Jar. RIH w/BHA #7 11568' V3,423'md. RIH w/BHA 117 (/3,423' t/3,585'md, attempt to establish circulation and function Rhino reamer • Packed off. Work pipe free and establish circulation and rotation. Under ream and open hole from 10 -5/8" to 11 -3/4" 1/3,565' V4,660'. CBU at apparent side track. POOH f/4,660' 1/1,805'md. 1/23/2010 1/24/2010 4,660.0 526.00 9.80 POOH f/1,805' V568'md. Rack back HWDP, LD 8" collars, break connections below under reamer. Finish LD remainder of BHA. PU 10 -5/8" BHA #8 and MU same. Upload MWD /LWD software files. PU remainder of BHA to 311'. Shallow pulse test MWD /LWD - Good test. RIH 1/311' 1/4,444'md, CBU while reciprocating 1/4,444' V4,540'. Take "Cassandra" surveys every 30' tp confirm side track point was at 4,550' ,Tag bottom of side track at 4,660'. Drill and slide (/4,660' t/5,186'md (Side track #1). 1/24/2010 1/25/2010 5,186.0 1,868.00 9.80 Drill and slide (/5,186' 1/7,054'. Trouble shoot MWD. POOH 1/7,054' V3,303'. 1/25/2010 1/26/2010 7,054.0 0.00 9.80 POOH f/3,303' 112,827'. CBU at 2,827'. POOH f/2,827' 1/638'. Down load MWD software, and change out MWD pulsar. Upload MWD /LWD software files. PU remainder of BHA to 638'. Shallow pulse test MWD /LWD - Good test. RIH w /BHA f/638' 1/7,014' md, and attempt to establish circulation - packed off. POOH f17,014' 1/3,493' (attempting numerous times to est. circulation on way out). Establish circulation and CBU at 3,493'. RIH f/3,493'md t/3,956'md. Attempt to establish circulation - packed off. POOH f/3,956'md t/3,493'md. Establish circulation and CBU at 3,493'. Ream in the hole f/3,493' 1/3,683'. RIH f/3,683 'md V4,635' md. Establish circulation, stage up pumps using step rate method and CBU at 4,635' with multiple pack off events. 1/26/2010 1/27/2010 7,054.0 809.00 9.80 RIH 1/4,635' 1/5,873'. Est. circulation & stage up. CBU at 5,873'. RIH 1/5,873' t/7,054`. Est. circulation & stage up flow rate. CBU at 7,054'. Drill and slide V7,054'1/7,863'. Pump 50 bbls hi -vis sweep and circulate hole clean with 3x bottoms up strokes. P00111/7,585' V3,493' w/o incidents, Page 2/6 Report Printed: 3/30/2010 'PIONEER III Operations Summary Report • NATURAL RESOURCES pi e Depth Start Foot/Meters Last Mud Staff Date End Date (ftKB) (ft) Dens (ib/gat) Summary 1/27/2010 1/28/2010 7,863.0 0.00 9.90 POOH w/ BHA #9 and LD same. Test Annular to 250 psi low / 2500 psi high. Test Top VBR 2 -7/8" x 5" Rams, Bottom Single Bore 5" Rams, Choke and Kill line NCR's, Choke and Kill line Manual Valves, Upper and Lower IBOP Valves, Floor Safety and Dart Valves and 14 Choke Manifold Valves to 250 psi low / 4500 psi high. All tests held 5 min each and charted. Performed Accumulator Test, System Pressure 3050 psi, After Closure 2100 psi, Initial 200 psi Attained 18 sec's, Final Pressure Attained 1 min 30 sec's. No failures. PU and MU BHA #10. Bull Nose - 3 Pt Rhino Reamer - XO - NM Pony DC - Stab - 2 x DC's - Drlg Jars - 14 x HWDP = 558.54'. RIH 1/3,575'. Function tested Rhino Reamer at 11 -3/4" csg shoe. Ream 11 -3/4" hole f/3,566' t/4,660'. Open 10 -5/8" Intermediate Hole to 11 -3/4" f/4,660' t/5,474'. AOGCC representative Mr. Lou Grimaldi waived witness of BOPE test. 1/28/2010 1/29/2010 7,863.0 0.00 9.85 Open 10 -5/8" Intermediate Hole Section to 11 -3/4" (/5,474' t/7,853'. Circulate and condition mud for wiper trip to 11 -3/4" shoe at 3,556'. 1/29/2010 1/30/2010 7,863.0 0.00 10.00 Circulate and condition hole /mud for wiper trip. POOH f/7,790' 1/3,556'. CBU. RIH f/3,556' 1/7,863'. Circulate and condition hole /mud for 9 -5/8" casing. POOH f/7,863' 1/2,271'. 1/30/2010 1/31/2010 7,863.0 0.00 10.00 POOH and LLD BHA #10. Set BOPE test plug. Change Top Rants from VBR's to 9-5/8". Test Annular to 250 psi low /2500 psi high, 9 -5/8" Rams to 250 psi low /4500 psi high. All test held 5 min each and charted. RU Casing Power Tongs and handling equipment. RIH w/ 9-5/8" 40# L -80 Hydril 521 casing t/161'. Fill casing and check floats, floats held. RIH w/ 9 -5/8" Casing 1/161' t/638'. 1/31/2010 2/1/2010 7,863.0 0.00 10.00 RIH w/ 9 -5/8" 40# L -80 Hydril 521 Drilling Liner 1/ 4,422'. PU & MU WFT Hgr /Pkr/Tie Back Sleeve assembly. RIH w/ Liner on 5" DP f/4,422' 1/6,759'. NOTE: Notified AOGCC of BOPE test to be performed on 2/1/10. Lou Grimaldi waived witness of test on 1/31/10. 2/1/2010 2/2/2010 7,863.0 0.00 10.00 RIH w/ 9-5/8" 40# L-80 Hydril 521 Drilling Liner on 5" DP and set at 7,853'. MU Cement and connect cement lines. Circulate at 4 bpm/700 psi. Drop Hgr Setting Ball and pump on seat. Pressure up to 2000 psi, observed Hgr slips release at 1400 psi. Set 100k down and set Hgr slips. 1 -• • ess r- i E.e • i 1 cr-m -n .ndsh- -r -tti ::II $$ psi. Rotate DP 5 rds to right and release setting tool. PU to 160k to verify setting tool release, lost 130k string weight. Circulate and condition hole /mud bringing rate up to 10 bpm w/ 2650 psi FCP. Pump 10 bbis water. Test cement lines to 4000 psi. Pump 60 bbls 12.5 ppg Dual Spacer (1.13 CuFt/Sx) at 5 bpm /600 psi Pump 77.1 bbls 15.8 ppg Premium "G" cement (1.18 CuFUSk, 372 sx) at 5 bpm /1700 psi, (additives = .75% HALAD -344, .20% CFR-3, .25% Super CBL and .35% SCR -100). Drop DP Wiper Plug, observed tattletail activate. Pump 20 bbls water at 4.5 bpm/900 psi. Switch to rig and displace at 9.3 bpm with 10,0 ppg LSND mud. Slowed pumps down to 2 bpm to latch up DP Wiper Dart with 9 -5/8" wiper plug, Did Not observe latch up. Increased pump rate back to 9.3 bpm/ 2400 psi. At 4,200 stks away slowed pumps to 2.5 bpm. Pumped Pluq w/ 4,275 stks (361.7 bbisl.,,Pressure up to 3500 psi, held 5 min. Released pressure and checked floats, floats held: PU 12' (PUW 160k) to expose Pkr Setting Dogs. Set Down 80k to set Pkr, repeated process 3 times. Verified Pkr set with 50k set down weight and rotated 5 rds w/ 8k torque to mechanically set Pkr. PU and remove packoff from Tie Back Sleeve. CJP 11:37 hrs. CBIJ. POOH w/ Liner Running Tool. V, j...) 11 Remove VG Intermediate 1 QDC (Quick Drilling Connector) Wellhead. AOGCC representative Bob Noble waived witness of BOPE test to be performed on 2/2/10. Page 3/6 Report Printed: 3/30/2010 P I ON E E R S Operations Summary Report • NATURAL RESOURCES Depth Start Foot/Meters Last Mud Start Date - End Date {111(8) {ft) Dens (Ib /gal) Summate, 2/2/2010 2/3/2010 7,863.0 0.00 10.10 Installed Multibowl Wellhead and tested to 250/5000 psi. NU BOPE's. C/O Upper Rams f/ 9 -5/8" t/ 2 -7/8" x 5" VBR's ,,RU MPD Rotating Head Assy and test to 250/4500 psi. Install Trip Nipple. Test Annular to 250/2500 psi. Test Upper 2 -7/8" x 5" VBR's, Lower 5" Single Bore Rams, HCR Kill land Choke line valves, Manual Kill and Choke line valves, 14 Choke Manifold Valves, Floor Dart and Safety valves, Upper and Lower IBOP valves to 250/4500 psi. All tests held 5 min d chartat Syere , rfter Closure 2050 each an psi, Initial 200 ed. Accumul psi attained tor 22 test; sec Ini , Full st Pressure m Pressu attained 3050 1 min psi 37 Pressu sec's. e A Unibolt connection on Kill line leaked, tightened and retested, good test. Remove Test Plug and install Wear Ring. Pressure test 11 -3/4" casing x 9 -5/8" liner to 3500 psi for 30 min, charted same. RIH w/ 8 -1/2" SSRS BHA #11. Shallow pulse test MWD, good pulse. RIH w/ BHA #11 picking up 5" DP from pipeshed & derrick 113,877'. Break in Geo -Pilot and test MWD. 2/3/2010 2/4/2010 7,863.0 515,00 10.00 RIH 1/3,877' 1/7,729'. Drill/Clean Out 9-5/8" Shoe Track, Cement + Rat Hole f/7,729' t/7,863'. Drill 1/7,863' V7,883. Displaced wellbore w/ new 10.0 ppg LSND mud,, Perform FIT 1/ 13 -5 prig EMW. Drill 8-1/2` hole 1/7,883' 1/8,378' maintaining 12.5ppg ECD w/ MPD, 2/4/2010 2/5/2010 8,378.0 917.00 10.00 Replace swab and liner in #2 rig pump. Drill 8 -1/2" hole f/8,378' 119,295' maintaining 12.5ppg ECD w/ MPD. 2/5/2010 2/6/2010 9,295.0 46.00 10.00 Drill 8 -1/2" hole 1/9,295' 1/9,339' maintaining 12,50Da ECD w/ 1,!PD. Circulated 30 bbl Walnut sweep around. Drill 1 /9,339' 1/9,341' maintaining 12.5ppg ECD w/ MPD. POOH f/9,341' due to high Stick Slip, high downhole vibration and low ROP. POOH t/2,950`. Spot 50 bbl Hi -Vis pill 1 /2,950 112,500'. POOH t/2,500'. Spot 230 bbl 17.5 ppg pill 1/2,500' 1/300'. Remove RCD and install Trip Nipple. Slip and Cut Drilling Line. POOH 1/2,500' 11546'. POOH & LD BHA #11. 2/6/2010 2/7/2010 9,341.0 164.00 10.00 POOH & LD BHA #11. PU BHA #12 and RIH 1184'. Download MWD program. RIH w/ BHA #12 11272'. Shallow test MWD, good pulse. RIH f/272' 112,450'. Remove Trip Nipple and install MPD RCD. Circulate out 17.5 ppg pill. RIH 1/2,450' 1/7,685'. Circulate and test MWD and Geo - Pilot. RIH (/7,865' 118,990'. Wash and Ream 1/8,990' 119,341'. Drill f/9,341' 119,505' maintaining 12.5ppg ECD w/ MPD. 2/7/2010 2/8/2010 9,505.0 140.00 10.10 Drill f/9,505' 1/9,645' maintaining 12.4ppg ECD w/ MPD. Lost MWD signal. Troubleshoot MWD issues. Unable to re-establish MWD signal. P0011 1/9,645' t/4,735'. Pump 100 bbls 12,2 ppg Hi -Vis spacer. POOH 1/3,370'. Pump 230 bbls 17,5 ppg pill. POOH 1/547'. POOH w/ BHA #12 1/84'. Download MWD data. C/O bad Pulser and replaced Telemetry Module in TM HOC. RIH w/ BHA #13 1/84'. Download MWD program. RIM w/ BHA #131/180'. 2/8/2010 2/9/2010 9,645.0 229.00 10.20 RIH w/ BHA #13 11547'. Pulse Test MWD, good pulse. RIH 114,817'. Remove Trip Nipple and install RCD. Circulate out Kill Pill and Hi -Vis spacer. RIH 119,303'. Ream f/9,303' 1/9,645'. Drill f/9,645' 119,874' maintaining 13.0ppg ECD w/ MPD. 2/9/2010 2/10/2010 9,874.0 526.00 10.20 Dr1111 /9 -874' 1/10.400' maintaining 13,0opg ECp w/ MPD. Lost partial returns. Lost 59 bbls while circulating. Static losses at 12 bph. Mix and pump 20 bbls LCM pill at 70 #/bbl, spot 1/10,350' V10,065'. Lost MPD Hyd unit. P00111/10,400' 1/7,781', 2/10/2010 2/11/2010 10,400.0 0.00 12.70 Circulate at 7,781' while replacing electric motor on MPD HPU. RIH 1110,344'. Ream f/10,344' 1110,390'. Circulate 50 bbl 12.0 ppg Hi -Vis sweep around. Circulate and weight up mud f/ 10.2 ppg -1112.7 ppg. 2/11/2010 2/12/2010 10,400.0 0.00 13.00 Circulate and weight up total mud system to 13.0 ppg. Spot LCM pill on bottom. POOH w/ BHA #131/277'. POOH & LD BHA. Change top rams U 7 ". Remove VG Wear Ring and install BORE test plug. 2/12/2010 2/13/2010 10,400.0 0.00 13.00 Test Annular 250/2500 psi and To Pipe Rams 250/4500 psi for 7" Casino, RU Casing Running Equipment and Run 230 of 254 total joints of 7" 26# L80 Mod -Btrc Casing to 9349' and while utilizing Auto Fill Float Equipment. Page 4/6 Report Printed: 3/30/2010 PIONEER a Operations Summary Report NATURAL RESOURCES Depth Start Foot/Meters ' Last Mud Start Date End Date fttKB) ('b) Dens (tb/gah Summary 2/13/2010 2/14/2010 10,400.0 0.00 11.00 RIH w/ 7" 26# L -80 BTC -M Csg & VG Hgr and land at 10,395'. MU Cement Head. Displace 12.0 ppg mud w/ 11.0 ppg mud. Pump 10 bbls seawater. Test cement lines to 4000 psi. Drop 1st plug, load Top Plug. Pump 55 bbls 13.0 ppg Dual Spacer. Drop 2nd Plug. Pump 20 bbls (95 sks) 15.8 ppq Premium "G" cement w/ .75% Naiad 344 3K% SCR-100 25% Super (:RI and .2% CFR -3. Drop Top Plug. Pump 20 bbls seawater. Switch to Rig and displace with 11.0 ppg mud at 4 -5 bpm. With Spacer at shoe increased pump rate to 6 bpm. Continued to pump at 6 bpm until 6 bbls cement out the shoe. At 4,325 stks slowed pumps to 3 bpm. Bumped plug w/ 4,510 stks. CIP @ 1610 hrs. Full returns through out displacemenj,Pressure up to 3500 psi and held 30 min. Bled down pressure and got back 5.4 bbls. Cement and casing equipment. Install 7" Pack -Off and test seals to 5000 psi for 10 min. LD 54 Jts 5" DP from derrick. Remove excess casing handling tools and equipment from rig floor. Stage Upper, Lower IBOP's and Hyd Actuator on rig floor. NOTE Notified AOGCC on 2/12/10 of BOPE test due to be performed on 2/14/20. 2/14/2010 2/15/2010 10,4010 0.00 11.00 C/O 5" Upper JBOP w/ Actuator and Lower IBOP with 4 ". 1/0 5" DP from derrick. Change Upper • " o _ -7/8" x 5" VBR's and Lower Rams from 5" to 4 ". Test Annular to 250/2500 psi. Test Upper 2 -718" x 5" VBR's, Lower 4" Single Bore Rams, HCR Kill land Choke line valves, Manual Kill and Choke line valves, 14 Choke Manifold Valves, Floor Dart and Safety valves, Upper and Lower IBOP valves to 250/4500 psi. All tests held 5 min each and charted. Accumulator test; Initial System Pressure 3050 psi, Pressure After Closure 2050 psi, Initial 200 psi attained 22 secs, Full Pressure attained 1 min 39 sec's, Slip and Cut Drilling Line. RIH 1,728'. NOTE; AOGCC representative Chuck Scheve contacted at 0710 hrs on 2/13/10 and waived witness of BOPE test at 1030 hrs on 2/14/10. 2/15/2010 2/16/2010 10,400.0 0.00 11.00 RIH picking up 4" DP 1/8,394'. Circulate and flush DP. POOH w/ 4" and stand back in derrick. PU 6 -1/8" RS BHA #14. Perform communication test on MWD tools, ADR failed. Replaced ADR and retest, good communications through out BHA. Download MWD program. RIH w/ BHA #14 1/208'. Install DP screen to flush HWDP. 2/16/2010 2/17/2010 10,400.0 113.00' 8.70 Finish PU BHA and RIH. grill Float Collar and cement 1/10,383'. Change out mud to 8,6 ppg and install RCD. Drill float shoe and formation t/10,410'.,Perform FIT to 12.5 ppq EMW. Drill 1/10,513' and begin Static Formation Pressure Test. 2/17/2010 2/18/2010 10,513.0 694.00 8.70 Complete Formation Pressure Test to 8.8 ppg EMW. Drill (/10,513' 1/11,207' maintaining 11.5ppg ECD w/ MPD. Difficulties in siderite streaks and sloughing shales. Increased EMW to 11.5 ppg with MPD for shale control. Experienced multiple MWD tool failures. POOH to 7 "casing and displace to 10.2 ppg trip brine. 2/18/2010 2/19/2010 11,207.0 0.00 8.80 POOH for MWD failure. PU BHA # 15 and RIH 2/19/2010 2/20/2010 11,207.0 367.00 8.80 MAD pass log in hole 1/11,185'md. Wash & Ream f/11,185' 1/11,207'md & increase to 11.0ppg EMW w /MPD. Drill PB -2, f/11,207' 1/11,574', (TD in LCU fm.). Circulate bottoms up 2x and POOH for geologic side track C 10,726'md. rp 2/20/2010 2/21/2010 11,574.0 - 829.00 8.70 Time drill for sidetrack 1/10.706" 1/10,746'. (from 5min/inch -1 min/inch rates). Trouble sho fo for apparent drill pipe wash out. 2/21/2010 2/22/2010 10,745.0 0.00 8.70 Trouble shoot drill pipe washout. Pull to 7" casing and displace to 10.2 ppg trip brine. POOH looking for washout.Tound washout in drilling iar, (LD Jar & lx HWDP). Finish laying dopwn rest of non required MWD /Geo Pilot equipment. Clear & clean floor & function test BOPE per AOGCC requirements. Start to make up new BHA and found mud motor rotor catcher missing. Wait on replacement motor from Deadhorse. Page 5/6 Report Printed: 3/30/2010 PIONEER O perations Summary Report • NATURAL RESOURCES Depth Start Foot/Meters l Last Mud Start Date End Date MKS) (ft) Dens (tbigai) Summary 2/22/2010 2/23/2010 10,746.0 148.00 8.70 Wait on Directional tools. MU BHA #16 and RIH. Establish MPD @ 10.0ppg EMW while displacing 10.2ppg brine with 8.7ppg mud @ 10,288'md. Wash 1/10,746' and orient 165R for Side track. Silde drill 1/10,765' and rotary drill 1/10,874' per Well Plan #5, w /start of KOP 10,726'md. 2/23/2010 2/24/2010 10,894.0 706.00 8.70 Directional drill 6-1/8" Lateral Hole Section 1/10,894' 1/11,600' maintaining t0.1ppg ECD wi MPD per WP #05 & Geology requests. 2/24/2010 2/25/2010 11,600.0 858.00 8.80 Drill 6 -1/8" Lateral Hole Section f/11,600' 1/12,458' maintaining 10.2ppg ECD w/ MPD. 2/25/2010 2/26/2010 12,458.0 445.00 8.75 Drill 6.1/8" Lateral Hole Section f/12,458' 1/12,631. Circulated bottom up sample. Drill f/12,631' 1/12,903' maintaining 10.2ppg ECD w/ MPD. 2/26/2010 2/27/2010 12,903.0 582.00 8.80 Directional Drill 6 -1/8" Lateral Hole Section f/12,903' 1/13,485' maintaining 10.2ppg ECD w/ MPD. 2/27/2010 2/28/2010 13,485.0 367.00 8.70 Directional Drill 6 -118" Lateral Hole Section f/13,485' 1/13,852' maintaining 10.2ppg ECD w/ MPD. Circulate 3 x BU. POOH f/13,852' 1/11,087'. Notified AOGCC on 02/26/10 0 1200 hrs of BOPE test to be performed on 02/28/10. Discussed test with AOGGC representatives Jeff Jones and John Crisp. Will give update when closer to test. 2/28/2010 3/1/2010 13,852.0 0.00 10.20 POOH (/11,087' 1/10,315'. RIH 1/13,402'. Wash and ream f113,402' 1113,852'. Circulate and spot new 8.7 ppg Quik -n -Drill mud in open hole. POOH 1/10,095', Spot 25 bbl Hi -Vis spacer out the bit w/ 10.2 ppg Brine. POOH 1/9,543'. Displace 8.8 ppg mud with 10.2 ppg Brine. Remove RCD and install Trip Nipple. POOH U 378'. LD BHA #16. AOGCC representative John Crisp waived witness of BOPE test at 11:45 hrs on 02/28/10. 3/1/2010 3/2/2010 13,852.0 0.00 10.20 POOH LD BHA #16. Remove Wear Ring and install Test PlugTestAnnular to 250/2500 psi, Test Upper 2 -7/8" x 5" VBR's, Lower 4" Single Bore Rams, Kiti & Choke line HCR valves, Kill & Choke Line Manual valves, 14 Choke Manifold valves, Floor & Dart Safety valves, Upper & Lower IBOP`s to 250/4500 psi. Lower IBOP failed, C/O and re- tested. All low/high tests held 5 min and charted. Accumulator Test; System Pressure 3000 psi, Pressure After Closure 2000 psi, Initial 200 psi attained 16 seconds, Full Pressure attained 1 min 36 seconds. Remove 4' Test Jt and install 4 -1/2" Test Jt. Test Upper VBR's to 250/4500 psi, both tests held 5 min each and charted. Remove Test Plug and install Wear Ring. RIH w/ 4-1/2' 12.6# 1-80 Slotted /Solid Production Liner on 4" DP 1110,334'. Circulate DP volume 0 3 bpm. RIH w/ 4 -1/2" Liner 1/13,384'. 3/2/2010 3/3/2010 13,852.0 0.00 9.50 RIH w/ 4 -1/2" 12.6# L -80 Production Liner f/13,384' 1/13,768'. Drop WFT 1 -3/4" Hanger Setting Ball. Pump on seat at 1 bpm. Set Hanger and Packer. Pressure up on backside to 3500 psi to test Packer, held pressure 30 min and charted same. Displace 10.2 ppg Brine with 9.5 ppg Brine. POOH w/ Liner Running Tool. PU Test Jt and install Test Plug. C/O Lower f /4" U 3 -1/2 ". Test Annular w/ 2 -7/8" Test Jt to 250/2500 psi and VBR's to 250/4500 psi. Remove 2 -7/8" Test Jt and install 3 -1/2" Test Jt. Test Lower 3 -1/2" Solid Bore Rams and VBR's to 250/4500 psi. All tests held 5 min each and charted. RU and RIH w/ ESP Pump Assy. 3/3/2010 3/4/2010 13,852.0 0,00 9.50 RIH w/ ESP Pump Assy and 3 -1/2" 9.3# 1-80 Completion Tubing 115,255'. 3/4/2010 3/5/2010 13,852.0 0.00 9.50 RIH w/ 3 -1/2" ESP Completion Tubing as per tally 1/9,886'. MU Tubing Hanger and land same w/ ESP Pump Assy set at 9,921'. RILDS & Test Hanger seals to 5000 psi. RD MPD. Rig released from ODSK -14 on 03/04/10 @ 24:00 hrs. 3/5/2010 3/6/2010 13,852.0 0.00 9.50 Page 6/6 Report Printed: 3/30/2010 ODSK- 1roduction Well Com etion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 0 Vent Valves Control Line 16" Conductor I ■ 158' MDrkb / 158' TVDrkb ► ©� Casing Item # Item MD (ft) TVD (ft) 3 - 1/2 ", 9.3# L - — A 16" Conductor 158 158 TCII or TSHP B 11 -3/4" 60# L -80 Hydril 511, 10.772" ID 3557 2938 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID 7853 5283 D 7" 26# L -80 BTC -M 6.276" ID 10394 6139 9.625" x 11.750" WEIRD E 4 -1/2" 12.6# L -80 Hydril 521 (Slotted Liner) 13769 6163 Liner hanger /packer w/ TBS F 3 -1/2" 9.3# L -80 TSHP & TCII 9920 6066 @ 3422' MDrkb / 3222' /�� G 2 -7/8" 6.5# L -80 IBT -M TVDrkb l�J *Estimated 9-5/8" TOC @ 6870' MD J *Estimated 7" TOC @ 9895' MD Upper Completion 11 - 3/4 ", 60# L - Hyd 521, 10.772" ID . 0 • Item # Item MDrkb (ft) TVDrkb (ft) 3557' MDrkb / 2938' TVDrkb Cr. 1 VetcoGray Tubing Hanger 34 34 Schlumberger 2 -7/8 TRMAXX 5E, 4.609" OD, 2.312" X Profile, 13Cr -80 Bore w/ 2 -7/8" EUE8RD pin x pin w/ Estimated Top of Cement @ 2 Mod Collar L -80 w/ 1/4" x .049" SS control line 2,022 1,942 6870' MD, 500' MD above Top Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ Torok 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts 0_.1 3 above top X nipple) 4,672 3,538 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 4 Mod Collar (min. 2 jts above Gas Vent Valve Packer) 4,754 3,589 WFT 7" x 2 -7/8" Hydrow -II Retry. Pkr f/ Feed Thru ESP 5 (max. TVD 3800') 4,838 3,637 Vanoil GLM 2 -7/8" x 1 -1/2" FO -2 w/ 1 -1/2" Dummy w/ IN 0 I 2 -7/8" IBT pin x pin w/ Mod L -80 Collar (min. 2 jts 9 - 5/8 ", 40# L - 80 Hydril 521, 8.835" ID 6 above X nipple) 8,782 5,760 7853' MDrkb / 5283' TVDrkb 8 HES 2.313" X Nipple 9 Chr w/ 2 -7/8" L -80 EUE8RD 7 Mod Collar w/ RHC -M plug installed (65 deg inc.) 8,867 5,794 8 Automatic Divert Valve (ADV) 9,816 6,045 ESP (Pump P75, Motor, and Jewelry) (9746 -9935 9 MD <1 °DLS) 9,825 6,047 O End of Assembly 9,920 6,872 Estimated Top of Cement @ 9895' MD, Lower Completion 500' MD above 7" shoe Item # Item MD (ft) TVD (ft) WFT PBR Tie Back Sleeve 15ft 10,232 6,121 WFT "NTH" Liner Top Pkr (7" 23 -32# X5" 15 #) 10,242 6,122 WFT "PHR" Rotating Hyd Set Liner Hanger (7" 23 -32# X5" 15 #) 10,245 6,123 4 -1/2" 12.6# L -80 IBT -Mod Slotted Liner and blank pipe 10,250 6,123 Liner Shoe 13,767 6,163 End of Assembly 13,769 6,163 7 ", 26# L -80 BTC -M, 6.276" ID 10,394' MDrkb / 6139' TVDrkb 13,852' MDrkb / 6165' TVDrkb /� Date: Revision By: Comments n IJ I 1 1 10/14/2009 jdf Proposed Completions 11 IVI 2/25/2010 jad Lateral extension edit ODSK -14 Producer NA T U RA RE SOIIRCESA ,A 2/26/2010 vtj Added completion detail Well Schematic 9 UNiI J U 3/26/2010 jad Final schematic S • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -00 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Drilling Services 0 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co -ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB 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 I Well ODSK -14 - Slot ODS -14 Well Position +N/-S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK -14 • Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 1/7/2008 22.87 80.81 57,678 Design ODSK -14 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,726.00 Vertical Section: Depth From (ND) +N/-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 Survey Program Date 3/4/2010 From To (ft) (ft) Survey (Weilbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1 Kup SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4,740.90 10,669.40 ODSK -14 PB2 MWD (ODSK -14 PB2 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1: 10,726.00 13,820.93 ODSK -14 MWD (ODSK -14) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 2/20/2010 1: Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +0-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 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED ■ 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro -SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro -SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro -SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro -SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro -SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro -SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro -SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro -SS (1) 3/4/2010 3:18:37PM Page 2 COMPASS 2003.16 Build 428 ! • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1•001 (ft) Survey Tool Name 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro -SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro -SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 -417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 -492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3/4/2010 3:18:37PM Page 3 COMPASS 2003.16 Build 42B • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD+ I FR2+MS+sag (2) 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,660.00 56.62 281.79 3,537.21 3,481.01 497.65 - 2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 4,740.95 55.40 279.20 3,582.47 3,526.27 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag (3) 4,836.40 54.98 280.65 3,637.02 3,580.82 523.93 - 2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 4,879.42 55.71 280.39 3,661.48 3,605.28 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 - 2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 - 2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 - 2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 - 2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 - 2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) 5,450.50 56.87 281.90 3,966.96 3,910.76 614.98 - 3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) 5,546.29 56.76 281.72 4,019.39 3,963.19 631.39 - 3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 5,641.35 56.95 279.09 4,071.38 4,015.18 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031,743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 3/4/2010 3:18:37PM Page 4 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 - 3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag (3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 - 3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 - 4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 - 4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) 6,878.72 56.92 279.21 4,758.80 4,702.60 803.14 - 4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) 6,974.00 57.33 278.74 4,810.52 4,754.32 815.62 - 4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 7,070.69 58.44 280.02 4,861.92 4,805.72 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) 7,164.65 57.01 278.08 4,912.10 4,855.90 841.48 - 4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) 7,259.49 56.57 276.96 4,964.04 4,907.84 851.87 - 4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 7,354.90 56.92 277.34 5,016.36 4,960.16 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) 7,451.12 57.52 279.93 5,068.46 5,012.26 873.95 - 4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) 7,545.34 57.71 279.62 5,118.93 5,062.73 887.46 - 4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 7,640.14 57.14 280.28 5,169.97 5,113.77 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 - 4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) 7,819.80 57.61 281.36 5,265.98 5,209.78 929.54 - 5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 7,892.32 58.60 282.43 5,304.29 5,248.09 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 - 5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032,114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032,154.95 464,244.87 2.51 5,576.60 MWD+ I FR2+MS+sag (3) 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032,242.53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032,318.39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032,362.71 463,771.84 2.61 6,093.25 MWD+ I FR2+MS+sag (3) 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD +IFR2 +MS +sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 3/4/2010 3:18:37PM Page 5 COMPASS 2003.16 Build 428 S Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB 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 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD+ I FR2+MS+sag (3) 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6 ,032 ,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD+ I FR2+MS+sag (3) 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) 10,726.00 92.79 316.72 6,148.20 6,092.00 2,370.07 - 7,249.21 6,033,470.31 462,602.06 1.98 7,602.30 MWD +IFR2 +MS +sag (4) 10,766.12 90.31 317.66 6,147.12 6,090.92 2,399.48 - 7,276.47 6,033,499.83 462,574.93 6.61 7,638.79 MWD +IFR2 +MS +sag (4) 10,797.83 89.47 317.75 6,147.18 6,090.98 2,422.94 - 7,297.80 6,033,523.37 462,553.69 2.66 7,667.53 MWD +IFR2 +MS +sag (4) 10,830.72 88.97 316.86 6,147.63 6,091.43 2,447.11 - 7,320.11 6,033,547.63 462,531.49 3.10 7,697.43 MWD +IFR2 +MS +sag (4) 10,853.73 89.33 317.61 6,147.97 6,091.77 2,464.00 - 7,335.73 6,033,564.58 462,515.94 3.62 7,718.36 MWD +IFR2 +MS +sag (4) 10,895.73 91.42 319.05 6,147.69 6,091.49 2,495.37 - 7,363.65 6,033,596.06 462,488.15 6.04 7,756.22 MWD +IFR2 +MS +sag (4) 10,928.96 89.36 317.27 6,147.47 6,091.27 2,520.13 - 7,385.81 6,033,620.90 462,466.09 8.19 7,786.22 MWD +IFR2 +MS +sag (4) 10,958.52 88.95 316.64 6,147.90 6,091.70 2,541.73 - 7,405.99 6,033,642.58 462,446.00 2.54 7,813.17 MWD + IFR2 +MS +sag (4) 10,991.76 89.68 316.41 6,148.30 6,092.10 2,565.85 - 7,428.85 6,033,666.79 462,423.24 2.30 7,843.57 MWD +IFR2 +MS +sag (4) 11,024.17 91.03 318.21 6,148.10 6,091.90 2,589.67 - 7,450.83 6,033,690.70 462,401.36 6.94 7,873.04 MWD +IFR2 +MS +sag (4) 11,055.41 89.88 318.65 6,147.85 6,091.65 2,613.04 - 7,471.55 6,033,714.15 462,380.73 3.94 7,901.18 MWD +IFR2 +MS +sag (4) 11,088.59 89.44 320.28 6,148.05 6,091.85 2,638.25 - 7,493.12 6,033,739.45 462,359.27 5.09 7,930.80 MWD+I FR2 +MS+sag (4) 11,120.48 89.88 321.08 6,148.24 6,092.04 2,662.92 - 7,513.32 6,033,764.20 462,339.17 2.86 7,958.96 MWD +IFR2 +MS +sag (4) 11,151.77 89.91 321.48 6,148.30 6,092.10 2,687.33 - 7,532.90 6,033,788.69 462,319.70 1.28 7,986.44 MW D+I FR2 +MS+sag (4) 11,201.20 89.31 323.11 6,148.63 6,092.43 2,726.44 - 7,563.13 6,033,827.91 462,289.63 3.51 8,029.42 MWD +IFR2 +MS +sag (4) 11,248.49 89.27 323.35 6,149.22 6,093.02 2,764.32 - 7,591.43 6,033,865.90 462,261.48 0.51 8,070.15 MW D+I FR2 +MS+sag (4) 11,280.78 89.11 323.67 6,149.67 6,093.47 2,790.28 - 7,610.63 6,033,891.94 462,242.39 1.11 8,097.88 MWD +IFR2 +MS +sag (4) 11,308.60 89.89 324.83 6,149.92 6,093.72 2,812.85 - 7,626.88 6,033,914.58 462,226.23 5.02 8,121.59 MWD +IFR2 +MS +sag (4) 11,344.71 90.80 323.60 6,149.70 6,093.50 2,842.14 - 7,648.00 6,033,943.95 462,205.24 4.24 8,152.37 MWD +IFR2 +MS +sag (4) 11,376.32 91.90 323.30 6,148.96 6,092.76 2,867.53 - 7,666.82 6,033,969.41 462,186.52 3.61 8,179.53 MWD +IFR2 +MS +sag (4) 11,409.34 91.77 322.69 6,147.90 6,091.70 2,893.89 - 7,686.68 6,033,995.84 462,166.77 1.89 8,208.02 MWD +IFR2 +MS +sag (4) 11,441.10 92.04 323.43 6,146.84 6,090.64 2,919.26 - 7,705.76 6,034,021.29 462,147.80 2.48 8,235.41 MWD +IFR2 +MS +sag (4) 11,472.44 92.74 324.01 6,145.54 6,089.34 2,944.50 - 7,724.29 6,034,046.60 462,129.37 2.90 8,262.25 MWD+I FR2 +MS+sa g (4) 11,506.38 90.48 322.43 6,144.58 6,088.38 2,971.67 - 7,744.60 6,034,073.85 462,109.17 8.12 8,291.47 MWD +IFR2 +MS +sag (4) 11,538.93 89.83 323.81 6,144.49 6,088.29 2,997.70 - 7,764.13 6,034,099.96 462,089.75 4.69 8,319.54 MWD +IFR2 +MS +sag (4) 11,570.08 90.54 322.31 6,144.39 6,088.19 3,022.60 - 7,782.85 6,034,124.93 462,071.13 5.33 8,346.42 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 6 COMPASS 2003.16 Build 428 • 0 Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name 11,602.99 90.88 324.84 6,143.99 6,087.79 3,049.08 - 7,802.39 6,034,151.49 462,051.70 7.76 8,374.66 MWD +IFR2 +MS +sag (4) 11,634.79 90.50 323.56 6,143.60 6,087.40 3,074.87 - 7,820.99 6,034,177.35 462,033.21 4.20 8,401.77 MWD +IFR2 +MS +sag (4) 11,666.24 90.70 323.06 6,143.27 6,087.07 3,100.08 - 7,839.78 6,034,202.64 462,014.52 1.71 8,428.84 MWD +IFR2 +MS +sag (4) 11,699.18 89.89 321.58 6,143.10 6,086.90 3,126.15 - 7,859.91 6,034,228.79 461,994.50 5.12 8,457.47 MWD +IFR2 +MS +sag (4) 11,731.14 89.95 320.74 6,143.15 6,086.95 3,151.05 - 7,879.96 6,034,253.76 461,974.56 2.63 8,485.57 MWD +IFR2 +MS +sag (4) 11,764.74 89.85 319.25 6,143.21 6,087.01 3,176.78 - 7,901.56 6,034,279.58 461,953.06 4.44 8,515.42 MWD +IFR2 +MS +sag (4) 11,796.76 89.88 320.92 6,143.28 6,087.08 3,201.34 - 7,922.10 6,034,304.22 461,932.62 5.22 8,543.86 MWD +IFR2 +MS +sag (4) 11,828.02 90.05 319.08 6,143.30 6,087.10 3,225.29 - 7,942.19 6,034,328.24 461,912.63 5.91 8,571.63 MWD + IFR2 +MS +sag (4) 11,877.21 91.14 318.95 6,142.79 6,086.59 3,262.42 - 7,974.45 6,034,365.50 461,880.52 2.23 8,615.72 MWD +IFR2 +MS +sag (4) 11,923.73 92.03 320.54 6,141.50 6,085.30 3,297.90 - 8,004.50 6,034,401.11 461,850.62 3.92 8,657.14 MWD +IFR2 +MS +sag (4) 11,972.44 90.41 321.07 6,140.47 6,084.27 3,335.64 - 8,035.28 6,034,438.97 461,820.00 3.50 8,700.09 MWD +IFR2 +MS +sag (4) 12,020.17 89.77 321.45 6,140.39 6,084.19 3,372.87 - 8,065.14 6,034,476.31 461,790.29 1.56 8,742.01 MWD +IFR2 +MS +sag (4) 12,063.52 90.58 323.16 6,140.26 6,084.06 3,407.17 - 8,091.65 6,034,510.72 461,763.93 4.36 8,779.70 MWD+ I FR2+MS+sag (4) 12,117.29 89.77 322.38 6,140.10 6,083.90 3,449.98 - 8,124.18 6,034,553.66 461,731.57 2.09 8,826.24 MWD +IFR2 +MS +sag (4) 12,152.67 90.55 322.20 6,140.00 6,083.80 3,477.97 - 8,145.82 6,034,581.73 461,710.05 2.26 8,857.00 MWD +IFR2 +MS +sag (4) 12,212.57 89.38 321.03 6,140.03 6,083.83 3,524.93 - 8,183.01 6,034,628.83 461,673.05 2.76 8,909.43 MWD +IFR2 +MS +sag (4) 12,258.08 90.26 321.06 6,140.18 6,083.98 3,560.32 - 8,211.63 6,034,664.33 461,644.58 1.93 8,949.48 MWD +IFR2 +MS +sag (4) 12,308.31 89.22 320.19 6,140.40 6,084.20 3,599.14 - 8,243.49 6,034,703.28 461,612.88 2.70 8,993.86 MWD +IFR2 +MS +sag (4) 12,359.63 89.70 319.74 6,140.89 6,084.69 3,638.43 - 8,276.50 6,034,742.70 461,580.03 1.28 9,039.48 MWD +IFR2 +MS +sag (4) 12,407.33 89.52 318.40 6,141.21 6,085.01 3,674.47 - 8,307.75 6,034,778.86 461,548.93 2.83 9,082.21 MWD +IFR2 +MS +sag (4) 12,455.47 89.34 318.54 6,141.69 6,085.49 3,710.51 - 8,339.67 6,034,815.02 461,517.17 0.47 9,125.56 MWD +IFR2 +MS +sag (4) 12,501.85 90.69 318.84 6,141.68 6,085.48 3,745.34 - 8,370.28 6,034,849.98 461,486.70 2.98 9,167.25 MWD +IFR2 +MS +sag (4) 12,549.95 89.74 317.06 6,141.50 6,085.30 3,781.06 - 8,402.50 6,034,885.82 461,454.63 4.19 9,210.76 MWD +IFR2 +MS +sag (4) 12,600.39 92.49 317.48 6,140.52 6,084.32 3,818.10 - 8,436.71 6,034,923.00 461,420.57 5.52 9,256.61 MWD +IFR2 +MS +sag (4) 12,631.70 91.92 317.57 6,139.31 6,083.11 3,841.17 - 8,457.84 6,034,946.16 461,399.54 1.84 9,285.01 MWD +IFR2 +MS +sag (4) 12,664.00 91.87 318.74 6,138.24 6,082.04 3,865.22 - 8,479.38 6,034,970.29 461,378.10 3.62 9,314.16 MWD +I FR2 +MS +sag (4) 12,695.76 91.37 318.58 6,137.35 6,081.15 3,889.06 - 8,500.35 6,034,994.21 461,357.23 1.65 9,342.70 MWD +I +MS +sag (4) 12,727.69 90.01 318.97 6,136.96 6,080.76 3,913.07 - 8,521.39 6,035,018.30 461,336.29 4.43 9,371.38 MWD +IFR2 +MS +sag (4) 12,761.32 89.52 317.89 6,137.10 6,080.90 3,938.23 - 8,543.70 6,035,043.55 461,314.08 3.53 9,401.67 MWD +IFR2 +MS +sag (4) 12,792.94 89.33 319.80 6,137.42 6,081.22 3,962.04 - 8,564.51 6,035,067.44 461,293.37 6.07 9,430.06 MWD +IFR2 +MS +sag (4) 12,823.21 88.34 319.17 6,138.03 6,081.83 3,985.04 - 8,584.17 6,035,090.52 461,273.81 3.88 9,457.07 MWD +IFR2 +MS +sag (4) 12,856.63 87.39 321.22 6,139.28 6,083.08 4,010.70 - 8,605.55 6,035,116.26 461,252.53 6.76 9,486.70 MWD +IFR2 +MS +sag (4) 12,888.97 88.04 319.33 6,140.57 6,084.37 4,035.55 - 8,626.20 6,035,141.20 461,231.99 6.18 9,515.34 MWD +I FR2 +MS +sag (4) 12,920.88 88.14 320.10 6,141.63 6,085.43 4,059.88 - 8,646.82 6,035,165.60 461,211.47 2.43 9,543.75 MWD+ I FR2+MS+sag (4) 12,953.27 88.71 320.61 6,142.52 6,086.32 4,084.81 - 8,667.48 6,035,190.62 461,190.91 2.36 9,572.43 MWD +IFR2 +MS +sag (4) 12,985.46 89.68 319.11 6,142.97 6,086.77 4,109.42 - 8,688.22 6,035,215.30 461,170.27 5.55 9,601.07 MWD +IFR2 +MS +sag (4) 13,017.27 89.45 318.91 6,143.21 6,087.01 4,133.43 - 8,709.09 6,035,239.40 461,149.50 0.96 9,629.58 MWD +IFR2 +MS +sag (4) 13,049.30 89.28 319.13 6,143.57 6,087.37 4,157.60 - 8,730.09 6,035,263.66 461,128.60 0.87 9,658.29 MWD + IFR2 +MS +sag (4) 13,081.70 88.71 319.02 6,144.14 6,087.94 4,182.08 - 8,751.31 6,035,288.22 461,107.48 1.79 9,687.31 MWD +IFR2 +MS +sag (4) 13,112.24 88.39 320.53 6,144.91 6,088.71 4,205.39 - 8,771.03 6,035,311.60 461,087.86 5.05 9,714.49 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 7 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK - 14 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NiS +V -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (°N00') (ft) Survey Tool Name 13,146.15 87.86 319.67 6,146.02 6,089.82 4,231.39 - 8,792.77 6,035,337.69 461,066.23 2.98 9,744.58 MWD +IFR2 +MS +sag (4) 13,178.84 87.65 321.50 6,147.30 6,091.10 4,256.63 - 8,813.51 6,035,363.01 461,045.59 5.63 9,773.45 MWD +IFR2 +MS +sag (4) 13,210.20 88.39 320.08 6,148.38 6,092.18 4,280.91 - 8,833.32 6,035,387.37 461,025.88 5.10 9,801.10 MWD +IFR2 +MS +sag (4) 13,242.64 89.83 320.08 6,148.89 6,092.69 4,305.79 - 8,854.13 6,035,412.33 461,005.17 4.44 9,829.90 MWD +IFR2 +MS +sag (4) 13,274.38 89.27 321.66 6,149.14 6,092.94 4,330.40 - 8,874.16 6,035,437.02 460,985.24 5.28 9,857.88 MWD +IFR2 +MS +sag (4) 13,308.10 89.46 320.85 6,149.51 6,093.31 4,356.70 - 8,895.27 6,035,463.40 460,964.25 2.47 9,887.50 MWD +IFR2 +MS +sag (4) 13,340.47 89.41 321.04 6,149.83 6,093.63 4,381.84 - 8,915.66 6,035,488.62 460,943.96 0.61 9,916.01 MWD +IFR2 +MS +sag (4) 13,371.95 88.87 319.41 6,150.30 6,094.10 4,406.03 - 8,935.80 6,035,512.89 460,923.92 5.45 9,943.93 MWD +IFR2 +MS +sag (4) 13,402.04 88.85 318.95 6,150.90 6,094.70 4,428.80 - 8,955.46 6,035,535.73 460,904.35 1.53 9,970.85 MWD +IFR2 +MS +sag (4) 13,435.95 88.96 320.36 6,151.55 6,095.35 4,454.63 - 8,977.41 6,035,561.66 460,882.51 4.17 10,001.07 MWD +IFR2 +MS +sag (4) 13,466.68 88.78 318.76 6,152.16 6,095.96 4,478.02 - 8,997.34 6,035,585.12 460,862.68 5.24 10,028.48 MWD +IFR2 +MS +sag (4) 13,499.18 88.24 319.65 6,153.00 6,096.80 4,502.61 - 9,018.57 6,035,609.80 460,841.56 3.20 10,057.56 MWD +IFR2 +MS +sag (4) 13,531.82 88.76 320.22 6,153.86 6,097.66 4,527.58 - 9,039.57 6,035,634.85 460,820.66 2.36 10,086.57 MWD +IFR2 +MS +sag (4) 13,564.08 88.04 320.55 6,154.76 6,098.56 4,552.43 - 9,060.13 6,035,659.77 460,800.20 2.45 10,115.12 MWD +IFR2 +MS +sag (4) 13,595.33 88.51 322.45 6,155.70 6,099.50 4,576.87 - 9,079.57 6,035,684.29 460,780.86 6.26 10,142.49 MWD +IFR2 +MS +sag (4) 13,627.87 88.32 322.81 6,156.60 6,100.40 4,602.72 - 9,099.32 6,035,710.22 460,761.22 1.25 10,170.68 MWD +IFR2 +MS +sag (4) 13,661.68 87.10 324.70 6,157.95 6,101.75 4,629.96 - 9,119.29 6,035,737.54 460,741.36 6.65 10,199.62 MWD +IFR2 +MS +sag (4) 13,693.77 85.86 323.59 6,159.92 6,103.72 4,655.92 - 9,138.05 6,035,763.58 460,722.71 5.18 10,226.95 MWD +IFR2 +MS +sag (4) 13,725.27 86.24 323.78 6,162.09 6,105.89 4,681.25 - 9,156.66 6,035,788.97 460,704.20 1.35 10,253.89 MWD +IFR2 +MS +sag (4) 13,757.98 87.49 323.82 6,163.88 6,107.68 4,707.60 - 9,175.95 6,035,815.40 460,685.02 3.82 10,281.85 MWD +IFR2 +MS +sag (4) 13,790.30 87.95 325.42 6,165.16 6,108.96 4,733.93 - 9,194.65 6,035,841.81 460,666.43 5.15 10,309.26 MWD +IFR2 +MS +sag (4) 13,820.93 89.70 324.82 6,165.79 6,109.59 4,759.05 - 9,212.16 6,035,866.99 460,649.02 6.04 10,335.11 MWD +IFR2 +MS +sag (4) 13,852.00 89.70 324.82 6,165.95 6,109.75 4,784.45 - 9,230.06 6,035,892.46 460,631.23 0.00 10,361.43 PROJECTED to TD 3/4/2010 3:18:37PM Page 8 COMPASS 2003.16 Build 42B • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 PB2 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -71 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Orilling Services is S Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5 @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5 @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB 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 ODSK -14 - Slot ODS -14 Well Position +NI-S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK -14 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSK -14 PB2 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,660.00 Vertical Section: Depth From (ND) +N/-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 J Survey Program Date 3/4/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4,740.90 11,539.05 ODSK -14 PB2 MWD (ODSK -14 PB2) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1: 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 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro -SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro -SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro -SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro -SS(1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro -SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro -SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro -SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS(1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro -SS (1) 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) 3/4/2010 3 :40 :41PM Page 2 COMPASS 2003.16 Build 428 • IP Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +0-W Northing Easting DLS Section (ft) (?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro -SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro -SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) I 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3/4/2010 3:40:41PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB 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) ( °/100') (ft) Survey Tool Name 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,660.00 56.62 281.79 3,537.21 3,481.01 497.65 - 2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 4,740.95 55.40 279.20 3,582.47 3,526.27 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag (3) 4,836.40 54.98 280.65 3,637.02 3,580.82 523.93 - 2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 4,879.42 55.71 280.39 3,661.48 3,605.28 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 - 2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 - 2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 - 2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 - 2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 - 2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) 5,450.50 56.87 281.90 3,966.96 3,910.76 614.98 - 3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) 5,546.29 56.76 281.72 4,019.39 3,963.19 631.39 - 3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 5,641.35 56.95 279.09 4,071.38 4,015.18 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031,743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41PM Page 4 COMPASS 2003.16 Build 42B • • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK - 14 North Reference: True Wellbore: ODSK - 14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 - 3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag (3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 - 3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 - 4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 - 4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) 6,878.72 56.92 279.21 4,758.80 4,702.60 803.14 - 4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) 6,974.00 57.33 278.74 4,810.52 4,754.32 815.62 - 4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 7,070.69 58.44 280.02 4,861.92 4,805.72 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) 7,164.65 57.01 278.08 4,912.10 4,855.90 841.48 - 4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) 7,259.49 56.57 276.96 4,964.04 4,907.84 851.87 - 4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 7,354.90 56.92 277.34 5,016.36 4,960.16 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) 7,451.12 57.52 279.93 5,068.46 5,012.26 873.95 - 4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) 7,545.34 57.71 279.62 5,118.93 5,062.73 887.46 - 4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 7,640.14 57.14 280.28 5,169.97 5,113.77 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 - 4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) 7,819.80 57.61 281.36 5,265.98 5,209.78 929.54 - 5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 7,892.32 58.60 282.43 5,304.29 5,248.09 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 - 5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032,114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032,154.95 464,244.87 2.51 5,576.60 MWD +IFR2 +MS +sag (3) 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032,242.53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032,318.39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032,362.71 463,771.84 2.61 6,093.25 MWD +IFR2 +MS +sag (3) 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD+ I FR2+MS+sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 314/2010 3:40:41PM Page 5 COMPASS 2003.16 Build 428 • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +e -W Northing Easting DLS Section ft (?) (?) (ft) (ft) (ft) (ft) (ft) ft ( °1100') (ft) Survey Tool Name 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD +IFR2 +MS +sag (3) 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6,032,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD +IFR2 +MS +sag (3) 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) 10,765.16 93.44 316.30 6,146.08 6,089.88 2,398.43 - 7,276.13 6,033,498.78 462,575.27 1.98 7,638.07 MWD +IFR2 +MS +sag (3) 10,862.85 90.30 314.19 6,142.89 6,086.69 2,467.75 - 7,344.86 6,033,568.37 462,506.82 3.87 7,728.23 MWD +IFR2 +MS +sag (3) 10,964.23 86.00 312.52 6,146.16 6,089.96 2,537.30 - 7,418.52 6,033,638.21 462,433.46 4.55 7,823.02 MWD +IFR2 +MS +sag (3) 11,056.05 90.61 319.69 6,148.88 6,092.68 2,603.38 - 7,482.09 6,033,704.54 462,370.16 9.28 7,907.17 MWD +IFR2 +MS +sag (3) 11,151.70 86.98 318.44 6,150.89 6,094.69 2,675.61 - 7,544.73 6,033,777.02 462,307.82 4.01 7,992.83 MWD +IFR2 +MS +sag (3) 11,247.97 85.96 319.38 6,156.82 6,100.62 2,748.03 - 7,607.88 6,033,849.68 462,244.97 1.44 8,079.04 MWD +IFR2 +MS +sag (3) 11,345.12 86.46 317.68 6,163.24 6,107.04 2,820.66 - 7,672.07 6,033,922.57 462,181.08 1.82 8,166.29 MWD +IFR2 +MS +sag (3) 11,440.88 86.76 316.50 6,168.91 6,112.71 2,890.67 - 7,737.16 6,033,992.83 462,116.28 1.27 8,253.35 MWD +IFR2 +MS +sag (3) 11,539.05 86.21 314.71 6,174.93 6,118.73 2,960.68 - 7,805.70 6,034,063.12 462,048.03 1.90 8,343.60 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41PM Page 6 COMPASS 2003.16 Build 428 • Well Plannin g - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 PB1 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -70 Sperry Drilling Services Definitive Survey Report 04 March, 2010 HALLIBURTON Sperry Drilling Services I S Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB 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 ODSK -14 - Slot ODS -14 Well Position +N/-S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSK -14 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 1/6/2009 22.43 80.81 57,719 Design ODSK -14 PB1 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 Survey Program Date 3/2/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.85 7,812.94 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) ( ?) (7) (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 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro -SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro -SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro -SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro -SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro -SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro -SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro -SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro -SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro -SS(1) 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 3/4/2010 3 :38 :35PM Page 2 COMPASS 2003.16 Build 42B ■ • • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Fasting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro -SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro -SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80. 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 3 COMPASS 2003.16 Build 428 • • • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK - 14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK - 14 PB1 KupB 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 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD+I FR2 +MS+sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,696.47 56.26 282.43 3,557.37 3,501.17 504.03 - 2,455.72 6,031,585.03 467,387.46 1.75 2,460.00 MWD +IFR2 +MS +sag (2) 4,795.92 55.38 283.19 3,613.24 3,557.04 522.27 - 2,535.94 6,031,603.59 467,307.32 1.09 2,541.05 MWD +IFR2 +MS +sag (2) 4,888.73 56.43 282.13 3,665.27 3,609.07 539.11 - 2,610.93 6,031,620.73 467,232.41 1.47 2,616.72 MWD +IFR2 +MS +sag (2) 4,985.32 57.16 281.02 3,718.16 3,661.96 555.32 - 2,690.10 6,031,637.26 467,153.32 1.22 2,696.02 MWD +IFR2 +MS +sag (2) 5,083.15 57.86 278.93 3,770.72 3,714.52 569.61 - 2,771.37 6,031,651.88 467,072.12 1.94 2,776.50 MWD +IFR2 +MS +sag (2) 5,177.31 57.67 277.08 3,820.94 3,764.74 580.70 - 2,850.23 6,031,663.29 466,993.31 1.67 2,853.54 MWD +IFR2 +MS +sag (2) 5,273.02 57.15 277.99 3,872.50 3,816.30 591.27 - 2,930.17 6,031,674.18 466,913.42 0.97 2,931.37 MWD +IFR2 +MS +sag (2) 5,368.00 57.45 277.58 3,923.81 3,867.61 602.10 - 3,009.36 6,031,685.33 466,834.28 0.48 3,008.60 MWD +IFR2 +MS +sag (2) 5,463.25 56.12 278.80 3,975.99 3,919.79 613.44 - 3,088.24 6,031,696.99 466,755.46 1.76 3,085.74 MWD +IFR2 +MS +sag (2) 5,558.44 55.81 280.01 4,029.26 3,973.06 626.33 - 3,166.06 6,031,710.20 466,677.70 1.10 3,162.51 MWD +IFR2 +MS +sag (2) 5,654.03 58.44 280.69 4,081.15 4,024.95 640.76 - 3,245.02 6,031,724.94 466,598.80 2.82 3,240.93 MWD +IFR2 +MS +sag (2) 5,748.48 58.02 281.56 4,130.88 4,074.68 656.25 - 3,323.81 6,031,740.75 466,520.08 0.90 3,319.59 MWD +IFR2 +MS +sag (2) 5,843.77 57.68 281.07 4,181.58 4,125.38 672.08 - 3,402.92 6,031,756.90 466,441.05 0.56 3,398.68 MWD +IFR2 +MS +sag (2) 5,938.67 56.64 280.79 4,233.05 4,176.85 687.20 - 3,481.21 6,031,772.34 466,362.83 1.12 3,476.74 MWD +IFR2 +MS +sag (2) 6,034.66 56.29 280.93 4,286.08 4,229.88 702.28 - 3,559.79 6,031,787.73 466,284.32 0.38 3,555.05 MWD +IFR2 +MS +sag (2) 6,129.07 55.43 280.95 4,339.06 4,282.86 717.10 - 3,636.51 6,031,802.87 466,207.67 0.91 3,631.55 MWD +IFR2 +MS +sag (2) 6,224.45 56.14 280.30 4,392.69 4,336.49 731.64 - 3,714.03 6,031,817.72 466,130.22 0.93 3,708.67 MWD +IFR2 +MS +sag (2) 6,319.42 55.74 280.69 4,445.88 4,389.68 745.98 - 3,791.39 6,031,832.36 466,052.92 0.54 3,785.57 MWD +IFR2 +MS +sag (2) 6,415.19 55.12 280.91 4,500.22 4,444.02 760.75 - 3,868.85 6,031,847.45 465,975.53 0.67 3,862.74 MWD +IFR2 +MS +sag (2) 6,502.10 54.78 279.48 4,550.14 4,493.94 773.35 - 3,938.87 6,031,860.33 465,905.57 1.40 3,932.20 MWD +IFR2 +MS +sag (2) 6,597.96 55.78 279.06 4,604.73 4,548.53 786.04 - 4,016.63 6,031,873.34 465,827.86 1.10 4,008.83 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 4 COMPASS 2003.16 Build 428 • Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +El -W Northing Easting DLS Section Survey Tool Name (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( /100') (ft) 6,692.29 57.01 278.23 4,656.94 4,600.74 797.84 - 4,094.30 6,031,885.45 465,750.25 1.50 4,085.04 MWD +IFR2 +MS +sag (2) 6,788.05 58.28 277.61 4,708.19 4,651.99 808.98 -4,174.42 6,031,896.92 465,670.18 1.43 4,163.26 MWD +IFR2 +MS +sag (2) 6,883.73 57.65 278.16 4,758.94 4,702.74 820.11 - 4,254.77 6,031,908.37 465,589.90 0.82 4,241.67 MWD +IFR2 +MS +sag (2) 6,978.84 57.20 278.05 4,810.15 4,753.95 831.41 - 4,334.11 6,031,919.99 465,510.60 0.48 4,319.23 MWD +IFR2 +MS +sag (2) 7,073.56 58.55 276.57 4,860.52 4,804.32 841.61 - 4,413.67 6,031,930.51 465,431.09 1.94 4,396.56 MWD +IFR2 +MS +sag (2) 7,168.75 57.36 277.30 4,911.02 4,854.82 851.35 - 4,493.77 6,031,940.57 465,351.05 1.41 4,474.21 MWD +IFR2 +MS +sag (2) 7,264.19 58.45 277.16 4,961.73 4,905.53 861.52 - 4,573.98 6,031,951.07 465,270.89 1.15 4,552.13 MWD +IFR2 +MS +sag (2) 7,359.11 57.98 278.70 5,011.73 4,955.53 872.65 - 4,653.89 6,031,962.53 465,191.03 1.47 4,630.15 MWD +IFR2 +MS +sag (2) 7,454.19 56.86 279.20 5,062.93 5,006.73 885.11 - 4,733.03 6,031,975.31 465,111.95 1.26 4,707.97 MWD +IFR2 +MS +sag (2) 7,548.93 56.20 280.22 5,115.18 5,058.98 898.44 - 4,810.93 6,031,988.95 465,034.11 1.14 4,784.97 MWD +IFR2 +MS +sag (2) 7,644.32 57.23 280.20 5,167.53 5,111.33 912.57 - 4,889.40 6,032,003.40 464,955.70 1.08 4,862.83 MWD +IFR2 +MS +sag (2) 7,737.27 57.17 279.72 5,217.88 5,161.68 926.09 - 4,966.36 6,032,017.22 464,878.81 0.44 4,939.03 MWD +IFR2 +MS +sag (2) 7,812.94 57.58 279.59 5,258.68 5,202.48 936.77 - 5,029.18 6,032,028.17 464,816.04 0.56 5,001.12 MWD +IFR2 +MS +sag (2) 3/4/2010 3 :38 :35PM Page 5 COMPASS 2003.16 Build 428 • RECEIVED PIONEER MAR 2 NATURAL RESOURCES ALASKA Letter of Transmittal Date: March 23, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources' Attn: Christine Mahnken 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other — 3 CDs, 12 Well Logs ❑ Agreement DETAIL QTY DESCRIPTION ODSK -14 (API: 50- 703 - 20610 -0000) ODSK -14PB1 (API: 50- 703 - 20610 -7000) ODSK -14PB2 (API: 50- 703 - 20610 -7100) 3 CDs 3CDs LWD Final Processed Data 12 Well Logs 12 Well logs DGR, EWR -Phase 4, ADR, ALD, CTN (1:600, 1:240) MD logs, TVD logs for ODSK -14 & ODSK -14PB2 DGR, EWR (1:600/ 1:240) MD logs, TVD logs for ODSK -14PB1 We request that all data t ated as confidential information. Thank you. Received by: Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907 -343 -2190 fax, 907 - 343 -2128 phone O - 1 `''- It • 1 n ATA --d? IT\ SA\LA, / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ;� ANCHORAGE, ALASKA 99501 -3539 / PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 tat-- Re: Oooguruk Field, Kuparuk Oil Pool, ODSK-14 Pioneer Natural Resources Alaska, Inc. Permit No: 209 -155 Surface Location: 2955' FSL, 1157' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 2259' FSL, 35' FEL, Sec. 4, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This approval supersedes and replaces the permit to drill for this well that was issued on December 14, 2009. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely Daniel T. Seamount, Jr. Chair DATED this 2 vs. day of February, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via 3 -mail) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI ION PERMIT TO DRILL 20 AAC 25.005 �� "` la. Type of Work: lb. Proposed Well Class: Development - Oil El . Service - Winj ❑ Single Zone 0 lc. Specify if well is proposed for: Drill la . Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 • ODSK -14 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 13,844' TVD: 6144' 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool ,- Surface: 2955' FSL, 1157' FEL, Sec. 11, T13N, R7E, UM . ADL 355036 / 6.0.1-a5:19537 z o4- /` Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4796' FSL, 2648' FEL, Sec. 10, T13N, R7E, UM 417497 1/10/2010 • Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2259' FSL, 35' FEL, Sec. 4, T13N, R7E, UM 5760 / 5724 3025' 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- 469840.87 y- 6031071.09 Zone- ASP 4 GL Elevation above MSL: 13.5 feet _ to Same Pool: ODSK -33 is 4990' away 16. Deviated wells: Kickoff depth: 300 feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.43 degrees Downhole: 3073 , Surface: 2410 . 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 IBT -M 3979' 9865' 6056' 13,844' 6144' Uncemented Slotted RECEIVED FEB 2 5 2ftfl 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): A$ taheitht388 won!. Conn j8 f d): Anchorag Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 16" Driven 158' 158' Surface 3518' 11 -3/4" 495 sx PF 'L'; 260 sx Class 'G' 3557' 2938' Intermediatel - DrIg Liner 4452' 9 -5/8" 372 sx Class 'G' 3401' - 7853' 2852' - 5284' Intermediate 2 10,356' 7" 95 sx Class 'G' 10,394' 6142' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program la 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Guy Schwartz Date 2/24/2010 22. I hereby certify that the foregoing is true and correct. Contact Joe Delmonico, 343 - 2182 r Prepared By: Kathy Campoamor, 343 -2183 Printed Name Vern Johnson Title Sr. Staff Drilling Engineer - 7 Signature V L Phone 343 -2111 Date 2/25/2010 g z , Commission Use Only Permit to Drill A API Number: ermit Approval See cover letter for other Number: UVI • S S 50 7D - 3 + �_,e,(, 11 0 - -" �.yJ (, 'b ate: J,2 / /L/ / b 7 requirements. Conditions of approval : If box is ch cked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: [v� Other: iv ysap P S ` b o f 1:5.-/--- Samples req'd: Yes ❑ No p' Mud log req'd: Yes ❑ No Ea-" H measures: Yes ❑ No ET Directional svy req'd: Yes I -No ❑ -4 2 S o O , o 7. An,,. L . . . Q . A . ‘ ' 7 - e - 51- k,. -, ) -- Q ..4ip 4.4.COl .,,,,,5. L,, PT a-pp 1 p- APPROVED BY THE COMMISSION 2 / / '� DATE: _ , COMMISSIONER ORIGINAL IL 2-z 6•to 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 Duplic to • PIONE NATURAL RESOURCES February 25, 2009 RECEIVED State of Alaska FEB 2 5 2010 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Alaska Oil & Gas Cons. Commission Anchorage, AK 99501 Anchorage RE: Application to Permit To Drill ODSK -14 Permit To Drill #209 -155 Surface Location: 2955' FSL, 1157' FEL, Sec 11, T13N, R7E, UM X = 469840.87, Y = 6031071.09, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) is in the process of drilling the approved well, ODSK -14 under PTD #209 -155. During the course of drilling ODSK -14, log results indicated thinner sands in the Kuparuk reservoir than expected. At the time of this letter, we have received a verbal approval for drilling a lateral extension to compensate for the reduced sand thickness. PNRA requests to drill approximately 1,500' MD beyond the original permitted bottom hole target location. As specified in the attachments, the remaining drilling program will consist of drilling the 6 -1/8" lateral production hole to a final TD of —13,844' MD / 6144' TVD, where a 4 -1/2" slotted production liner will be run. The completion will utilize 3 -1/2" tubing. Please find attached the updated information as required by 20 AAC 25.005 (a) and (c) for your review. 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 planned with descriptions c. A complete proposed casing program is attached per 20 AAC 25.030 d. Point forward drilling plan e. Wellbore schematic depicting proposed well completion 3) A copy of the Planned Directional Well Path — including traveling cylinder and development layout plots Alaska Oil & Gas Conservation Commission November 25, 2009 Page 2of2 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. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson @pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The start date of drilling the lateral extension for ODSK -14 is February 25, 2010. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sin - ely, Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -14 Well File • • Permit to Drill Well Plan Summary ODSK -14 Oooguruk - Kuparuk Production Well Surface TD @ 3,557' MD / 2,938' TVD - Drilling Liner TD @ 7,853' MD / 5,284' TVD Intermediate TD @ 10,394' MD / 6,142' TVD Production TD @ 13,844' MD / 6144' TVD Surface Location: 2955' FSL, 1157' FEL, Sec 11, T13N, R7E, UM ' ASP 4 (NAD27) projection X = 469840.87 ' 1 Y = 6031071.09 • 1 Target: Oooguruk - Kuparuk 4796' FSL, 2648' FEL, Sec 10, T13N, R7E, Umiat X = 463077.00 1 Y = 6032943.00 1 6059' TVDrkb Bottom Hole Location: 2259' FSL, 35' FEL, Sec 4, T13N, R7E, Umiat X = 460418.90 Y = 6035693.29 6144' TVDrkb AFE Number: TBA Est. Start Date: January 10, 2010 1 Rig: Nabors 19AC Operating days: 38.2 days to Drill and Complete TD: 13,843.6' MD / 6144 TVDrkb Objective: Kuparuk 1 Well Type (exp, dev, etc): Development Well Design: Modified Slimhole (11 -3/4" x 9 -5/8" liner x 7" x 4 -1/2" liner) — Producer — wp04a Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' • RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' . Conductor: 157.66' MDrkb Pioneer Natural Resources Last Revised for Re- Permit: February 25, 2010 ODSK -14 Permit To Drill Page 1 of 5 Well Control: 6 -1/8" Production Liner Hole Section: • Maximum anticipated BHP: 3073 psi @ 6032' TVDss • (Based on 9.8 ppg Oooguruk- Kuparuk pore pressure) • Maximum surface pressure: 2410 psi @ surface . (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ 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 . 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 connection Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 7" Intermediate Shoe Rathole + 20' from shoe FIT 12.5 ppg Production Hole Mud Properties: 6 -1/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 8.6 ppg ( -10.2 37 - 50 13 - 18 5 - 14 < 5 <8 ppg via MPD) Logging Program: 6 -1/8" Section: Drilling: Mud logging Dir / GR / Azm Res / Dens / Neut / PWD Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing CsglTbg Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 61/8" 4-1/2" 12.6# L -80 IBT -M 9,865' 13,844'/6,144' slotted 3599 Pioneer Natural Resources Last Revised for Re- Permit: February 25, 2010 ODSK -14 Permit To Drill Page 2 of 5 • I Tubing 3 -1/2" 1 9.3# L -80 TSHP/TCII 9,972' Surface 1 10,015' / 6,059' I 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" IBT -M 8430 7500 289 M 289 M slotted 3 -1/2" 9.3# L -80 2.992" 2.867" TSHP/TCII 10160 10540 207 M 207 M Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised for Re- Permit: February 25, 2010 ODSK -14 Permit To Drill Page 3 of 5 • • Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Riq Activity: Drill and Complete 1. Drill 6 -1/8" lateral production hole to TD. • 2. Circulate and condition the hole to run liner. 3. Change one set of pipe rams to 4 -1/2" and test BOPE as required. 4. RIH w/ 4 -1/2" slotted production liner from 150' inside the intermediate shoe to TD. 5. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 6. MU ESP completion and RIH. • 7. Land the tubing and RILDS. Install TWC. 8. ND BOPE, NU tree and test to 5,000 psi. 9. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 10. 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. 11. RDMO to next well. Post -Riq Work 12. RU Slickline and pull the ball and rod. Pull the RHC -m plug. Pioneer Natural Resources Last Revised for Re- Permit: February 25, 2010 ODSK -14 Permit To Drill Page 4 of 5 ODSK -14 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre- reservoir meeting to outline heightened • awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck , from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45 - close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press 7" Intermediate / Infinite 8'6 ppg 3059 12.5 ppg (FIT) 6 -1/8" (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 H site, however Standard Operating • Procedures for H 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 for Re- Permit: February 25, 2010 ODSK -14 Permit To Drill Page 5 of 5 ODSK -14 Pr action Well Proposed•ompletion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 158' MDrkb / 158' TVDrkb 2 -7/8" ScSSSV, 2.313" ID @ —755' MD / 755 TVD 3 -1/2 ", 9.3# L -80 TCII or TSHP ► ■ 11 -3/4 ", 60# L -80 Hyd 521, 10.772" ID , NM 3557' MDrkb / 2938' TVDrkb —1 2 -7/8" GLM #2 @ 4250' MDrkb / 3330' TVDrkb II 2 7/8" X Nipple, 2.313" ID @ 5020' MD ,il 7" x 2 -7/8" Packer @5050' MDrkb / —3750' TVDrkb I 2 7/8" X Nipple, 2.313" ID w RHC -M Profile @ 5070' MD Estimated Top of Cement @ 6870' MD, 2 -7/8" GLM #1 @ 8250' MDrkb / 5510' TVDrkb ESP Cable 500' MD above Top Torok 9 -5/8 ", 40# L -80 Hydril 521, 8.835" ID I II 7853' MDrkb / 5284' TVDrkb 1 2 7/8" XN Nipple, 2.205" ID Nogo 8880' MD / 5771' TVD 000 ADV @ 9740' MD / 6025' TVD ESP at @ 9760' MDrkb / 6027' TVD End of Assembly 9850' MD Estimated Top of Cement @ 9895' MD, 500' MD above 7" shoe 7" Weatherford Liner Top Packer and Tieback 10244' MDrkb / 6120' TVD, 7 ", 26# L -80 Hyd 511, 6.276" ID 4 -1 /2" slotted liner 12.6# L -80 IBT -M 10,394' MDrkb / 6142' TVDrkb 13,844' MDrk / 6144' TVDrkb • PIONEER Date: Revision By: Comments 10/14/2009 jdf Proposed Completions 2/25/2010 jad Lateral extension edit ODSK -14 Producer NATURAL RESOURCESALASI Well Schematic Draft • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 - Slot ODS -14 ODSK -14 KupB Plan: ODSK -14 KupB wp06 Standard Proposal Report 25 February, 2010 HALLIBURTOIN Sperry Drilling Services • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 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 ODSK -14 - Slot ODS -14 Well Position +N /-S 0.0 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E/ -W 0.0 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSK -14 KupB Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) (7) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSK -14 KupB wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) (7) 42.7 0.0 0.0 292.47 2/25/2010 9:03:32AM Page 2 COMPASS 2003.16 Build 428 • Halliburton Company HA,LLI BU RTOle Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.T + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N /-S +E/ -W Rate Rate Rate Tool Face (ft) ( ?) ( ?) (ft) ft (ft) (ft) ( ?/100ft) ( ?/100ft) ( ?/100ft) ( ?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 0.00 0.00 0.00 0.00 600.0 3.00 300.00 599.9 543.7 3.9 -6.8 1.00 1.00 0.00 300.00 750.0 6.00 300.00 749.4 693.2 9.8 -17.0 2.00 2.00 0.00 0.00 983.3 13.00 300.00 979.4 923.2 29.1 -50.3 3.00 3.00 0.00 0.00 1,689.2 23.03 288.55 1,650.0 1,593.8 112.9 -250.5 1.50 1.42 -1.62 -25.00 1,797.9 23.03 288.55 1,750.0 1,693.8 126.4 -290.8 0.00 0.00 0.00 0.00 2,946.6 57.05 279.25 2,617.3 2,561.1 280.0 - 1,001.1 3.00 2.96 -0.81 -13.87 8,295.3 57.05 279.25 5,526.5 5,470.3 1,001.1 - 5,431.1 0.00 0.00 0.00 0.00 9,716.2 83.00 315.75 6,022.6 5,966.4 1,631.3 - 6,564.3 3.00 1.83 2.57 60.68 10,016.2 83.00 315.75 6,059.2 6,003.0 1,844.6 - 6,772.1 0.00 0.00 0.00 0.00 10,181.8 87.99 315.84 6,072.2 6,016.0 1,963.0 - 6,887.2 3.00 3.01 0.06 1.08 10,261.5 87.99 315.84 6,075.0 6,018.8 2,020.1 - 6,942.7 0.00 0.00 0.00 0.00 10,329.4 90.00 315.71 6,076.2 6,020.0 2,068.8 - 6,990.0 3.00 2.96 -0.20 -3.91 10,377.1 91.43 315.70 6,075.6 6,019.4 2,102.9 - 7,023.3 3.00 3.00 -0.01 -0.25 10,734.7 91.43 315.70 6,066.7 6,010.5 2,358.7 - 7,272.9 0.00 0.00 0.00 0.00 10,761.0 90.66 315.89 6,066.2 6,010.0 2,377.6 - 7,291.3 3.00 -2.91 0.74 165.79 10,761.6 90.68 315.90 6,066.2 6,010.0 2,378.1 - 7,291.8 3.00 2.90 0.77 14.87 11,169.0 90.68 315.90 6,061.3 6,005.1 2,670.5 - 7,575.2 0.00 0.00 0.00 0.00 11,192.5 90.00 315.72 6,061.2 6,005.0 2,687.4 - 7,591.6 3.00 -2.90 -0.77 - 165.13 11,238.2 88.63 315.72 6,061.7 6,005.5 2,720.1 - 7,623.5 3.00 -3.00 0.00 - 180.00 12,343.6 88.63 315.72 6,088.2 6,032.0 3,511.2 - 8,395.0 0.00 0.00 0.00 0.00 12,369.1 87.86 315.72 6,089.0 6,032.8 3,529.5 - 8,412.9 3.00 -3.00 0.00 179.96 13,843.6 87.86 315.72 6,144.0 6,087.8 4,584.4 - 9,441.6 0.00 0.00 0.00 0.00 2/25/2010 9 :03 :32AM Page 3 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURT011 Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 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) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 400.0 1.00 300.00 400.0 343.8 0.4 -0.8 6,031,071.53 469,840.12 1.00 0.87 500.0 2.00 300.00 500.0 443.8 1.7 -3.0 6,031,072.85 469,837.85 1.00 3.46 600.0 3.00 300.00 599.9 543.7 3.9 -6.8 6,031,075.04 469,834.09 1.00 7.78 700.0 5.00 300.00 699.6 643.4 7.4 -12.8 6,031,078.56 469,828.06 2.00 14.70 750.0 6.00 300.00 749.4 693.2 9.8 -17.0 6,031,080.97 469,823.92 2.00 19.45 800.0 7.50 300.00 799.0 742.8 12.7 -22.1 6,031,083.93 469,818.84 3.00 25.28 900.0 10.50 300.00 897.8 841.6 20.6 -35.6 6,031,091.80 469,805.33 3.00 40.78 983.3 13.00 300.00 979.4 923.2 29.1 -50.3 6,031,100.35 469,790.67 3.00 57.61 1,000.0 13.23 299.54 995.6 939.4 30.9 -53.6 6,031,102.24 469,787.40 1.50 61.36 1,100.0 14.60 297.07 1,092.7 1,036.5 42.3 -74.8 6,031,113.70 469, 766.26 1.50 85.28 1,200.0 16.00 295.01 1,189.1 1,132.9 53.9 -98.5 6,031,125.36 469,742.59 1.50 111.62 1,300.0 17.42 293.29 1,284.9 1,228.7 65.6 -124.7 6,031,137.21 469,716.40 1.50 140.36 1,400.0 18.85 291.81 1,379.9 1,323.7 77.5 -153.5 6,031,149.25 469,687.71 1.50 171.48 1,500.0 20.29 290.54 1,474.2 1,418.0 89.6 -184.7 6,031,161.45 469,656.53 1.50 204.95 1,600.0 21.73 289.43 1,567.5 1,511.3 101.9 -218.4 6,031,173.83 469,622.89 1.50 240.77 1,689.2 23.03 288.55 1,650.0 1,593.8 112.9 -250.5 6,031,185.01 469,590.82 1.50 274.67 1,700.0 23.03 288.55 1,659.9 1,603.7 114.3 -254.5 6,031,186.36 469,586.82 0.00 278.88 1,706.8 23.03 288.55 1,666.2 1,610.0 115.1 -257.1 6,031,1 87.22 469,584.30 0.00 281.54 Base of Permafrost 1,797.9 23.03 288.55 1,750.0 1,693.8 126.4 -290.8 6,031,198.69 469,550.58 0.00 317.08 1,800.0 23.09 288.51 1,752.0 1,695.8 126.7 -291.6 6,031,198.96 469,549.79 3.00 317.91 1,900.0 26.01 286.88 1,842.9 1,786.7 139.3 -331.2 6,031,211.71 469,510.26 3.00 359.30 2,000.0 28.95 285.55 1,931.6 1,875.4 152.1 -375.5 6,031,224.74 469,466.01 3.00 405.16 2,100.0 31.90 284.45 2,017.8 1,961.6 165.2 -424.4 6,031,238.02 469,417.16 3.00 455.36 2,200.0 34.85 283.52 2,101.3 2,045.1 178.5 -477.8 6,031,251.51 469,363.84 3.00 509.76 2,300.0 37.81 282.72 2,181.9 2,125.7 191.9 -535.5 6,031,265.18 469,306.20 3.00 568.21 2,400.0 40.78 282.01 2,259.3 2,203.1 205.5 -597.4 6,031,278.98 469,244.40 3.00 630.55 2,431.8 41.73 281.81 2,283.2 2,227.0 209.8 -617.9 6,031,283.39 469,223.88 3.00 651.19 Top West Sak 2,500.0 43.75 281.39 2,333.3 2,277.1 219.1 -663.2 6,031,292.87 469,178.61 3.00 696.62 2,600.0 46.73 280.83 2,403.7 2,347.5 232.8 -732.9 6,031,306.83 469,109.01 3.00 766.22 2,700.0 49.70 280.33 2,470.3 2,414.1 246.5 -806.2 6,031,320.81 469,035.78 3.00 839.18 2,800.0 52.68 279.86 2,533.0 2,476.8 260.1 -882.9 6,031,334.77 468,959.13 3.00 915.28 2,900.0 55.66 279.43 2,591.5 2,535.3 273.7 -962.8 6,031,348.67 468,879.28 3.00 994.33 2,946.6 57.05 279.25 2,617.3 2,561.1 280.0 - 1,001.1 6,031,355.12 468,841.02 3.00 1,032.11 3,000.0 57.05 279.25 2,646.4 2,590.2 287.2 - 1,045.3 6,031,362.50 468,796.83 0.00 1,075.73 3,100.0 57.05 279.25 2,700.7 2,644.5 300.7 - 1,128.1 6,031,376.32 468,714.07 0.00 1,157.42 3,200.0 57.05 279.25 2,755.1 2,698.9 314.2 - 1,211.0 6,031,390.13 468,631.31 0.00 1,239.11 3,300.0 57.05 279.25 2,809.5 2,753.3 327.6 - 1,293.8 6,031,403.95 468,548.55 0.00 1,320.80 3,400.0 57.05 279.25 2,863.9 2,807.7 341.1 - 1,376.6 6,031,417.76 468,465.79 0.00 1,402.49 2/25/2010 9:03:32AM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTOR Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +6/-W Northing Fasting DDS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 2,862.00 3,499.8 57.05 279.25 2,918.2 2,862.0 354.6 - 1,459.3 6,031,431.55 468,383.20 0.00 1,484.01 Tuffaceous Shales 3,500.0 57.05 279.25 2,918.3 2,862.1 354.6 - 1,459.4 6,031,431.58 468,383.03 0.00 1,484.17 3,600.0 57.05 279.25 2,972.7 2,916.5 368.1 - 1,542.3 6,031,445.40 468,300.27 0.00 1,565.86 3,671.0 57.05 279.25 3,011.3 2,955.1 377.7 - 1,601.1 6,031,455.21 468,241.51 0.00 1,623.86 11 3/4" 3,700.0 57.05 279.25 3,027.1 2,970.9 381.6 - 1,625.1 6,031,459.21 468,217.51 0.00 1,647.55 3,800.0 57.05 279.25 3,081.5 3,025.3 395.1 - 1,707.9 6,031,473.03 468,134.75 0.00 1,729.24 3,900.0 57.05 279.25 3,135.9 3,079.7 408.5 - 1,790.7 6,031,486.85 468,051.99 0.00 1,810.93 4,000.0 57.05 279.25 3,190.3 3,134.1 422.0 - 1,873.6 6,031,500.66 467,969.23 0.00 1,892.62 4,100.0 57.05 279.25 3,244.7 3,188.5 435.5 - 1,956.4 6,031,514.48 467,886.47 0.00 1,974.31 4,200.0 57.05 279.25 3,299.0 3,242.8 449.0 - 2,039.2 6,031,528.30 467,803.71 0.00 2,056.00 4,300.0 57.05 279.25 3,353.4 3,297.2 462.5 - 2,122.0 6,031,542.11 467,720.95 0.00 2,137.69 4,400.0 57.05 279.25 3,407.8 3,351.6 475.9 - 2,204.9 6,031,555.93 467,638.19 0.00 2,219.38 4,500.0 57.05 279.25 3,462.2 3,406.0 489.4 - 2,287.7 6,031,569.75 467,555.43 0.00 2,301.07 4,600.0 57.05 279.25 3,516.6 3,460.4 502.9 - 2,370.5 6,031,583.56 467,472.67 0.00 2,382.76 4,700.0 57.05 279.25 3,571.0 3,514.8 516.4 - 2,453.3 6,031,597.38 467,389.91 0.00 2,464.45 4,800.0 57.05 279.25 3,625.4 3,569.2 529.9 - 2,536.1 6,031,611.20 467,307.15 0.00 2,546.14 4,900.0 57.05 279.25 3,679.8 3,623.6 543.4 - 2,619.0 6,031,625.01 467,224.39 0.00 2,627.83 5,000.0 57.05 279.25 3,734.2 3,678.0 556.8 - 2,701.8 6,031,638.83 467,141.63 0.00 2,709.52 5,100.0 57.05 279.25 3,788.6 3,732.4 570.3 - 2,784.6 6,031,652.65 467,058.87 0.00 2,791.21 5,200.0 57.05 279.25 3,843.0 3,786.8 583.8 - 2,867.4 6,031,666.46 466,976.11 0.00 2,872.90 5,300.0 57.05 279.25 3,897.4 3,841.2 597.3 - 2,950.3 6,031,680.28 466,893.35 0.00 2,954.59 5,400.0 57.05 279.25 3,951.7 3,895.5 610.8 - 3,033.1 6,031,694.10 466,810.59 0.00 3,036.28 5,500.0 57.05 279.25 4,006.1 3,949.9 624.2 - 3,115.9 6,031,707.91 466,727.83 0.00 3,117.97 5,600.0 57.05 279.25 4,060.5 4,004.3 637.7 - 3,198.7 6,031,721.73 466,645.07 0.00 3,199.65 5,700.0 57.05 279.25 4,114.9 4,058.7 651.2 - 3,281.6 6,031,735.54 466,562.31 0.00 3,281.34 5,800.0 57.05 279.25 4,169.3 4,113.1 664.7 - 3,364.4 6,031,749.36 466,479.55 0.00 3,363.03 5,900.0 57.05 279.25 4,223.7 4,167.5 678.2 - 3,447.2 6,031,763.18 466,396.79 0.00 3,444.72 6,000.0 57.05 279.25 4,278.1 4,221.9 691.7 - 3,530.0 6,031,776.99 466,314.03 0.00 3,526.41 6,049.8 57.05 279.25 4,305.2 4,249.0 698.4 - 3,571.3 6,031,783.88 466,272.79 0.00 3,567.12 Brook 2b 6,100.0 57.05 279.25 4,332.5 4,276.3 705.1 - 3,612.9 6,031,790.81 466,231.27 0.00 3,608.10 6,200.0 57.05 279.25 4,386.9 4,330.7 718.6 - 3,695.7 6,031,804.63 466,148.51 0.00 3,689.79 6,300.0 57.05 279.25 4,441.3 4,385.1 732.1 - 3,778.5 6,031,818.44 466,065.75 0.00 3,771.48 6,400.0 57.05 279.25 4,495.7 4,439.5 745.6 - 3,861.3 6,031,832.26 465,982.99 0.00 3,853.17 6,500.0 57.05 279.25 4,550.1 4,493.9 759.1 - 3,944.2 6,031,846.08 465,900.23 0.00 3,934.86 6,600.0 57.05 279.25 4,604.4 4,548.2 772.6 - 4,027.0 6,031,859.89 465,817.47 0.00 4,016.55 6,700.0 57.05 279.25 4,658.8 4,602.6 786.0 - 4,109.8 6,031,873.71 465,734.71 0.00 4,098.24 6,800.0 57.05 279.25 4,713.2 4,657.0 799.5 - 4,192.6 6,031,887.53 465,651.95 0.00 4,179.93 6,900.0 57.05 279.25 4,767.6 4,711.4 813.0 - 4,275.4 6,031,901.34 465,569.19 0.00 4,261.62 7,000.0 57.05 279.25 4,822.0 4,765.8 826.5 - 4,358.3 6,031,915.16 465,486.43 0.00 4,343.31 7,100.0 57.05 279.25 4,876.4 4,820.2 840.0 - 4,441.1 6,031,928.98 465,403.67 0.00 4,425.00 7,200.0 57.05 279.25 4,930.8 4,874.6 853.4 - 4,523.9 6,031,942.79 465,320.91 0.00 4,506.69 7,300.0 57.05 279.25 4,985.2 4,929.0 866.9 - 4,606.7 6,031,956.61 465,238.15 0.00 4,588.38 2/25/2010 9:03 :32AM Page 5 COMPASS 2003.16 Build 428 • Halliburton Company 1- 1ALLlBURTO Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 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) 4,954.00 7,346.0 57.05 279.25 5,010.2 4,954.0 873.1 - 4,644.8 6,031,962.96 465,200.09 0.00 4,625.94 Top Torok Ss 7,400.0 57.05 279.25 5,039.6 4,983.4 880.4 - 4,689.6 6,031,970.43 465,155.39 0.00 4,670.07 7,500.0 57.05 279.25 5,094.0 5,037.8 893.9 - 4,772.4 6,031,984.24 465,072.63 0.00 4,751.76 7,600.0 57.05 279.25 5,148.4 5,092.2 907.4 - 4,855.2 6,031,998.06 464,989.87 0.00 4,833.45 7,700.0 57.05 279.25 5,202.8 5,146.6 920.9 - 4,938.0 6,032,011.88 464,907.11 0.00 4,915.14 7,796.4 57.05 279.25 5,255.2 5,199.0 933.9 - 5,017.9 6,032,025.20 464,827.30 0.00 4,993.91 Base Torok Ss 7,800.0 57.05 279.25 5,257.1 5,200.9 934.3 - 5,020.9 6,032,025.69 464,824.35 0.00 4,996.82 7,853.0 57.05 279.25 5,286.0 5,229.8 941.5 - 5,064.8 6,032,033.01 464,780.48 0.00 5,040.12 9 5/8" 7,900.0 57.05 279.25 5,311.5 5,255.3 947.8 - 5,103.7 6,032,039.51 464,741.59 0.00 5,078.51 8,000.0 57.05 279.25 5,365.9 5,309.7 961.3 - 5,186.5 6,032,053.33 464,658.83 0.00 5,160.20 8,100.0 57.05 279.25 5,420.3 5,364.1 974.8 - 5,269.3 6,032,067.14 464,576.07 0.00 5,241.89 8,200.0 57.05 279.25 5,474.7 5,418.5 988.3 - 5,352.2 6,032,080.96 464,493.31 0.00 5,323.58 8,295.3 57.05 279.25 5,526.5 5,470.3 1,001.1 - 5,431.1 6,032,094.12 464,414.47 0.00 5,401.40 8,300.0 57.12 279.39 5,529.1 5,472.9 1,001.8 - 5,435.0 6,032,094.78 464,410.54 3.00 5,405.27 8,400.0 58.63 282.45 5,582.3 5,526.1 1,017.8 - 5,518.1 6,032,111.18 464,327.49 3.00 5,488.24 8,500.0 60.21 285.42 5,633.2 5,577.0 1,038.6 - 5,601.7 6,032,132.26 464,244.04 3.00 5,573.36 8,600.0 61.85 288.28 5,681.6 5,625.4 1,063.9 - 5,685.4 6,032,157.97 464,160.44 3.00 5,660.42 8,700.0 63.56 291.06 5,727.5 5,671.3 1,093.9 - 5,769.0 6,032,188.24 464,076.91 3.00 5,749.16 8,800.0 65.31 293.76 5,770.6 5,714.4 1,128.3 - 5,852.4 6,032,222.97 463,993.69 3.00 5,839.36 8,850.1 66.21 295.08 5,791.2 5,735.0 1,147.2 - 5,894.0 6,032,242.04 463,952.16 3.00 5,885.03 Top Hrz 8,900.0 67.11 296.38 5,811.0 5,754.8 1,167.0 - 5,935.3 6,032,262.09 463,910.99 3.00 5,930.75 9,000.0 68.96 298.94 5,848.4 5,792.2 1,210.1 - 6,017.4 6,032,305.48 463,829.05 3.00 6,023.10 9,100.0 70.84 301.42 5,882.7 5,826.5 1,257.3 - 6,098.5 6,032,353.01 463,748.09 3.00 6,116.14 9,200.0 72.75 303.86 5,914.0 5,857.8 1,308.6 - 6,178.5 6,032,404.57 463,668.33 3.00 6,209.63 9,217.7 73.09 304.28 5,919.2 5,863.0 1,318.1 - 6,192.6 6,032,414.13 463,654.32 3.00 6,226.24 Base Hrz 9,300.0 74.69 306.24 5,942.0 5,885.8 1,363.7 - 6,257.1 6,032,460.01 463,590.00 3.00 6,303.30 9,400.0 76.66 308.58 5,966.8 5,910.6 1,422.5 - 6,334.0 6,032,519.18 463,513.30 3.00 6,396.90 9,500.0 78.65 310.88 5,988.1 5,931.9 1,485.0 - 6,409.2 6,032,581.91 463,438.44 3.00 6,490.17 9,570.6 80.06 312.48 6,001.2 5,945.0 1,531.1 - 6,461.0 6,032,628.28 463,386.79 3.00 6,555.73 Kalubik Mkr 9,600.0 80.65 313.15 6,006.1 5,949.9 1,550.8 - 6,482.2 6,032,648.04 463,365.64 3.00 6,582.86 9,700.0 82.67 315.39 6,020.6 5,964.4 1,619.9 - 6,553.1 6,032,717.37 463,295.09 3.00 6,674.72 9,716.2 83.00 315.75 6,022.6 5,966.4 1,631.3 - 6,564.3 6,032,728.89 463,283.89 3.00 6,689.49 9,800.0 83.00 315.75 6,032.9 5,976.7 1,690.9 - 6,622.4 6,032,788.70 463,226.09 0.00 6,765.90 1 9,900.0 83.00 315.75 6,045.0 5,988.8 1,762.0 - 6,691.6 6,032,860.07 463,157.13 0.00 6,857.08 9,904.4 83.00 315.75 6,045.6 5,989.4 1,765.2 - 6,694.7 6,032,863.21 463,154.10 0.00 6,861.08 j KupB wp4 GeoPoly 10,000.0 83.00 315.75 6,057.2 6,001.0 1,833.1 - 6,760.9 6,032,931.44 463,088.17 0.00 6,948.25 10,003.7 83.00 315.75 6,057.7 6,001.5 1,835.8 - 6,763.5 6,032,934.11 463,085.59 0.00 6,951.65 KupB wp4 DDPoIy 2/25/2010 9 :03:32AM Page 6 COMPASS 2003.16 Build 428 • Halliburton Company HALLIBURTOR Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wel'bore: ODSK -14 KupB Design: ODSK -14 KupB wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ */ Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 6,003.00 10,016.2 83.00 315.75 6,059.2 6,003.0 1,844.6 - 6,772.1 6,032,943.00 463,077.00 0.00 6,963.01 Kup C - KupB v4 T1A 10,100.0 85.51 315.80 6,067.6 6,011.4 1,904.4 - 6,830.3 6,033,002.98 463,019.09 3.00 7,039.59 10,181.8 87.99 315.84 6,072.2 6,016.0 1,963.0 - 6,887.2 6,033,061.77 462,962.42 3.02 7,114.57 10,200.0 87.99 315.84 6,072.8 6,016.6 1,976.0 - 6,899.8 6,033,074.87 462,949.81 0.00 7,131.26 10,261.5 87.99 315.84 6,075.0 6,018.8 2,020.1 - 6,942.7 6,033,119.16 462,907.15 0.00 7,187.71 10,300.0 89.14 315.77 6,076.0 6,019.8 2,047.7 - 6,969.5 6,033,146.83 462,880.46 3.00 7,223.01 10,329.4 90.00 315.71 6,076.2 6,020.0 2,068.8 - 6,990.0 6,033,168.00 462,860.00 2.93 7,250.06 KupB v3 T2 10,377.1 91.43 315.70 6,075.6 6,019.4 2,102.9 - 7,023.3 6,033,202.25 462,826.85 3.00 7,293.86 10,394.1 91.43 315.70 6,075.2 6,019.0 2,115.0 - 7,035.2 6,033,214.45 462,815.05 0.00 7,309.46 7" 10,400.0 91.43 315.70 6,075.0 6,018.8 2,119.3 - 7,039.3 6,033,218.68 462,810.94 0.00 7,314.88 10,500.0 91.43 315.70 6,072.5 6,016.3 2,190.8 - 7,109.1 6,033,290.51 462,741.42 0.00 7,406.74 10,600.0 91.43 315.70 6,070.0 6,013.8 2,262.4 - 7,178.9 6,033,362.33 462,671.90 0.00 7,498.61 10,700.0 91.43 315.70 6,067.5 6,011.3 2,333.9 - 7,248.8 6,033,434.15 462,602.38 0.00 7,590.47 10,734.7 91.43 315.70 6,066.7 6,010.5 2,358.7 - 7,272.9 6,033,459.04 462,578.29 0.00 7,622.30 10,761.0 90.66 315.89 6,066.2 6,010.0 2,377.6 - 7,291.3 6,033,478.00 462,560.00 3.00 7,646.49 KupB v3 T3 10,761.6 90.68 315.90 6,066.2 6,010.0 2,378.1 - 7,291.8 6,033,478.46 462,559.55 3.00 7,647.08 10,800.0 90.68 315.90 6,065.7 6,009.5 2,405.6 - 7,318.4 6,033,506.11 462,532.98 0.00 7,682.27 10,900.0 90.68 315.90 6,064.5 6,008.3 2,477.4 - 7,388.0 6,033,578.19 462,463.69 0.00 7,774.02 11,000.0 90.68 315.90 6,063.4 6,007.2 2,549.2 - 7,457.6 6,033,650.27 462,394.40 0.00 7,865.77 11,100.0 90.68 315.90 6,062.2 6,006.0 2,621.0 - 7,527.2 6,033,722.35 462,325.11 0.00 7,957.51 11,169.0 90.68 315.90 6,061.3 6,005.1 2,670.5 - 7,575.2 6,033,772.06 462,277.34 0.00 8,020.77 11,192.5 90.00 315.72 6,061.2 6,005.0 2,687.4 - 7,591.6 6,033,789.00 462,261.00 3.00 8,042.39 KupB v3 T4 11,200.0 89.77 315.72 6,061.2 6,005.0 2,692.8 - 7,596.8 6,033,794.39 462,255.78 3.00 8,049.28 11,238.2 88.63 315.72 6,061.7 6,005.5 2,720.1 - 7,623.5 6,033,821.85 462,229.22 3.00 8,084.38 11,300.0 88.63 315.72 6,063.2 6,007.0 2,764.4 - 7,666.6 6,033,866.25 462,186.28 0.00 8,141.14 11,400.0 88.63 315.72 6,065.6 6,009.4 2,835.9 - 7,736.4 6,033,938.09 462,116.78 0.00 8,233.00 11,500.0 88.63 315.72 6,068.0 6,011.8 2,907.5 - 7,806.2 6,034,009.94 462,047.27 0.00 8,324.85 11,600.0 88.63 315.72 6,070.4 6,014.2 2,979.1 - 7,876.0 6,034,081.79 461,977.77 0.00 8,416.70 11,700.0 88.63 315.72 6,072.8 6,016.6 3,050.6 - 7,945.8 6,034,153.63 461,908.27 0.00 8,508.55 11,800.0 88.63 315.72 6,075.2 6,019.0 3,122.2 - 8,015.6 6,034,225.48 461,838.77 0.00 8,600.40 11,900.0 88.63 315.72 6,077.6 6,021.4 3,193.8 - 8,085.4 6,034,297.32 461,769.27 0.00 8,692.26 12,000.0 88.63 315.72 6,080.0 6,023.8 3,265.4 - 8,155.2 6,034,369.17 461,699.77 0.00 8,784.11 12,100.0 88.63 315.72 6,082.4 6,026.2 3,336.9 - 8,225.0 6,034,441.02 461,630.27 0.00 8,875.96 12,200.0 88.63 315.72 6,084.8 6,028.6 3,408.5 - 8,294.8 6,034,512.86 461,560.77 0.00 8,967.81 12,300.0 88.63 315.72 6,087.2 6,031.0 3,480.1 - 8,364.6 6,034,584.71 461,491.27 0.00 9,059.67 12,343.6 88.63 315.72 6,088.2 6,032.0 3,511.2 - 8,395.0 6,034,616.00 461,461.00 0.00 9,099.67 Start Dir 3.0/100' 12343.60' MD, 6088.20' TVD - KupB v4 T5 12,369.1 87.86 315.72 6,089.0 6,032.8 3,529.5 - 8,412.9 6,034,634.35 461,443.25 3.00 9,123.13 End Dir 12369.10' MD, 6089.00' TVD 12,400.0 87.86 315.72 6,090.1 6,033.9 3,551.6 - 8,434.4 6,034,656.54 461,421.78 0.00 9,151.50 2/25/2010 9 :03 :32AM Page 7 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTOle Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 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) 6,037.67 12,500.0 87.86 315.72 6,093.9 6,037.7 3,623.2 - 8,504.2 6,034,728.36 461,352.31 0.00 9,243.32 12,600.0 87.86 315.72 6,097.6 6,041.4 3,694.7 - 8,574.0 6,034,800.18 461,282.84 0.00 9,335.13 12,700.0 87.86 315.72 6,101.3 6,045.1 3,766.3 - 8,643.7 6,034,872.00 461,213.37 0.00 9,426.94 12,800.0 87.86 315.72 6,105.1 6,048.9 3,837.8 - 8,713.5 6,034,943.81 461,143.89 0.00 9,518.76 12,900.0 87.86 315.72 6,108.8 6,052.6 3,909.3 - 8,783.3 6,035,015.63 461,074.42 0.00 9,610.57 13,000.0 87.86 315.72 6,112.5 6,056.3 3,980.9 - 8,853.0 6,035,087.45 461,004.95 0.00 9,702.39 13,100.0 87.86 315.72 6,116.3 6,060.1 4,052.4 - 8,922.8 6,035,159.27 460,935.48 0.00 9,794.20 13,200.0 87.86 315.72 6,120.0 6,063.8 4,124.0 - 8,992.6 6,035,231.08 460,866.01 0.00 9,886.02 13,300.0 87.86 315.72 6,123.7 6,067.5 4,195.5 - 9,062.3 6,035,302.90 460,796.54 0.00 9,977.83 13,400.0 87.86 315.72 6,127.4 6,071.2 4,267.0 - 9,132.1 6,035,374.72 460,727.06 0.00 10,069.64 13,500.0 87.86 315.72 6,131.2 6,075.0 4,338.6 - 9,201.9 6,035,446.54 460,657.59 0.00 10,161.46 13,600.0 87.86 315.72 6,134.9 6,078.7 4,410.1 - 9,271.7 6,035,518.36 460,588.12 0.00 10,253.27 13,700.0 87.86 315.72 6,138.6 6,082.4 4,481.7 - 9,341.4 6,035,590.17 460,518.65 0.00 10,345.09 13,800.0 87.86 315.72 6,142.4 6,086.2 4,553.2 - 9,411.2 6,035,661.99 460,449.18 0.00 10,436.90 13,843.5 87.86 315.72 6,144.0 6,087.8 4,584.3 - 9,441.5 6,035,693.23 460,418.96 0.00 10,476.84 Total Depth at 13843.60' MD, 6144.00' TVD 13,843.6 87.86 315.72 6,144.0 6,087.8 4,584.4 - 9,441.6 6,035,693.29 460,418.90 0.00 10,476.92 KupB v6 T6 2/25/2010 9:03:32AM Page 8 COMPASS 2003.16 Build 42B • • Halliburton Company HALLIBURTOle Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD. Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Welibore: ODSK -14 KupB Design: ODSK -14 KupB wp06 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting - Shape ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) KupB v4 T5 0.00 0.00 6,088.2 3,511.2 - 8,395.0 6,034,616.00 461,461.00 - plan hits target - Point KupB v3 T4 0.00 0.00 6,061.2 2,687.4 - 7,591.6 6,033,789.00 462,261.00 - plan hits target - Point KupB v3 T3 0.00 0.00 6,066.2 2,377.6 - 7,291.3 6,033,478.00 462,560.00 - plan hits target - Point KupB v4 T1A 0.00 0.00 6,059.2 1,844.6 - 6,772.1 6,032,943.00 463,077.00 - plan hits target - Point KupB wp4 DDPoIy 0.00 0.00 6,088.2 1,904.3 - 6,687.8 6,033,002.29 463,161.55 - plan misses by 106.5ft at 10003.7ft MD (6057.7 TVD, 1835.8 N, - 6763.5 E) - Polygon Point 1 6,088.2 1,904.3 - 6,687.8 6,033,002.29 463,161.55 Point2 6,088.2 3,583.2 - 8,321.2 6,034,687.63 461,535.14 Point 3 6,088.2 3,439.1 - 8,469.0 6,034,544.15 461,386.77 Point4 6,088.2 1,761.9 - 6,833.9 6,032,860.50 463,014.89 KupB v6 T6 0.00 0.00 6,144.0 4,584.4 - 9,441.6 6,035,693.29 460,418.90 - plan hits target - Point KupB v3 T2 0.00 0.00 6,076.2 2,068.8 - 6,990.0 6,033,168.00 462,860.00 - plan hits target - Point KupB wp4 GeoPoly 0.00 0.00 6,088.2 1,611.9 - 6,844.5 6,032,710.60 463,003.70 - plan misses by 218.5ft at 9904.4ft MD (6045.6 TVD, 1765.2 N, - 6694.7 E) - Polygon Point 1 6,088.2 1,611.9 - 6,844.5 6,032,710.60 463,003.70 Point2 6,088.2 3,399.2 - 8,651.6 6,034,505.04 461,204.05 Point 3 6,088.2 3,766.3 - 8,278.2 6,034,870.58 461,578.90 Point4 6,088.2 1,912.1 - 6,538.8 6,033,009.53 463,310.58 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,671.0 3,011.3 113/4" 11.750 14.500 7,853.0 5,286.0 9 5/8" 9.625 11.750 10,394.1 6,075.2 7" 7.000 8.500 13,843.6 6,144.0 41/2" 4.500 6.125 2/25/2010 9:03:32AM Page 9 COMPASS 2003.16 Build 42B • Halliburton Company HALLIBURTOM Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp06 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ?) ( ?) 9,217.7 5,919.2 Base Hrz 8,850.1 5,791.2 Top Hrz 1,706.8 1,666.2 Base of Permafrost 0.00 2,431.8 2,283.2 Top West Sak 7,796.4 5,255.2 Base Torok Ss 0.00 9,570.6 6,001.2 Kalubik Mkr 6,049.8 4,305.2 Brook 2b 3,499.8 2,918.2 Tuffaceous Shales 7,346.0 5,010.2 Top Torok Ss 0.00 10,016.2 6,059.2 Kup C Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /$ +E/-W (ft) (ft) (ft) (ft) Comment 12,343.6 6,088.2 3,511.3 - 8,395.1 Start Dir 3.0/100' 12343.60' MD, 6088.20' TVD 12,369.1 6,089.0 3,529.5 - 8,412.9 End Dir 12369.10' MD, 6089.00' TVD 13,843.5 6,144.0 4,584.3 - 9,441.5 Total Depth at 13843.60' MD, 6144.00' TVD I I 2/25/2010 9 :03 :32AM Page 10 COMPASS 2003.16 Build 428 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 ODSK -14 KupB ODSK -14 KupB wp06 Sperry Drilling Services Clearance Summary Anticollision Report 25 February, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp06 Well Coordinates: 6,031,071.09 N, 469,840.87 E (70° 29' 45.45" N, 150° 14' 47.80" W) • Datum Height: 42.T + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 12,344.0 to 13,843.6 ft. Measured Depth. Scan Radius is 1,580.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42B Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2010 02 24T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 ,1A,1 Depth Range From: 12344.0 To 13843.6 Depth From Depth To Survey/Plan Tool 'F'+ TO TD Results Limited By: Centre Distance: 1580.1 42.7 1293.0 ODSK -14 KupB wp06 SR- Gyro -SS Reference: Plan: ODSK -14 KupB wp06 (ODSK- 141ODSK -14 KupB) 1293.0 13842.6 ODSK -14 KupB wp06 MWD+IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference o 1u From Color To MD 30 30 330 � 43 250 ` --- 30 _-- _._ -_ i 250 500 - ' 500 - 750 750 _._. 1000 , 2i _ 1000 1250 300 � , 60 1250 1500 _ ,,, , +4 `_` . ‚$ 1500 1750 • 1750 2000 � 2000 2250 l 2250 - 2500 g1 2500 - 2750 270 90 _ (� 2750 3000 I 3000 -- 4000 } &Ail 4000 5000 , ` 270 • 90 �5000 6000 ��, ";�,� t • i r 6000 -.. 7000 7000 600-6 240 ,,` , � 120 8000 - 9000 ,� ,� 9000 - ' 10000 wo 1 0000 - -_. 11000 11000 12000 ``` 210 150 • ,, 1 1300 , r 13000 14000 240 120 ._ _ 14000 _ 15000 ' ,' 15000 16000 � ' 16000 17000 180 17000 18000 210 ' 150 18000 -" 19000 19000 - 20000 Travelling Cylinder Azimuth (TFO+A71) [ ?] vs Centre to Centre Separation [20 ft /in] 11 20000 `- 21000 180 BECTONDETALS Sec MD he An 1VD +WS +EAW DLeg TFace VSec Target /� 1 427 000 000 427 0.0 0.0 000 000 00 Travelling Cylinder Azimuth (TFO+AZI) [ ?] vs Centre to Centre Separation 150 ft /in] 2 3000 000 0.00 300.0 00 0.0 000 600 0.0 3 6000 300 300.00 599.9 3.9 38 1 0 300.00 7.8 4 7500 600 30000 7494 98 -17.0 200 00 19.5 5 9833 1300 30000 9794 91 -60.3 300 0.00 57.6 REFERENCE INFORMATION 16892 2303 28855 16500 1129 -2505 1.0 -250 2747 Well Planning - Pioneer - Oooguruk 7 1797.9 2303 288.55 17500 1264 -2908 000 000 317.1 8 2946 6 57.05 27925 26173 280.0 -101.1 3.00 -13 87 1032.1 9 8295.3 57.05 27925 55265 1011 3431.1 0.0 000 54014 Co-ordinate (N/E) Reference: WeIIODSK- I4- Slot 005- 14,True North Calculation Method: Minimum Curvature 10 97162 8300 31575 60226 18313 -65643 30 6068 6689.5 Vertical (TVD) Reference: 42.7' +13.5' @56.2ft (Nabors l9AC) 11 10016.2 83.00 31575 60592 18446 37721 000 00 69630 KupB v4 T1A Error System: ISCWSA 12 10181.8 8799 31584 60722 19630 -6887.2 300 108 71146 Section (VS) Reference: Slot - ODS- 14(0.0N, 0.0E) 13 10261.5 87.99 315.84 60750 9201 39427 000 0 00 1029 7187.7 Measured Depth Reference: 42.7' +13.5'@ 56.2ft (Nabors l9AC) Scan Method: Tray. Cylinder North 141 90.00 3 1 5. 70 60756 20688 -6990.0 30 -391 72501 KupB v3 T2 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 16 10734.7 91.43 315.70 60667 2358.7 -72729 0.00 699 76223 v3 73 Warning Method: Rules Based 18 107616 909086 .48 31590 60662 23781 -7291 8 300 165 14.87 75477.1 KupB 3 19 111690 0.88 31590 6061.3 26705 - 75752 0.0 00 80208 20 111920 90 0 315 72 60612 26874 - 75910 3 0 -16513 80424 KupB v3 74 21 112382 8863 31572 6061.7 27201 -78235 300 - 180.0 80844 22 123436 88 63 315 72 60882 3511 2 -8395 0 0.00 0 0 099.7 KupB v4 T5 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -14 23 123601 8786 31572 60890 35295 -84129 3.00 179.96 91232 24 138436 8786 31572 61440 4584.4 -94410 000 000 104769 KupB v6 T6 Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS -14 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp06 Scan Range: 12,344.0 to 13,843.6 ft. Measured Depth. Scan Radius is 1,580.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSN -16 - ODSN -16 PN11 - ODSN -16 PN11 wp03 12,352.7 1,513.0 12,352.7 1,020.7 14,525.0 3.073 Clearance Factor Pass - Major Risk • Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 42.7 1,293.0 ODSK -14 KupB wp06 SR- Gyro-SS 1,293.0 13,842.6 ODSK -14 KupB wp06 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. - 25 February, 2010 - 9:21 Page 2 of 4 COMPASS • 1110 , From the successful cementing operations of the Surface Casing 1. ND Riser, NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 2. MU 10 -5/8" x 11 -3/4" BHA, MWD /LWD (BHA will be a 10 -5/8" pilot hole opened to 11 -3/4" while drilling). 3. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 4. Drill through surface shoe, rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 5. Drill 10 -5/8" x 11 -3/4" Intermediate 1 to casing point. 6. Circulate and condition the hole to run the 9 -5/8" Drilling Liner. POOH. 7. Change one set of pipe rams to 9 -5/8" and test BOPE as required. 8. Run 9 -5/8" drilling liner on 5" DP. Set liner hanger, release from liner and cement. 9. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 10. Release pressure and ensure floats are holding • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 11. Set liner top packer and test the liner top and the liner top to 3500 psi for 5 minutes • This will check the integrity of the liner top packer to ensure isolation between the liner and the surface casing • Note the pressure test of the liner top in the morning report Note: The surface casing was pressure tested to 3500 psi for 30 minutes prior to drilling out the surface casing shoe 12. POOH w/ 5" DP. 13. ND Drilling spool, NU BOPE and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test. • Ensure integrity of the liner and the liner top has been verified by a pressure test prior to performing this step 14. Close blind rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi for 30 minutes -- chart and send to ODE. 4 " i S ctr u 04.4.' 0 c- s-� 4`4'4. 6 Np p 1.1 4 -es-t-,4,1• 'f' - 9 54 „ d r ; y►- ) / -t- C 1 • 44, -1--4.:-._ C4s eL-cf 4 c-r‘c- { " d irt O A..„-L4...4- tve1.14-- 4" r j 7 /L /?•471'10 Page 1 of 1 • PIONEER Operations Summary Report NATURAL. RESOURCES - - Start Time End Time Dur (hrs) Op Step Phase P/N Comment 12:00 13:00 1.00 CIRC PP CBU. * GPM 420, ICP 2,400 psi, FCP 2,350 psi. * PUW 160k, SOW 120k. 13:00 14:00 1.00 CSG _ - PP Remove wFT cement head and UD same. 14:00 16:00 2.00 TRIP PP POH w/ WFT Liner Running Tool f/ 3,400' - t/ 784'. 16:00 19:30 3.50 BHA PP POH & UD 9 Jts 5" HWDP, WFT Bumper Sub, 7 x 8 " DC's and WFT Liner Running Tool. UD 3 x 8" Flex DC's from derrick. 19:30 20:30 1.00 BHA PP Clear and clean rig floor. Clean rotary table drip pan. 20:30 23:00 2.50 BOPS PP NiDDritliog,Riser, BOPEs-and Riser. Pits. 23:00 00:00 1.00 WLHEAD PP Remove VG Intermediate 1 QDC Wellhead. Operations Report Report Start Date Report End Date 2/2/2010 2/3/2010 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 WLHEAD PP Installed VG Mutibowl Wellhead. Test seals to 250/5,000 psi. Held 10 min and charted same. 01:30 03:00 1.50 BOPS PP N/U BOPE Riser, BOPE's and Kill and Choke lines 03:00 04:00 1.00 BOPS PP Installed VG BOPE Test Plug. Change Upper Rams f/ 9-5/8" - t/ 2 -7l8 "x 5" VBR's. 04:00 07:30 3.50 RURDRT PP R/U MPD work landing. Installed Rotating Head Assy. M/U feed and return lines. 07:30 09:00 1.50 RURDRT PP Installed RHA Test Flange. Test RHA, HCR and Manual feed line valves to 250/4,500 psi. All tests held 5 min each and charted. Remove RHA Test Flange and install trip nipple. -- - -- - - - - -- - - - - - - -- - 09:00 12:00 3.00 BOPS PP Test Annular to 250/2,500 psi. Test Upper 2 -7/8" x 5" VBR's, Lower 5" Single Bore Rams, HCR Kill and Choke line valves, Manual Kill and Choke line valves, 14 Choke Manifold Valves, Floor Dart and Safety valves, Upper and Lower IBOP valves to 250/4,500 psi. All tests held 5 min each and charted. Accumulator test, Initial System Pressure 3,050 psi, Pressure After Closure 2,050 psi, Initial 200 psi attained 22 sec's, Full Pressure attained 1 min 37 sec's. Unibolt connection on Kill line leaked, tightened and retested, good test. 12:00 12:30 0.50 BOPS PP R/D BOPE test equipment. Remove Test Joint and Test Plug. Installed VG Wear Ring. 12:30 13:30 1.00 CSG PP Pressure test 11 -3/4" casing x 9-5/8" liner to 3,500 psi: Test held 30 min and charted. 13:30 15:30 2.00 BHA PP P/U & M/U BHA #11 8 -1/2" SSRS. Security FSF 2463 Bit - 7600 Geo Pilot - Geo Flex - EWR - Smart Stab - DGR/PWD - TM HOC - Stab t/ 84'. 15:30 17:00 1.50 LWD PP Download MWD program. Took 2 attempts to complete. Download successful. 17:00 19:00 2.00 BHA PP RIH w/ BHA #11. P/U 2 x Float Subs - 3 x Flex DC's - 3 x 5" HWDP t/ 272'. Shallow Pulse Test MWD at 500 gpm w/ 1,200 psi, got pulse. P/U Hyd Drilling Jars and 8 x 5" HWDP t/ 546.39'. * PUW 77k, SOW 75k. 19:00 20:30 1.50 TRIP PP RIH f/ 546' - t/ 1,975'. P/U 63 Jts DP 1 x 1 from Pipeshed. * PUW 110k, SOW 100k. 20:30 21:00 0.50 CIRC PP Fill DP and break circulation. Test MWD w/ 600 gpm at 1,520 psi, good test. 21:00 23:00 2.00 TRIP PP RIH f/ 1,975' - t/ 3,877'. * PUW 130k, SOW 95k. 23:00 00:00 1.00 CIRC PP Break in Geo - Pilot. Circulate, test MWD and Downlink Test Geo - Pilot. * RPM 60, TQ 5k. * GPM 600, PSI 1,850. * RTW 110k, PUW 130k, SOW 110k. Report Start Date Report End Date 2/3/2010 2/4/2010 Start Time End Time Dur (hrs) Op Step T Phase PM Comment - - - Page 16/16 Report Printed: 2/3 /2010 • _ _ PIONEER Operations Summary Report NATURAL RESOURCES Start Time End Time Dur (hrs) _ Op Step Phase PM Comment 20:30 21:30 1.00 CSG PP Install Casing Fill -Up tool on TD. P/U 350 ton elevators. 21:30 00:00 2.50 CSG PP RIH w/ 9-5/8" csg f/ 240' - t/ 638'. Having to push down each joint with Casing Fill -Up tool push plate. * Connection Torque = 12,500 ft/lbs. * PUW 65k, SOW 25k. * Fill every joint while slacking off. Operations Report - -___ -- - Report Start Date Report End Date 1/31/2010 2/1/2010 Start Time End T� Dur (hrs) Op 1 Step Phase I PM Comment 00:00 11:00 11.00 CSG PP RIH w/ 9 -5/8" 40# L -80 Hydril 521 Drilling Liner f/ 638' - t/ 4,422'. At 1,705' (43 Jts) liner going in the hole w/o pushing. * PUW 185k, SOW 120k. * Connection Torque, 12,600 ft/lbs. 11:00 14:00 3.00 CSG PP Remove Casing Fill -Up tool. Flush and L/D same. R/D 9 -5/8" casing handling equipment. Install 5" elevators. 14:00 16:00 2.00 CSG PP P/U WFT 10 -1/2" Liner Top Hgr /Pkr assembly (w/ 11 -3/4" Hgr Setting Ball & DP Wiper Dart installed in head). M/U same as per WFT representative. R/D Casing Power Tongs. 16:00 18:30 2.50 CSG PP P/U 7 x 8" DC and 3 x 5 "HWDP and RIH w/ 9 -5/8" Drilling liner 1/ 4,780'. No returns while RIH w/ DC's & HWDP. * PUW 205k, SOW 127k. To 19:00 0.50 CIRC PP Break circulation with step rate method starting at 1/2 bpm. Increased circulation rate in 1/2 bbl increments until 3 bpm achieved. Circulated 53 bbls. * Initial GPM 30, PSI 250. * Final GPM 130, PSI 500. * PUW 215k, SOW 150k. 19:00 00:00 5.00 CSG PP RIH w/ 9 -5/8" Drilling Liner on 5" DP f/ 4,780' - U 6,759'. Loosing 1 bph while running liner. * PUW 225k, SOW 155k. - - - -- -- --- - - - -- - - - -- Report Start Date Report End Date 2/1/2010 2/2/2010 Start Time End Time Dur (hrs) 1 Op Step Phase P/N Comment 00:00 02:00 2.00 CSG PP RIH w/ 9 -5/8" 40# L -80 Hydril 521 Drilling Liner on 5" DP f/ 6,759' -1/ 7,838'. * Running speed at 10 fpm to minimize losses. * SOW 145k. 02:00 02:30 0.50 CSG PP P/U 2 Jts 5" DP. P/U & M/U WFT TD Cement Head. RIH and set 9-5/8" shoe at 7,853'. R/U cement/circulation lines to cement head. * PUW 290k, SOW 147k. 02:30 03 :00 0.50 CIRC PP Break circulation utilizing step rate method starting at 1/2 bpm w/ 150 psi. Increased circulating rate to 4 bpm in 1/2 bpm increments w/ 700 psi FCP. 03:00 08:00 5.00 CIRC PP Drop 1 -3/4" Hgr Setting Ball and chase at 1 bpm. Increased rate to 2 bpm and then to 4 bpm. Setting Ball seated at 6,350 stks. 08:00 08:30 0.50 CSG PP Pressure up to 2,000 psi, observed Hgr slips release at 1,400 psi. Set 100k down to set Hgr slips. Increased pressure in 500 psi increments and sheared out Hgr Setting Ball w/ 3,400 psi. Rotate DP 5 rds to right and release setting tool. P/U to 160k to verify setting tool release, lost 130k string weight. 08:30 10:00 1.50 CIRC PP Circulate and condition mud /hole for cement. Utilize step rate method at 1/2 bpm for final 10 bpm pump rate at 2,650 psi. PJSM for cement job. 10:00 12:00 2.00 CSG PP Pump 10 bbls water. Test cement lines to 4,000 psi. Pump 60 bbls 12.5 ppg Dual Spacer (1.13 CuFt/Sk) at 5 bpm /600 psi. Pump 77.1 bbls 15.8 ppg Premium "G" cement (1.18 CuFt/Sk, 372 sks) at 5 bpm /1,700 psi (additives = .75% HALAD -344, .20% CFR -3, .25% Super CBL and .35% SCR -100). Drop DP Wiper Plug, observed tattletail activate. Pump 20 bbls water at 4.5 bpm /900 psi. Switch to rig and displace at 9.3 bpm with 10.0 ppg LSND mud. Slowed pumps down to 2 bpm to latch up DP Wiper Dart with 9 -5/8" wiper plug, Did Not observe latch up. Increased pump rate back to 9.3 bpm/ 2,400 psi. At 4,200 stks away slowed pumps to 2.5 bpm. Pumped Plug w/ 4,275 stks (361.7 bbls). Pressure up to 3,500 psi, held 5 mitt Released pressure and checked floats, floats held. P/U 12' (PUW 160k) to expose Pkr Setting Dogs. Set Down 80k to set Pkr, repeated process 3 times. Verified Pkr set with 50k set down weight and rotated 5 rds w/ 8k torque to mechanically set Pkr. P/U and remove packoff from Tie Back Sleeve. CIP @ 11:37 hrs. Page 15/16 Report Printed: 2/3 /2010 • Page l of 2 Schwartz, Guy L (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Wednesday, February 03, 2010 8:16 AM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Vaughan, Alex Subject: RE: ODSK -14 (PTD 209 -155) - revised summary of operations Attachments: AOGCC Permit ODSK -14 - revised summary 1- 5- 10.pdf Guy, ) About a month ago, I sent you a correction for a PTD for the well we are on, ODSK -14. In the original permit to drill, we inadvertently left off a break in the stack for a drilling spool and a BOP test. The attached document was sent to show you this break and BOP test. As I never heard back from you on questions, I made the assumption (correct or incorrect) that you had no questions about our path forward. The ODSK -14 well is the first well designed with a 9 -5/8" drilling liner. With this design, we have to use a temporary drilling spool to drill and case the drilling liner hole section, hence the break to remove the spool. In that attached revised summary of operations, we indicated that we would have a full pressure test of the 11- 3/4" surface casing and the 9 -5/8" liner prior to initiating the break in the surface stack to remove the drilling spool and install the wellhead and re- install the BOPE — this did not happen. Conditions that existed at the time of the break in the stack: 1. A pressure test of the 11 -3/4" casing to 3500 psi was done prior to drilling the drilling liner hole section a. An FIT of the surface casing shoe was done to 16.7 ppg EMW 2. The hole was drilled, cased with 9 -5/8" liner and cemented in place a. Reservoir pressure is 8.6 ppg b. 9.8 ppg drilling fluid was used for formation control and wellbore stability c. All fluids with the exception of a 10 bbl water preflush in front of the cement job with full returns and good lift pressures 3. The liner below the liner top packer was tested to 3500 psi for 5 minutes and the floats of the liner held 4. 9.8 ppg fluid was left inside the casing While the well was in a safe position during the break in the stack, it was not according to the approved permit to drill or the revised summary of operations I sent you previously. Please let me know what you need from me further on this issue. I am definitely going to be giving you a call. james James Franks Pioneer Natural Resources Alaska 907.343.2179 From: Franks, James Sent: Tuesday, January 05, 2010 1:13 PM To: 'Schwartz, Guy L (DOA)' Cc: Johnson, Vern; Vaughan, Alex Subject: ODSK -14 (PTD 209 -155) - revised summary of operations 2/3/2010 • Page 2 of 2 Guy, In the permit for the ODSK -14 well, we inadvertently left off a planned BOP test from the summary. I have included it in the attached document and highlighted the changes in yellow. Give me a shout if you would like to discuss. Happy New Year. James James Franks Pioneer Natural Resources Alaska 907.343.2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/3/2010 l ., 7- 2,7 -f Pioneer Natural Resources Well Plan K -14 Summary Drilling Operations (,, p A pra u +- K Qlei sic( 6rc.• Pre -Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rio Activity: Drill and Complete 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 14 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11 -3/4" surface casing. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC i needed. 6. ND Riser, NU Drilling Speol and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 7. MU 10 -5/8" x 12 -1/4" BHA, MWD /LWD (BHA will be a 10 -5/8" pilot hole opened to 12 -1/4" while drilling). 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 9. Drill through surface shoe, rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 10. Drill 10 -5/8" x 12 -1/4" Intermediate 1 to casing point. 11. Circulate and condition the hole to run the 9 -5/8" drilling liner. POOH. 12. Change one set of pipe rams to 9 -5/8" and test BOPE as required. 13. Run 9 -5/8" drilling liner on 5" DP. Set liner hanger, release from liner and cement. 14. Bump the plug, release pressure and ensure floats are holding, set liner hanger packer. .L- 15. Close . alii rardand test drilling liner to 3500 psi for 30 minutes -- chart and send to ODE. 16. POOH w/ 5" DP. 17. ND Meng spool, NU BOPS and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test 18. MU 8 -1/2" directional drilling, MWD /LWD on 5" DP. RU MPD trip nipple. 19. RIH and cleanout casing to landing collar. 20. Drill through drilling liner shoe + 20' of new hole and perform LOT to a minimum of 12.5 ppg, however, should the test reach a 14.0 ppg EMW FIT without breaking over, we do not need to take the test to LOT. 21. RD MPD trip nipple and RU bearing assembly. Drill 8 -1/2" Intermediate 2 to casing point. 22. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 23. Change one set of pipe rams to 7" and test BOPE as required. 24. Run and cement the 7" intermediate casing. 25. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Release pressure and ensure floats are holding. 26. LD 5" DP 27. Change pipe rams to 4" and test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 28. PU 4" DP as needed to TD the Production hole section. 29. MU 6 -1/8" MWD /LWD motor drilling assembly on 4" DP. RU MPD trip nipple. RIH and cleanout Pioneer Natural Resources Last Revised: January 5, 2010 ODSK -14 Permit To Drill Page 1 of 2 to landing collar. RD MPD trip nipple and RU bearing assembly. 30. Drill through Intermediate 2 shoe, rathole + 20' of new hole and perform FIT to 12.5 ppg. 31. Displace to drill -in -fluid for production lateral. 32. Drill 6 -1/8" lateral production hole to TD. 33. Circulate and condition the hole to run liner. 34. Change one set of pipe rams to 4 -1/2" and test BOPE as required. 35. RIH w/ 4 -1/2" slotted production liner from 150' inside the intermediate shoe to TD. 36. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 37. MU ESP completion and RIH. 38. Land the tubing and RILDS. Install TWC. 39. ND BOPE, NU tree and test to 5,000 psi. 40. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 41. 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. 42. 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: January 5, 2010 ODSK -14 Permit To Drill Page 2 of 2 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 21, 2010 10:06 AM To: 'Franks, James' Subject: RE: ODSK -14 (PTD 209 -155) - reservoir pressure determination James, The commission has no problem with the proposed operation to determine Kuparuk sand reservoir pressure as outlined in the attachment. You have permission to proceed as outlined below. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Franks, James [mailto:James.Franks @pxd.com] Sent: Wednesday, January 20, 2010 2:07 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Hazzard, Vance; Delmonico, Joe; Vaughan, Alex Subject: RE: ODSK -14 (PTD 209 -155) - reservoir pressure determination Guy, Attached is what we would like to propose as a plan to determine the reduced pressure in the Kuparuk due to the off take. Please let me know how you would like to move forward to approve this plan or what further information you need. Take care, james James Franks Pioneer Natural Resources Alaska 907.343.2179 From: Franks, James Sent: Tuesday, January 12, 2010 12:29 PM To: 'Schwartz, Guy L (DOA)' Cc: Johnson, Vern Subject: ODSK -14 (PTD 209 -155) - reservoir pressure determination Guy, The permit for K -14 was written including original pressure as the guiding factor in the mud weight and the back - pressure we hold with our Managed Pressure Drilling (MPD) process. Based on the production from ODSK -33, we are wondering if we can deviate from the back pressure held with MPD by verifying the reservoir pressure 1/21/2010 Page 2 of 2 once we drill into the reservoir? Below is a bit on our reasoning: Reasons for needing to determine reservoir pressure: • Due to off take from the reservoir, the pressure has dropped. o Using a 9.8 ppg EMW reservoir pressure is no longer accurate • The Kuparuk reservoir is highly fractured in nature and losses have been seen on many wells. o As we are drilling utilizing MPD, we have a lot of flexibility in `dialing in' the back pressure we need to hold to keep the reservoir in check and reduce the fluid lost to the reservoir in a partial loss situation. Assumptions: • Original Kuparuk reservoir pressure is 3100 psi (9.8 ppg EMW) • ODSK -33 BHP = 2500 psi (7.88 ppg EMW) I have a plan drafted for this, but still need to review it with Vern to make sure we are on the same page, but would this be something the State might consider? What documentation would you need to see? Thanks! james James Franks Pioneer Natural Resources Alaska 907.343.2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/21/2010 • /77 261, ASS Kuparuk Reservoir Pressure determination plan - draft Reasons for needing to determine reservoir pressure: • Due to off take from the reservoir, the pressure has dropped. o Using a 9.8 ppg EMW reservoir pressure is no longer accurate • The Kuparuk reservoir is highly fractured in nature and losses have been seen on many wells. o As we are drilling utilizing MPD, we have a lot of flexibility in `dialing in' the back pressure we need to hold to keep the reservoir in check and reduce the fluid lost to the reservoir in a partial loss situation. Assumptions: • Original Kuparuk reservoir pressure is 3100 psi (9.8 ppg EMW) • July 09 K -14 BHL estimate = 2800 psi (9.0 ppg EMW) o See attached slide • ODSK -33 BHP = 2500 psi (7.88 ppg EMW) Well condition: • The 7" Longstring is set into the top of the Kuparuk and cemented in place. • The cement job was displaced with an underbalanced fluid o 8.6 ppg WBM • BHA is picked up and we have drilled to, but not broken through, the float shoe. • RCD bearing assembly is installed and we are lined up to take returns through the MPD choke. Procedure: 1. Drill out the remaining shoe track, rat hole and 20' of new formation while holding back pressure at the shoe of 9.8 ppg EMW and taking returns through the MPD choke. 2. Pull back into the casing and perform FIT as planned. a. During the FIT, ensure Pressure vs Volume is tracked and recorded 3. Once the FIT is complete and with the bit in the casing, lower the backpressure held on the surface to a 9.8 ppg EMW at the shoe ( -374 psi surface pressure with an 8.6 ppg fluid) 4. Bleed off pressure at the surface to lower the EMW at the shoe by 0.2 ppg ( -62 psi and <2 gallons of fluid). 5. Shut the well in and watch the casing pressure for 5 minutes or until stable. a. If the casing pressure is rising, assume that the well is underbalanced to the formation. i. Increase the backpressure held at the surface to the last over - balanced test point and circulate bottoms up to remove any wellbore fluids that may have entered. b. If the casing pressure is static, repeat the process as needed to find the reservoir pressure. Confidential 0 0 6. Once the reservoir pressure has been determined, hold this pressure at the intermediate casing shoe while drilling ahead. Reservoir Pressure at Dev. Locations PIONEER 1 i 1 Reservoir Pressure at Dev. Locations 8 1 U28 1 -SP-2006 1 NOV 2011.03 1-JAN-20C673 1 . WA .2009 i •MAY. 2009 1 .JUL -2009 1 A W - — --- : 7: : : — - — -- — " — — 1 : — --- --- w - --- ---- - — --- — - ---- --- - ---- — - — ---- '''."- -- - - % . ----_____ ------------„,„.„ . - \ \ \ ■ - lf, r::-.• 1 I .c .9 8 ' ) 11 •,-,,, '-.....--._ 1 (i) I .• .,, -______ t . — 1 co - i' 111 K-14 BHL . \ i i: 1,111-2008 1.5E1)12008 1 4W.20113 1 .JAft. 2009 1.1441?-2009 1-MAY.2009 1 ML•2009 [ -- Well KUPG Wei Ku* 1 — well Kurk 2 — Vvel Kuril I Wel KUal 2 ! Confidential • Page 1 of 2 Schwartz, Guy L (DOA) -/ 3 S From: Vaughan, Alex [AIex.Vaughan @pxd.com] Sent: Monday, February 01, 2010 10:24 AM To: Schwartz, Guy L (DOA) Subject: RE: ODSK -14 sidetrack information Attachments: ODSK -14 KupB wp04.b Plan View with PB1Small Scale.pdf; ODSK -14 KupB wp04.b Section View with PB1 Small Scale.pdf; ODSK -14 KupB wp04.b Section View with PB1.pdf; ODSK -14 KupB wp04.b Plan View with PB1.pdf Sorry, I forgot to attach it. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.226.2180 (Cosmo Rig) 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Monday, February 01, 2010 10:21 AM To: Vaughan, Alex Subject: RE: ODSK -14 sidetrack information Thanks Alex... Can you please try and resend the attachment. It got lost in Cyberspace. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Thursday, January 28, 2010 2:19 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern Subject: ODSK -14 sidetrack information Guy, As discussed with Vern Johnson we have inadvertently sidetrack the well ODSK -14. After drilling to intermediate 1 section TD of 7,853'MD with a 10 -5/8" bit we pulled out of hole to pick up a 10- 5/8" bit and 10 -5/8" to 11 -3/4" hole opener. We ran in hole with hole opening assembly to 3,585' MD (surface shoe @ 3,556' MD) and functioned reamer. We opened hole from 10 -5/8" to 11 -3/4" to 4,534' MD where we tagged up on a hard streak. Drilling parameters were adjusted and we continued to open hole down to 4,660' MD where it was confirmed we had sidetracked. The 10 -5/8" to 11 -3/4 "hole opener was laid down and we ran in hole with a 10 -5/8" bit and confirmed sidetrack depth at 4,550' MD. We continued to drill ahead as per plan 2/2/2010 Page 2 of 2 to new intermediate 1 section TD after making a failed attempt to re -enter original hole. Deviation from original borehole and sidetrack was 20.82' at greatest point. Please see attached section view of original ODSK -14 intermediate 1 borehole and sidetrack. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.226.2180 (Cosmo Rig) 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/2/2010 PIONEER Project: Oooguruk Development WALLIBURT ©N Site: Oooguruk Drill Site Well: ODSK -14 Wellbore: ODSK -14 KupB Plan: ODSK -14 KupB wp04.b - p Zak —/ 1120- 1080- ODSK - 14 KupB wp04 b 1040 1000- ODSK -14 P131 KupB 9 5/8" 960 — p_ 920 — a 880- 0 ODSK - 14 KupB _. + 840— z 800- - o — 760— • 720 - 680- 640 — 600 — 560 — 520 — 11[i 1111111i pi it! [11111 ri II -5480 -5440 -5400 -5360 -5320 -5280 -5240 -5200 -5160 -5120 -5080 -5040 -5000 - 4960 - 4920 - 4880 - 4840 - 4800 - 4760 - 4720 - 4680 - 4640 - 4600 -4560 West( - )/East( +) (100 ft/in) PIONEER Project: Oooguruk Development HALLIBURTON NATURAL � ESOURCE.S Site: Oooguruk Drill Site Sperry Drilling Well: ODSK -14 Wellbore: ODSK -14 KupB Plan: ODSK -14 KupB wp04.b 4800 — 4840 — 4880 — • 4920— 4960 — 5000 — c 5040 — 0 5080— _ - a - a) - 0 5120 — a> 5160 — 5200— OODSK - 14 KupB ODSK - 14 PB1 KupB 5240 — 5280 — 5320— 9 5/8 5360 �� - ODSK - 14 KupB wp04.b 5400 — 4520 4560 4600 4640 4680 4720 4760 4800 4840 4880 4920 4960 5000 5040 5080 5120 5160 5200 5240 5280 5320 5360 5400 5440 Vertical Section at 292.70? (100 ft/in) PIONEER " Project: Oooguruk Development HALLIBURT ©N ,,. ce Site: Oooguruk Drill Site -- � Well: ODSK -14 Sperry Drilling Wellbore: ODSK -14 KupB Plan: ODSK -14 KupB wp04.b -600 — 0— 600 = 1200 — 1800 — 2400- 2_ 0 3000— �� - - -- 113/4" . - aa) 3600 — c� - ; 4200 — > - a> ODSK -14 PB1 KupB 1 11 1 1. 4800- 5400— _ - 9 5/8" ODSK -14 KupB ODSK -14 KupB wp04.b 6000— . 4 1/2" 6600— 7200- 7800 — 111111111111111 n jIIII 111111 m 11111I1r T1111111 m 111111 I n 11111 l III1 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section at 292.70° (1500 ft/in) PIONEER Project: Oooguruk Development HALLUBURTON Site: Oooguruk Drill Site Well: ODSK -14 Sperry Drilling Wellbore: ODSK -14 KupB Plan: ODSK -14 KupB wp04.b 5200 - 4800- 1 4400 - • ODSK - 14 KupB wp04. h 4000- i 3600- 4 1/2"_ Ii 3200 _ 4 2800- I - - O o - 2400 - I _ + - I �j^ I 2000- Ii - - I 1600- - ODSK -14 PB I KupB • 1200- 9 5/8" 800 11 3/4" OW. -14 KupB g 400- - e 0- -400 - -800 - -8800 -8400 -8000 -7600 -7200 -6800 - 6400 -6000 -5600 -5200 - 4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 - 800 - 400 0 400 West( - )/East( +) (1000 ft/in) HALLIBURTON WELL DETAILS: ODSK -14 REFERENCE INFORMATION Co- ordinate (N/E) Reference: Well ODSK -14 - Slot ODS -14, True North Ground Level: 13.5 Vertical (TVD) Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) k,i.a.aiiiiiic umi i. a Sperry Drilling +N / -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS-14 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO - ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Name TVD +N / -S +E / -W Northing Easting Shape KupB v4 T1A 6059.2 1844.6 - 6772.1 6032943.00 463077.00 Point Calculation Method: Minimum Curvature Site: Oooguruk Drill Site KupB v3 T4 6061.2 2687.4 - 7591.6 6033789.00 462261.00 Point Error System: ISCWSA Well: ODSK -14 KupB v3 T3 6066.2 2377.6 - 7291.3 6033478.00 462560.00 Point Scan Method: Tray. Cylinder North KupB v3 T2 6076.2 2068.8 - 6990.0 6033168.00 462860.00 Point Error Surface: Elliptical Conic Wellbore: ODSK -14 KupB KupB v4 T5 6088.2 3511.2 - 8395.0 6034616.00 461461.00 Point WamingMethod: Rules Based Plan: ODSK -14 KupB wp06 KupB wp4 DDPoIy 6088.2 1904.3 - 6687.8 6033002.29 463161.55 Polygon KupB wp4 GeoPoly 6088.2 1611.9 - 6844.5 6032710.60 463003.70 Polygon KupB v6 T6 6144.0 4584.4 - 9441.6 6035693.29 460418.90 Point -600 SECTION DETAILS Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 0- 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 - 3 600.0 3.00 300.00 599.9 3.9 -6.8 1.00 300.00 7.8 - 4 750.0 6.00 300.00 749.4 9.8 -17.0 2.00 0.00 19.5 - 5 983.3 13.00 300.00 979.4 29.1 -50.3 3.00 0.00 57.6 • 600 6 1689.2 23.03 288.55 1650.0 112.9 -250.5 1.50 -25.00 274.7 - 7 1797.9 23.03 288.55 1750.0 126.4 -290.8 0.00 0.00 317.1 - 8 2946.6 57.05 279.25 2617.3 280.0 - 1001.1 3.00 -13.87 1032.1 - 9 8295.3 57.05 279.25 5526.5 1001.1 - 5431.1 0.00 0.00 5401.4 - 10 9716.2 83.00 315.75 6022.6 1631.3 - 6564.3 3.00 60.68 6689.5 1200 11 10016.2 83.00 315.75 6059.2 1844.6 - 6772.1 0.00 0.00 6963.0 KupB v4 T1A 26 12 10181.8 87.99 315.84 6072.2 1963.0 - 6887.2 3.00 1.08 7114.6 13 10261.5 87.99 315.84 6075.0 2020.1 - 6942.7 0.00 0.00 7187.7 - 14 10329.4 90.00 315.71 6076.2 2068.8 - 6990.0 3.00 -3.91 7250.1 KupB v3 T2 - 1800 15 10377.1 91.43 315.70 6075.6 2102.9 - 7023.3 3.00 -0.25 7293.9 16 10734.7 91.43 315.70 6066.7 2358.7 - 7272.9 0.00 0.00 7622.3 - 17 10761.0 90.66 315.89 6066.2 2377.6 - 7291.3 3.00 165.79 7646.5 KupB v3 T3 c - �� 18 10761.6 90.68 315.90 6066.2 2378.1 - 7291.8 3.00 14.87 7647.1 2400 19 11169.0 90.68 315.90 6061.3 2670.5 - 7575.2 0.00 0.00 8020.8 h� 20 11192.5 90.00 315.72 6061.2 2687.4 - 7591.6 3.00 - 165.13 8042.4 KupB v3 T4 ° 0 1 DDI = 6.45 21 11238.2 88.63 315.72 6061.7 2720.1 - 7623.5 3.00 - 180.00 8084.4 t.r) _ 11 3/4" 22 12343.6 88.63 315.72 6088.2 3511.2 - 8395.0 0.00 0.00 9099.7 KupB v4 T5 � �� - 23 12369.1 87.86 315.72 6089.0 3529.5 - 8412.9 3.00 179.96 9123.2 L 3000 24 13843.6 87.86 315.72 6144.0 4584.4 - 9441.6 0.00 0.00 10476.9 KupB v6 T6 a L tD a - 3600 - a) - 4■ > a) 4200- Start Dir 3.0/100' 12343.60' MD, 6088.20' TVD 2 H - End Dir 12369.10' MD, 6089.00' TVD - S I 4800- \ CASING DETAILS \ - 9 5/8" - 1VD MD Name Size o - \ � Total Depth at 13843.60' MD, 6144.00' TVD 5400 3011.3 3671.0 113/4" 11.750 O 5286.0 7853.0 9 5/8" 9.625 GD \ 1 _ 6075.2 10394.1 7" 7.000 ` - 6144.0 13843.6 4 1/2" 4.500 ro 7 t t l / 6000- . ' 5 I , ' 4 1/2" - , I' I S ` / 1 I \ I / ` - I ` \ ` ODSK -14 KupB wp06 6600 SURVEY PROGRAM ' 1 l / KupB v4 TIP i KupB v3 T3 `\ KupB v4 T5 / Date: 2010 -02- 24700:00:00 Validated: Yes Version: 1 \ KupB v6 T6 7200 - Depth From Depth To Survey /Plan Tool KupB v3 T2 KupB v3 T4 - 42.7 1293.0 ODSK -14 KupB wp06 SR- Gyro -SS - 1293.0 13842.6 ODSK -14 KupB wp06 MWD +IFR2 +MS +sag - l I l 1 1 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I l I I I I I l I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section at 292.47? (1500 ft/in) PIONEE R HALLI BURTON WELL DETAILS: ODSK -14 REFERENCE INFORMATION Ground Level: 13.5 Co ordinate (N/E) Reference: Well ODSK - 14 - Slot ODS - 14, True North `.'4gorry Drilling +N / -5 +E1 -W Northing Easting Latittude Longitude Slot Vertical (TVD) Reference: 427' +13.5 @ 56.2ft(Nabors 19AC) 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS-14 Measured Depth Reference: Minimum + m Curvature @ 56.2x[ (Nabors 19AC) Calculation Method: Minimum Curvature Project: Oooguruk Development SURVEY PROGRAM COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Site: Oooguruk Drill Site Date: 2010- 02- 24T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Well: ODSK -14 Error System: ISCWSA Depth From Depth To Survey /Plan Tool Scan Method: Tray. Cylinder North Wellbore: ODSK -14 KupB 42.7 1293.0 ODSK -14 KupB wp06 SR- Gyro-SS Error Surface: Elliptical Conic Plan: ODSK -14 KupB wp06 1293.0 13842.6 ODSK -14 KupB wp06 MWD +IFR2 +MS +sag Warning Method: Rules Based WELLBORE TARGET DETAILS (MAP CO- ORDINATES) SECTION DETAILS Name ND +N / -S +E / -W Northing Easting Shape Sec MD Inc Azi ND +N / -S +E / -W DLeg TFace VSec Target KupB v4 T1A 6059.2 1844.6 - 6772.1 6032943.00 463077.00 Point 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 KupB v3 T4 6061.2 2687.4 - 7591.6 6033789.00 462261.00 Point 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 KupB v3 T3 6066.2 2377.6 - 7291.3 6033478.00 462560.00 Point 3 600.0 3.00 300.00 599.9 3.9 -6.8 1.00 300.00 7.8 KupB v3 T2 6076.2 2068.8 - 6990.0 6033168.00 462860.00 Point 4 750.0 6.00 300.00 749.4 9.8 -17.0 2.00 0.00 19.5 KupB v4 T5 6088.2 3511.2 - 8395.0 6034616.00 461461.00 Point 5 983.3 13.00 300.00 979.4 29.1 -50.3 3.00 0.00 57.6 KupB wp4 DDPoIy 6088.2 1904.3 - 6687.8 6033002.29 463161.55 Polygon 6 1689.2 23.03 288.55 1650.0 112.9 -250.5 1.50 -25.00 274.7 _ KupB wp4 GeoPol)6088.2 1611.9 - 6844.5 6032710.60 463003.70 Polygon 7 1797.9 23.03 288.55 1750.0 126.4 -290.8 0.00 0.00 317.1 6000- KupB vS T6 6144.0 4584.4 - 9441.6 6035693.29 460418.90 Point 8 2946.6 57.05 279.25 2617.3 280.0 - 1001.1 3.00 -13.87 1032.1 9 8295.3 57.05 279.25 5526.5 1001.1 - 5431.1 0.00 0.00 5401.4 - 10 9716.2 83.00 315.75 6022.6 1631.3 - 6564.3 3.00 60.68 6689.5 - 11 10016.2 83.00 315.75 6059.2 1844.6 - 6772.1 0.00 0.00 6963.0 KupB v4 T1A 12 10181.8 87.99 315.84 6072.2 1963.0 - 6887.2 3.00 1.08 7114.6 5400- Total Depth at 13843.60' MD, 6144.00' TVD D D I =6.45 13 10261.5 87.99 315.84 6075.0 2020.1 - 6942.7 0.00 0.00 7187.7 - ODSK -l4 KupB wp06 14 10329.4 90.00 315.71 6076.2 2068.8 - 6990.0 3.00 -3.91 7250.1 KupB v3 T2 15 10377.1 91.43 315.70 6075.6 2102.9 - 7023.3 3.00 -0.25 7293.9 16 10734.7 91.43 315.70 6066.7 2358.7 - 7272.9 0.00 0.00 7622.3 4800- ■ , 17 10761.0 90.66 315.89 6066.2 2377.6 - 7291.3 3.00 165.79 7646.5 KupB t3 T3 41/2 "_ _ • I .' 18 10761.6 90.68 315.90 6066.2 2378.1 - 7291.8 3.00 14.87 7647.1 _ ; 1 19 11169.0 90.68 315.90 6061.3 2670.5 - 7575.2 0.00 0.00 8020.8 _ End Dir 12369.10' MD, 6089.00' TVD 20 11192.5 90.00 315.72 6061.2 2687.4 - 7591.6 3.00 - 165.13 8042.4 KupB v3 T4 4200- ' 21 11238.2 88.63 315.72 6061.7 2720.1 - 7623.5 3.00 - 180.00 8084.4 - I KupB v6 T� 22 12343.6 88.63 315.72 6088.2 3511.2 - 8395.0 0.00 0.00 9099.7 KupB v4 T5 - , ' 23 12369.1 87.86 315.72 6089.0 3529.5 - 8412.9 3.00 179.96 9123.2 - ,' 24 13843.6 87.86 315.72 6144.0 4584.4 - 9441.6 0.00 0.00 10476.9 KupB v6 T6 - �K Z' 3600- ' ♦ _ Start Dir 35/100' 12343.60' MD, 6088.20' TVD S _ i. 0 _ 1 • • CASING DETAILS • V 3000- IKupB v4 Ti • • • ♦ ■ ND MD Name Size ■ 3011.3 3671.0 11 3/4" 11.750 + - ♦ ■ ■ 7 „ 5286.0 7853.0 9 5/8" 9.625 ■ V ♦ ♦ 6075.210394.1 7" 7.000 0 2400- KupB v3 T4 / \ ♦ 6144.013843.6 4 1/2" 4.500. _ ■ • I KupB wp4 DDPoIi A \ Ne 1800- I KupB v3 T' cn - -- , ,,,.,{{ I '/! S - 0 1200- I KupB wp4 GeoPol3 s s 4-, S g h _ I KupB v4 T14 v v �$ o h o 600- 95/8' o oo - „, o 0 N o • V- N 11 3/4" 0- -600 - - i I I I I I I i i i i I I I l I I I I l I I I I l I I I I i l I i l i l I I I I l I i i i l I i l r r r l l i l I l l l l I rT I I I i r l l I l l l l I l l i l I l i I l I l i l I l i i l I l l i i I I I i i I I I i i I i i I I I i i i l I -10800 -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 - 4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 West( - )/East( +) (1500 ft/in) lb Page 1 of 1 Schwartz, Guy L (DOA) From: Vaughan, Alex [AIex.Vaughan @pxd.com] Sent: Thursday, January 28, 2010 2:19 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern -r— Subject: ODSK -14 sidetrack information P I J� ' 01 — / S Guy, As discussed with Vern Johnson we have inadvertently sidetrack the well ODSK -14. After drilling to intermediate 1 section TD of 7,853'MD with a 10 -5/8" bit we pulled out of hole to pick up a 10- 5/8" bit and 10 -5/8" to 11 -3/4" hole opener. We ran in hole with hole opening assembly to 3,585' MD (surface shoe @ 3,556' MD) and functioned reamer. We opened hole from 10 -5/8" to 11 -3/4" to 4,534' MD where we tagged up on a hard streak. Drilling parameters were adjusted and we continued to open hole down to 4,660' MD where it was confirmed we had sidetracked. The 10 -5/8" to 11 -3/4 "hole opener was laid down and we ran in hole with a 10 -5/8" bit and confirmed sidetrack depth at 4,550' MD. We continued to drill ahead as per plan to new intermediate 1 section TD after making a failed attempt to re -enter original hole. Deviation from original borehole and sidetrack was 20.82' at greatest point. Please see attached section view of original ODSK -14 intermediate 1 borehole and sidetrack. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.226.2180 (Cosmo Rig) 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/1/2010 • Page 1 of 2 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson @pxd.com] Sent: Wednesday, February 24, 2010 5:41 PM To: Schwartz, Guy L (DOA) Cc: Campoamor, Kathy; Delmonico, Joe; Hazzard, Vance Subject: RE: ODSK -14 PTD 209 -155 Thanks Guy, we will bring a 10 -401, and directional plan over in the morning. Vern From: Schwartz, Guy L (DOA) [mailto:guy.schwartz©alaska.gov] Sent: Wednesday, February 24, 2010 4:50 PM To: Johnson, Vern Cc: Campoamor, Kathy; Bond, Andy; Hazzard, Vance; Cook, Robert Subject: RE: ODSK -14 PTD 209 -155 Vern, You have verbal approval to continue drilling from the AOGCC. Extending the target location by 1500 feet does not infringe on the unit boundary. A revised PTD will need to be submitted with the new BHL directional plan attached as soon as possible. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson @pxd.com] Sent: Wednesday, February 24, 2010 4:45 PM To: Schwartz, Guy L (DOA) Cc: Campoamor, Kathy; Bond, Andy; Hazzard, Vance; Cook, Robert Subject: ODSK -14 PTD 209 -155 Guy, As discussed earlier today, Pioneer would like to drill up to 1500' horizontal MD past the originally permitted total depth of the well in the Kuparuk reservoir. The original permit bottom hole location was at 1182' FSL, 4269' FEL, sec 3, T13N, R7E, UM, and had a total well length of 12 344' MD. We request approval to drill up to 13844' MD, roughly 1500' MD from the original target. We are currently drilling horizontally in the Kuparuk sand at 12235' MD. Log results have indicated thinner than expected sand, so to compensate for reduced thickness we plan to drill a longer lateral. Let me know if you have any questions or concerns. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2111 office 2/25/2010 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson @pxd.com] Sent: Monday, February 22, 2010 4:16 PM To: Schwartz, Guy L (DOA) Cc: Vaughan, Alex; Campoamor, Kathy; Franks, James Subject: RE: ODSK -14 PB2 Sidetrack PTD# 209 -155 Guy, As discussed, we are attempting to perform an open hole sidetrack in 6 -1/8" hole on our current well (ODSK -14) in the Kuparuk sands. We drilled out of zone into the top shale layer at 10800' MD, then drilled down through the Kuparuk sand and into Lower Cretaceous Unconformity and stopped at 11574' MD. The kickoff point will be approximately 10706' MD. The final completion includes a slotted liner, and we expect the abandoned section of the well to collapse under production conditions. We plan to name the abandoned section of the hole ODSK- 14PB1, with API suffix -71. Let me know if you have any questions. Vern From: Vaughan, Alex Sent: Thursday, January 28, 2010 2:19 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern Subject: ODSK -14 sidetrack information Guy, As discussed with Vern Johnson we have inadvertently sidetrack the well ODSK -14. After drilling to intermediate 1 section TD of 7,853'MD with a 10 -5/8" bit we pulled out of hole to pick up a 10- 5/8" bit and 10 -5/8" to 11 -3/4" hole opener. We ran in hole with hole opening assembly to 3,585' MD (surface shoe @ 3,556' MD) and functioned reamer. We opened hole from 10 -5/8" to 11 -3/4" to 4,534' MD where we tagged up on a hard streak. Drilling parameters were adjusted and we continued to open hole down to 4,660' MD where it was confirmed we had sidetracked. The 10 -5/8" to 11 -3/4 "hole opener was laid down and we ran in hole with a 10 -5/8" bit and confirmed sidetrack depth at 4,550' MD. We continued to drill ahead as per plan to new intermediate 1 section TD after making a failed attempt to re -enter original hole. Deviation from original borehole and sidetrack was 20.82' at greatest point. Please see attached section view of original ODSK -14 intermediate 1 borehole and sidetrack. Alex Vaughan Operations Drilling Engineer 2/22/2010 Page 2 of 2 • M • PIONEER NATURAL RESOURCES 907.226.2180 (Cosmo Rig) 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/22/2010 • Page 1 of 1 Schwartz, Guy L (DOA) -p Z©i From: Schwartz, Guy L (DOA) Sent: Tuesday, February 16, 2010 10:11 AM To: 'Johnson, Vern' Subject: RE: ODSK -14 FIT depth Vern, Approval is granted to reduce new hole to 10' from the required 20' of new hole (25 AAC 20.030 (f)) . Please make sure that you are monitoring cuttings to be sure new formation is being exposed past the cement shoe. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson @pxd.com] Sent: Tuesday, February 16, 2010 10:04 AM To: Schwartz, Guy L (DOA) Cc: OoogurukDrillingSupervisor Subject: ODSK -14 FIT depth Guy, As discussed this morning, we request approval to drill 10' of new hole prior to performing an FIT, instead of 20'. This is to mitigate the potential for drilling fractures and encountering losses prior to the FIT. Let me know if you have any questions. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907- 343 -2111 office 907- 575 -9430 cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/16/2010 FMC Gen 5 Tree 1 B1 -38 Well Bore Diagram As of 2/11/2010 Pre Set 20" ROW - 11,0 Structural Bottom @ 80' MD Conductor ■ 4 - 13'/2" 10 -3/4" 45.5# L -80 BTC hole TMAXX -5e SSSV • 2.813" x- profile 2,203' MD 4 Shoe @ 3,930' MD 7%" 29.7# L -80 BTC • 3-1/2" x 1" GLM's KBMG 7,802' MD 10,114' MD 1 4__— 9' /s" 11,280' MD hole 12,080' MD 12,631' MD ,, Cement - f - 10,835' MD HES 3'% "x 7% PHL Packer ' 12,657' MD I 3W 9.2# L -80 IBTM 12,700' MD -' I P -' Shoe @ - 12,835' MD 5W 17# N -80 Liner `'.•■ • 12,683' to 15,555' MD , 6 -3/4" '~— hole (yam PBTD 15,421' MD • TRANSMITTAL LETTER CHECKLIST WELL NAME Oer.557e,c., < `�-- �— ( PTD# 24-' l v ( e L �= C Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: L Le ire <c L POOL: 1^ u re-c l/ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production / injection should API number are continue to be reported as a function of the original API number between 60 -69) 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. Should conventional core be acquired in this well, representative chip samples from each foot of core must be submitted to the Commission in accordance with 20 AAC 25.071. 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: 2/1/2010 F ield & Pool 000GURUK, KUPARUK OIL - 576100 - —_ Well Name: 000GURUK KUP ODSK-14 Program DEV Well bore seg ❑ PTD#: 2091550 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class /Type DEV / 1 -OIL GeoArea 973 Unit 11550 On /Off Shore On Annular Disposal ❑ Administration 1 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well in ADL 355036 3 Unique well name and number Yes 14 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 000GURUK, KUPARUK OIL - 576100, governed by Conservation Order No. 596 and AIO No. 33 6 Well located proper distance from other wells Yes CO 596 specifies no restrictions as to well spacing except no pay open within 500' 7 Sufficient acreage available in drilling unit Yes of external property line. of external property line. Well will be >2000' from exterior boundary of 8 If deviated, is wellbore plat included Yes Oooguruk Unit. 19 Operator only affected party Yes 110 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 112 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 2/26/2010 IP 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 115 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers, AIO 33 Conclusion 3 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons No OH slotted liner completion. 23 Casing designs adequate for C, T, B & permafrost Yes ( permit reissued due to extending the lateral target by 1500' and 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Passes all major risk criteria. 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in area. 20 AAC 25.035(h) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3073 psi (9.8 ppg EMW) will drill with 8.6 -9.8 ppg mud and MPD technique. GLS 2/26/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 24.10 psi Will test BOP to 4500 psi. ill 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S expected. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified ( For service well onl y) NA 135 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S monitors will be operational. Geology 36 Data presented on potential overpressure zones Yes Expected max. pressure is 9.8 ppg EMW; will be drilled using 9.2 -9.6 ppg mud and managed Appr Date 1 37 Seismic analysis of shallow gas zones NA pressure drilling to keep equivalent circulating density between 10.5 and 12.5 ppg as required. SFD 2/26/2010 38 Seabed condition survey (if off - shore) NA No shallow gas or hydrates expected at this development location. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering r Re issue of permit required as the TD has changed by more than 500' laterally. SFD Date: Date .. loner Date Commissioner: Commissioner �7�/ L DTS 2 2 Or �"Z V-fe • • ffi SEAN PARNELL, GOVERNOR [E /A\ ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -14 Pioneer Natural Resources Alaska, Inc. Permit No: 209 -155 Surface Location: 2955' FSL, 1157' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 1182' FSL, 4269' FEL, Sec. 3, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this I day of December, 2009 cc: Department of Fish 81, Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. IR ECEIVEb STATE OF ALASKA ALOA OIL AND GAS CONSERVATION COW /ION Njj v 2 5 2009 PERMIT TO DRILL 20 AAC 25.005 1ji?:51fh `,j£l' Gas Cons. Commission la. Type of Work: 1b. Proposed Well Class: Development - Oil 0 . Service - Winj ❑ Single Zone , El 1c. Specify A eve osed for: Drill El • Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket el Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 • ODSK -14 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 12,344' . TVD: 6088' . 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool Surface: 2955' FSL, 1157' FEL, Sec. 11, T13N, R7E, UM ADL 355036 . Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4796' FSL, 2648' FEL, Sec. 10, T13N, R7E, UM 417497 1/10/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1182' FSL, 4269' FEL, Sec. 3, T13N, R7E, UM 5760 1010' 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- 469840.87 • y- 6031071.09. Zone- ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: ODSK -33 is 5039' away 16. Deviated wells: Kickoff depth: 300 feet ‘ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.43 degrees Downhole: 3073 , Surfac 2410 • 18. Casing Program: Specifications Top - Setting Depth - Bottom 1 2•V b Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD i TVD MD TVD (including stage data) _ 24" 16" 109# H -40 Welded 115' Surface 456` 16 158' Driven 14 -1/2" 11 -3/4" 60# L -80 Hyd 521 3607' Surface - 3659` 365o" 3000' 522 sx PF 'L'; 260 sx Class 'G' _ 12-1/4" 9 -5/8" 40# L -80 Hyd 521 4500' 3500' 2918' 800 5366' 245 sx Class 'G' 8 -1/2" 7" 26# L -80 Hyd 511 9972' Surface 407015 /o Dl S ' 6059' 86 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 IBT -M 2479' 9865' 6041' 12,344' 6088' , U Slotted 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) > ii•A0° Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat El BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ID 20 AAC 25.050 requir ments❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the oregoing is true and correct. Contact Alex Vaughan, 343 - 2186 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Vern oh on Title Sr. Staff Drilling Engineer / //z. ,-/, Signature . .._..- Phone 343 -2111 Date 11/25/2009 Commission Use Only Permit to Drill API Number: � it Appr val /g /© G/J �•. ' See cover letter for other . Number: .L -'qf c c) 50- - 7t-. ,. 3 ""',� .4 ) 4- Al,..) . ) Al,..) - - c - Date: requirements. Conditions of approval : If bo is checke may not be used to explore for, test, or produce coa ed methane, as hydrates, or gas contained in shales: E Other: '�'-' `S0 D ter" Oa e l 7;-51 r/ Samples req'd: Yes ❑ No [ Mud log req'd: Yes ❑ No 13 • is 0o "Se, 14 "�' ` H measures: Yes ❑ No01 Directional svy req'd: Yes 3' No ❑ iVLr--f-Gr VV ot; J�.of Z AAG ZS• 3 S C U(z) APPROVED BY THE COMMISSION ) Z L._tiji DATE: ... ..J , COMMISSIONER ANAL y L,z•,v.dq /2. 7 ,,,/,244., 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 PIONE NATURAL RESOURCES RECEIVED November 25, 2009 NOV 2 4 1O09 Alaska Oil & Gas Cons. Commission Anchorage State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK -14 Surface Location: 2955' FSL, 1157' FEL, Sec 11, T13N, R7E, UM X = 469840.87, Y = 6031071.09, 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. The well is designed to be a production well in the Oooguruk - Kuparuk 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: • Surface Hole: o Drill 14 -1/2" to —3650' MD / 3000' TVDrkb and set 11 -3/4" flush joint casing. • Intermediate Hole 1: o Drill 10 -5/8" and under -ream while drilling (UWD) to 12 -1/4" to —8000' MD / 5366' TVDrkb. Run and set a 9 -5/8" Flush Joint Drilling Liner. • Intermediate Hole 2: o Drill 8 -1/2" to — 10015' MD / 6059' TVDrkb and set a 7" flush joint Intermediate casing into the top of the Oooguruk - Kuparuk formation. • Production Hole: o Drill 6 -1/8" horizontally to —12344' MD / 6088' TVDrkb and set a 4 -1/2" slotted liner. • Completion: o 3 -1/2" tubing and an ESP. PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 and Production hole sections of ODSK -14. • Alaska Oil & Gas Conservation Commission November 25, 2009 Page 2 of 3 PNRA plans to use this technique while drilling the Intermediate 2 and Production intervals as outlined below. • From TD of Intermediate 1 until Intermediate 2 TD o Use -10.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Kuparuk Sands, -9.8 ppg Pore Pressure • From the Intermediate 2 Shoe to TD o Use -8.7 ppg fluid while using MPD to control pressure from the surface to -9.8 i to10.2 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. 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. In the future, PNRA may provide information and permitting requesting annular disposal of drilling wastes on this well. 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). 1 • Alaska Oil & Gas Conservation Commission November 25, 2009 Page 3of3 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. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report- Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson@pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The anticipated spud date for this well is January 10, 2010. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Since ly, Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -14 Well File • • Permit to Drill Well Plan Summary ODSK -14 Oooguruk - Kuparuk Production Well Surface TD @ 3,650' MD / 3,000' TVD • Drilling Liner TD @ 8,000' MD / 5,366' TVD Intermediate TD @ 10,015' MD / 6,059' TVD , Production TD @ 12,344' MD / 6,088' TVD6 . Surface Location: 2955' FSL, 1157' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469840.87 1 Y = 6031071.09 1 Target: Oooguruk - Kuparuk 4796' FSL, 2648' FEL, Sec 10, T13N, R7E, Umiat X = 463077.00 1 Y = 6032943.00 1 6059' TVDrkb Bottom Hole Location: 1182' FSL, 4269' FEL, Sec 3, T13N, R7E, Umiat X = 461461.00 1 Y = 6034616.00 1 6088' TVDrkb AFE Number: TBA Est. Start Date: January 10, 2010 1 Rig: Nabors 19AC Operating days: 38.2 days to Drill and Complete TD: '12344' MD / 6088 TVDrkb Objective: Kuparuk '1 Well Type (exp, dev, etc): Development ' Well Design: Modified Slimhole (11 -3/4" x 9 -5/8" liner x 7" x 4 -1/2" liner) — Producer — wp04a Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 1 of 10 • Well Control: 14 -1/2" Surface Section: • Maximum anticipated BHP: 1316 psi @ 2943'TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 992 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 10 -5/8" x 12 -1/4" Drilling Liner Hole Section: • Maximum anticipated BHP: 2388 psi @ 5310' TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 1790 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 8 -1/2" Intermediate Casing Hole Section: • Maximum anticipated BHP: 3059 psi @ 6003' TVDss (Based on 9.8 ppg Oooguruk- Kuparuk pore pressure) • Maximum surface pressure: 2399 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 6 -1/8" Production Liner Hole Section: • Maximum anticipated BHP: 3073 psi @ 6032' TVDss • (Based on 9.8 ppg Oooguruk - Kuparuk pore pressure) • Maximum surface pressure: • 2410 psi @ surface • (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ 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 Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 2 of 10 0 • Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 11 -3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg 9 -5/8" Drilling Liner Shoe Rathole + 20' from shoe LOT 12.5 ppg (14.0 ppg max) 7" Intermediate Shoe Rathole + 20' from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 14 -1/2" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 - 25 10 - 15 unrestricted Final 9.2 -9.6 . 70 -100 25 - 35 15 - 25 10 - 15 <12 Drilling Liner Mud Properties: 10 -5/8" x 12 -1/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 10.0 ppg 40 - 60 15 - 25 12 - 20 < 12 8 - 10 Intermediate Hole Mud Properties: 8 -1/2" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 9.8 - 10.5 ppg 50 - 70 15 - 25 15 - 25 < 10 3 - 5 (8 -10 ( -12.5 ppg via HTHP) MPD) Production Hole Mud Properties: 6 -1/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 8.6 ppg ( -10.2 37 - 50 13 - 18 5 - 14 < 5 <8 ppg via MPD) Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. EMW Comments (Psi) (PP9) Base of Permafrost 1707 1666 Top West Sak 2432 2283 8.65 Base of fluvial sands Tuffaceous Shales 3500 2918 Brook 2b 6050 4305 Top Torok Ss 7346 5010 2228 8.65 Base Torok Ss 7796 5255 Top Hrz 8850 5791 Base Hrz 9218 5919 Kalubik Mkr 9571 6001 Kup C 10016 6059 3059 9.8 ' TD 12344 6089 Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 3 of 10 • • Logging Program: 14 -1/2" Section: Drilling: Dir / GR Open Hole: N/A Cased Hole: N/A 10 -5/8" x 12 -1/4" Section: Drilling: Dir / GR . Open Hole: N/A Cased Hole: N/A 8 -1/2" Section: Drilling: Dir / GR / Res Open Hole: N/A Cased Hole: N/A 6 -1/8" Section: Drilling: Mud logging Dir / GR / Azm Res / Dens / Neut / PWD - Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 4 of 10 • Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 115' Surface 158' / 158' 14 -1/2" 11 -3/4" 60# L -80 Hydril 521 3,607' Surface 3,650' / 3,000' 12 -1/4" 9 -5/8" 40# L -80 Hydril 521 4,500' 3,500' 8,000' / 5,366 8 -1/2" 7" 26# L -80 Hydril 511 9,972' Surface 10,015' / 6,059' 6-1/8" 4 -1/2 12.6# L-80 IBT M 9,865' 12,344' / 6,088' slotted 2,479' Tubing 3 -1/2" 9.3# L -80 TSHP/TCII 9,972' Surface 10,015' / 6,059' Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 11 -3/4" 60# L -80 10.772" 10.62" Hydril 521 5830 ' 3180 1384M 1384M 9 -5/8" 40# L -80 8.835' 8.75" Hydril 521 5750 ' 3090 916 M 916 M 7" 26# L -80 6.276" 6.75 Hydril 511 7240 • 5410 604 M 604 M 4-1/2" 12.6# L -80 3.958" 3.833" IBT -M 8430 • 7500 289 M 289 M slotted 3 -1/2" 9.3# L -80 2.992" 2.867" TSHP/TCII 10160 10540 207 M 207 M Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 5 of 10 • • Cement Calculations: Casing Size: 1 11 -3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3150' MD I Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 386 bbls / 522 sx of 10.92 ppg Type "L" Permafrost Cement. , 4.15 cf /sk, 20.0 gps water req. Tail 55 bbls / 260 sx of 15.9 ppg Premium "G" + adds. 1.19 cf /sk, ' 5.23 gps water req. Displ 395 bbls Mud Temp BHST -55° F, BHCT -60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 9 -5/8" Intermediate 1 - Drilling Liner - single stage Basis: TOC: 7500' MD - 500' MD of open hole 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg Dual Spacer Primary 51 bbls / 245 sx Premium "G" + adds. 1.17 cf /sk Displ 397 bbls mud Temp BHST -- 135° F at 5366' TVDrkb, -110° F BHCT Casing Size: 1 7" Intermediate 2 - single stage 1 Basis: TOC: - 9515'MD - 500' MD above the top of intermediate 2 casing shoe 30% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 18 bbls / 286 sx Premium "G" + adds. 1.17 cf /sk Displ 378 bbls mud Temp BHST .- 165° F at 6100' TVDrkb, -135° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 6 of 10 • 1 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rio Activity: Drill and Complete 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 14 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11 -3/4" surface casing. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Riser, NU BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 7. MU 10 -5/8" x 12 -1/4" BHA, MWD /LWD (BHA will be a 10 -5/8" pilot hole opened to 12 -1/4" while drilling). 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 9. Drill through surface shoe, rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 10. Drill 10 -5/8" x 12 -1/4" Intermediate 1 to casing point. 11. Circulate and condition the hole to run the 9 -5/8" drilling liner. POOH. 12. Change one set of pipe rams to 9 -5/8" and test BOPE as required. 13. Run 9 -5/8" drilling liner on 5" DP. Set liner hanger, release from liner and cement. 14. Bump the plug, release pressure and ensure floats are holding, Set liner hanger packer. 15. Close blind rams and test drilling liner to 3500 psi for 30 minutes -- chart and send to ODE. N p 16. POOH w/ 5" DP. SUPERCEDED 4 , / ( N - 17. MU 8 -1/2" directional drilling, MWD /LWD on 5" DP. RU MPD trip nipple. Spe P 18. RIH and cleanout casing to landing collar. 7. /6 19. Drill through drilling liner shoe + 20' of new hole and perform LOT to a minimum of 12.5 ppg, however, should the test reach a 14.0 ppg EMW FIT without breaking over, we do not need to take the test to LOT. 20. RD MPD trip nipple and RU bearing assembly. Drill 8 -1/2" Intermediate 2 to casing point. 21. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 22. Change one set of pipe rams to 7" and test BOPE as required. 23. Run and cement the 7" intermediate casing. 24. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Release pressure and ensure floats are holding. 25. LD 5" DP 26. Change pipe rams to 4" and test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 27. PU 4" DP as needed to TD the Production hole section. 28. MU 6 -1/8" MWD /LWD motor drilling assembly on 4" DP. RU MPD trip nipple. RIH and cleanout to landing collar. RD MPD trip nipple and RU bearing assembly. 29. Drill through Intermediate 2 shoe, rathole + 20' of new hole and perform FIT to 12.5 ppg. Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 7 of 10 • • 30. Displace to drill -in -fluid for production lateral. 31. Drill 6 -1/8" lateral production hole to TD. 32. Circulate and condition the hole to run liner. 33. Change one set of pipe rams to 4 -1/2" and test BOPE as required. 34. RIH w/ 4 -1/2" slotted production liner from 150' inside the intermediate shoe to TD. 35. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 36. MU ESP completion and RIH. 37. Land the tubing and RILDS. Install TWC. 38. ND BOPE, NU tree and test to 5,000 psi. • 39. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 40. 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. 41. RDMO to next well. Post - Rig Work 42. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 43. RD Slickline. Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 8 of 10 • 1 Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test (or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit) with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT /FIT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every IA of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. Note: For FIT, do not take to leak off • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the LOT /FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: November 25, 2009 ODSK -14 Permit To Drill Page 9 of 10 ODSK -14 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre- reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the - formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature . (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45 - close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press 11 -3/4" Surface / 337 bbls 10 ppg 2388 12.5 ppg (LOT) 10 -5/8" x 12 -1/4" 9 -5/8" Drilling Liner / Infinite 10.0 ppg 3059 12.5 ppg (LOT), 8 -1/2" (12.5 EMW w /MPD) 14.0 ppg Max 7" Intermediate / Infinite 8 ' 6 ppg 3059 12.5 ppg (FIT) 6 -1/8" (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 H site, however Standard Operating Procedures for H 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: November 25, 2009 ODSK -14 Permit To Drill Page 10 of 10 • • Pioneer Natural Resources Alaska Cementing Services ODSK-14 cxx guruk EXECUTIVE SUMMARY Assumptions: This design is based on WP 4. Revision #1 Changed 7" Intermediate to a full casing string. 11 -3/4" SURFACE CASING SUMMARY The slurry design volumes are based on bring cement to surface and 500' of tail cement with 75% excess in the permafrost plus 50 bbls and 30% below the permafrost. Fluid Summary 10 bbl Water Spacer 40 bbl Dual Spacer 383.5 bbl (519 sk) Type L Permafrost Cement mixed at 10.7 ppg 55 bbl (260 sk) Premium Cement with 2% Calcium Chloride mixed at 15.9 ppg 395 bbl Mud Displacement ECD Program based on 3,650' of fill and a frac. gradient of 13.9 ppg 3,650' MD / 3,000' TVD. Lead Slurry Fill Tail Slurry Fill ECD 3,150' 500' "V 12.74 ppg 9 -5/8" INTERMEDIATE LINER SUMMARY The well is located outside of the '/2 mile radius of the disposal well so cement does not need to cover the disposal zone. The slurry design volumes are based on bringing the cement 500' above the shoe with 60% excess. Fluid Summary 10 bbl Water Spacer 60 bbl Dual Spacer 51 bbl (245 sk) Premium Cement+ 0.7% Halad -344 + .2% CFR -3, + 0.25 LB /SK. Super CBL+ 0.5% SCR -100 or as required mixed at 15.8 ppg 397 bbl Mud Displacement ECD Program based on 500' of fill and a frac. gradient of 13 ppg 8,000' MD / 5,365' TVD. Tail Slurry Fill ECD 500' N 11 ppg HAL L IDURTOIV 3 • • Pioneer Natural Resources Alaska Cementing Services ODSK -14 000guruk 7" INTERMEDIATE CASING SUMMARY The well is located outside of the ' mile radius of the disposal well so cement does not need to cover the disposal zone. The slurry design volumes are based on bringing the cement 500' above the shoe with 30% excess. Fluid Summary 10 bbl Water Spacer 40 bbl Dual Spacer 17.9 bbl (286 sk) Premium Cement+ 0.7% Halad -344 + .2% CFR -3, + 0.25 LB /SK. Super CBL+ 0.5% SCR -100 or as required mixed at 15.8 ppg 380 bbl Mud Displacement ECD Program based on 500' of fill and a frac. gradient of 13 ppg 10,014' MD / 6,059' TVD. Mud Weight Tail Slurry Fill ECD 11.5 ppg 500' X 13.6 ppg 10.5 ppg 500' N , 12.3 ppg HAL.L.IEURTDN 4 ODSK -14 Pr•uction Well Proposecoompletion Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 01;,'. ,,.. Vent Valves Control Line 16" Conductor 158' MDrkb / 158' TVDrkb 2 -7/8" ScSSSV, 2.313" ID @ -755' MD / 755' TVD 3 -1/2 ", 9.3# L -80 TCII or TSHP ► 11 -3/4 ", 60# L -80 Hyd 511, 10.772" ID J 3650' MDrkb / 3000' TVDrkb 2.7/8' GLM #2 @ 4250' MDrkb / 3330' TVDrkb 2 7/8" X Nipple, 2.313" ID @ 5020' MD 7" x 2 -7/8" Packer @-5050' MDrkb / -3750' TVDrkb 2 7/8" X Nipple, 2.313" ID w RHC -M Profile @ 5070' MD 2 -7/8" GLM #1 @ 8250' MDrkb / 5510' TVDrkb ESP Cable Estimated Top of Cement @ 6856' MD, 500' MD above Top Torok 9 -5/8 ", 40# L -80 Hydril 521, 8.835" ID 8000' MDrkb / 5366' TVDrkb 1 2 7/8" XN Nipple, 2.205" ID Nogo 8880' MD / 5771' TVD 000 ADV @ 9740' MD / 6025' TVD ESP at @ 9760' MDrkb / 6027' ND End of Assembly 9850' MD Estimated Top of Cement @ 9514' MD, 500' MD above 7" shoe 7" Weatherford Liner Top Packer and Tieback 9864' MDrkb / 6040' ND, 7", 26# L -80 Hyd 511, 6.276" ID 4 -1/2" slotted liner 12.6# L -80 IBT -M 10014' MDrkb / 6059' TVDrkb 12344' MDrkb / 6088' TVDrkb NON Date: Revision By: Comments EER 10/14/2009 jdf Proposed Completions ODSK -14 Producer NATURAL RESOJRCES ALAN Well Schematic Draft • I .• . . . . . . .,.. Y '•',, - ,,: Well Planning - Pioneer - Oooguruk Oooguruk Development :-',-: -•? Oooguruk Drill Site ODSK-14 - Slot ODS-14 -• ,-. . ODSK-14 KupB •••,. ,,:,,,: -:,,,. •,: ',. :1•; Plan: ODSK-14 KupB wp04.a : •• ,,,,,, : • ,,,. "•,:, • .- . .•-:.: ,,; --,,, Standard Proposal Report :...: ...'!, ..„ , 03 November, 2009 ... 1: * :•,. :, -:.: / . • :;''- :.1:', - . .,i : ::• . ,, • ..i ',, 5::•:, :... HALLIBURTONI Sperry Drilling Services e, • PIONEER HALLIBURTON WELL DETAILS: ODSK -14 REFERENCE INFORMATION - - Ground Level: 13.5 Co- ordinate (ME) Reference: Well ODSK -14 - Slot ODS -14, True North NATURAL RESOURCES ;!,., r'41 ,- +N / - +E /-W Northing Easting Latittude Longitude Slot Verdcal(TVD) Reference: 42.T +13.5'@ 56.2ft (Nabors l9AC) B 8 B Measured Depth Reference: 42.T+ 13.5' @ 56.2ft (Nabors 19AC) 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS -14 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO-ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Name TVD +N / -S +E / -W Northing Easting Shape Calculation Method: Minimum Curvature Site: Oooguruk Drill Site KupB v4 T1A 6059.2 1844.6 - 6772.1 6032943.00 463077.00 Point Error System: ISCWSA KupB v3 T4 6061.2 2687.4 - 7591.6 6033789.00 462261.00 Point Scan Method: Tmv. Cylinder North Well: ODSK -14 KupB v3 T3 6066.2 2377.6 - 7291.3 6033478.00 462560.00 Point Error Surface: Elliptical Conic Wellbore: ODSK 14 KupB KupB v3 T2 6076.2 2068.8 - 6990.0 6033168.00 462860.00 Point Warning Method: Rules Based KupB v4 T5 6088.2 3511.2 - 8395.0 6034616.00 461461.00 Point Plan: ODSK -14 KupB wp04.a SECTION DETAILS - Sec MD Inc At TVD +N / -S +E/ -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 - 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 3 600.0 3.00 300.00 599.9 3.9 -6.8 1.00 300.00 7.8 PA 4 750.0 6.00 300.00 749.4 9.8 -17.0 2.00 0.00 19.5 - � 5 983.3 13.00 300.00 979.4 29.1 -50.3 3.00 0.00 57.6 6 1689.2 23.03 288.55 1650.0 112.9 -250.5 1.50 -25.00 274.7 0- Start Dir 2.00/100' 600.00' MD, 599.90' TVD 7 1797.9 23.03 288.55 1750.0 126.4 -290.8 0.00 0.00 317.1 • ' - - ' 8 2946.6 57.05 279.25 2617.3 280.0 - 1001.1 3.00 -13.87 1031.6 -' Start Dir 3.00/100' 750.00' MD, 749.40' TVD 9 8295.3 57.05 279.25 5526.5 1001.1 - 5431.1 0.00 0.00 5396.7 -_ - ' _ _ - 10 9716.2 83.00 315.75 6022.6 1631.3 - 6564.3 3.00 60.68 6685.4 600 - _ - - - - 11 10016.2 83.00 315.75 6059.2 1844.6 - 6772.1 0.00 0.00 6959.4 KupB v4 T1A _ - - - - Start Dir 1.50/100' 983.30' MD, 979.40' TVD 12 10181.8 87.99 315.84 6072.2 1963.0 - 6887.2 3.00 1.08 7111.2 - _ _ - _ - 13 10261.5 87.99 315.84 6075.0 2020.1 - 6942.7 0.00 0.00 7184.5 - - - - - - 14 10329.4 90.00 315.71 6076.2 2068.8 - 6990.0 3.00 -3.91 7247.0 KupB v3 T2 - 15 10377.1 91.43 315.70 6075.6 2102.9 - 7023.3 3.00 -0.25 7290.8 1200 - End Dir 1689.20' MD, 1650.00' TVD 16 10734.7 91.43 315.70 6066.7 2358.7 - 7272.9 0.00 0.00 7619.8 Base of Permafrost 2� - - - 17 10761.0 90.66 315.89 6066.2 2377.6 - 7291.3 3.00 165.79 7644.1 KupB v3 T3 - _ - " 18 10761.6 90.68 315.90 6066.2 2378.1 - 7291.8 3.00 14.87 7644.7 19 11169.0 90.68 315.90 6061.3 2670.5 - 7575.2 0.00 0.00 8019.0 1800 - - _ - - -- - _. Start Dir 3.0/100' 1797.90' MD, 1750.00' TVD 20 11192.5 90.00 315.72 6061.2 2687.4 - 7591.6 3.00 - 165.13 8040.6 KupB v3 T4 21 11238.2 88.63 315.72 6061.7 2720.1 - 7623.5 3.00 180.00 8082.7 c - 1k6 22 12343.6 88.63 315.72 6088.2 3511.2 - 8395.0 0.00 0.00 9099.7 KupB v4 T5 DDI = 6.34 h End Dir 2946.60' MD, 2617.30' TVD °0 2400 h - - - - Top West Sak s - 11 3/4" End Dir 10377.10' MD, 6075.60' TVD • 3000- - , Start Dir 3.0/100' 8295.30' MD, 5526.50' TVD aI T Tuffaceous Shales ` Start Dir 3.0/100' 10734.70' MD, 6066.70' TVD TO - ` End Dir 9716.20' MD, 6022.60' TVD 3600 - aI > - 4 o �, Start Dir 3.0/100' 10016.20' MD, 6059.20' TVD End Dir 10761.60' MD, 6066.20' TVD 4200 FORMATION TOP DETAILS , ■ ' v / � ! - TVDPath TVDssPath MDPath Formation , En Dir 10181.80' MD, 6072.20' TVD ' . Start Dir 3.0/100' 11169.00' MD, 6061.30' TVD 1666.2 1610.0 1706.8 Base of Permafrost ! 4800 2283.2 2227.0 2431 Top West Sak Brook 2b End Dir 11238.20' MD, 6061.70' TVD 2918.2 2862.0 3499.8 Tuffaceous Shales - - 4305.2 4249.0 6049.8 Brook 2b , Start Dir 3.0/100 10261.50' MD 6075.00 r TVD' .- 5010.2 4954.0 7346.0 Top Torok ss T Torok Ss ' � ` ` ` 1 i , , - 5255.2 5199.0 7796.4 Base Torok Ss 5400 5791.2 5735.0 8850.1 Top Hrz co 1 Total Depth at 12343.50' MD, 6088.20' TVD 5919.2 5863.0 9217.7 Base Hrz Base Torok Ss 9 5/8 t ° t ' 1 � , / .- - - - 6001.2 5945.0 9570.6 Kalubi ) o , ! ! , �� 41/2" - - 6059.2 6003.0 10016.2 Kup C .C' i ! t /� 6000- Top HR - /7\ 1 - Ha SURVEY PROGRAM CASING DETAILS Base H j 7 " �1 ■ - ' _ 6600 Date: 2009- 11- 03T00:00:00 Validated: Yes Version: TVD MD Name Size Kup C ; \ . ODSK - KupB wp04.a - 3000.0 3650.2 11 3/4" 11.750 Kalubik Mkr , I KupB v3 T2 , ( KupB v3 T4 , - Depth From Depth To Survey /Plan Tool 5365.9 8000.0 9 5/8" 9.625 ' ` k 42.7 1000.0 ODSK -14 KupB wp04.a SR- Gyro-SS 6059.0 10014.6 7" 7.000 -- KupB V4 TS 7200 1000.0 12343.5 ODSK -14 KupB wp04.a MWD +IFR2 +MS +sag 6088.2 12343.6 4 1/2" 4.500 KupB v4 T1A KupB v3 T31 p 1 ! 1 1 1 1 1 I i 1r 1 1 1 1 1 1 i 1 , 1 I! I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 11M1f111111[1111111 1 1 1 1 1 1 1 1 j 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section at 292.70° (1500 ft/in) P 1 0 N E E R HALLIBURTA R N WELL ODSK -14 REFERENCE INFOMATION 11 N Ground Level: 13.5 Co- ordinate (N/E) Reference: Well ODSK -14 - Slot ODS -14, True North Sperry Drilling +N / -S +E/ -W Northing Easting Latittude Longitude Slot Vertical (TVD) Reference: 42.T +13.5' 56.25 (Nabors 19AC) 5 P V 9 g 8 8 Measured Depth Reference: 42.7 + 13.5' @ 562/1 (Nabors 19AC) 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS -14 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO - ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name TVD +N / - +E / - Northing Easting Shape Calculation Method: Minimum Curvature Project: Oooguruk k Develo ment KupB v4 T1A 6059.2 1844.6 - 6772.1 6032943.00 463077.00 Point Error System: ISCWSA g KupB v3 T4 6061.2 2687.4 - 7591.6 6033789.00 462261.00 Point Scan Method: Tray. Cylinder North Site: Oooguruk Drill Site KupB v3 T3 6066.2 2377.6 - 7291.3 6033478.00 462560.00 Point Error Surface: Elliptical Conic W ell: ODSK -14 KupB v3 T2 6076.2 2068.8 - 6990.0 6033168.00 462860.00 Point Warring Method: Rules Based Wel /bore: ODSK -14 KupB KupB v4 T5 6088.2 3511.2 - 8395.0 6034616.00 461461.00 Point Plan: ODSK -14 KupB wp04.a SURVEY PROGRAM CASING DETAILS Date: 2009 -11- 03700:00:00 Validated: Yes Version: TVD MD Name Size .605 Depth From Depth To Survey /Plan Tool 5 365.9 059.9 8000.0 3650.2 11 5/8" 11.750 42.7 1000.0 ODSK -14 KupB wp04.a SR- Gyro -SS 6059.0 100 00 9 5/ 7" 9 7.01 614.6 7" 7.000 1000.0 12343.5 ODSK -14 KupB wp04.a MWD +IFR2 +MS +sag 6088.2 12343.6 4 1/2" 4.500 - SECTION DETAILS 6000- - Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target - DDI =6.34 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 - 3 600.0 3.00 300.00 599.9 3.9 -6.8 1.00 300.00 7.8 5400- 4 750.0 6.00 300.00 749.4 9.8 -17.0 2.00 0.00 19.5 5 983.3 13.00 300.00 979.4 29.1 -50.3 3.00 0.00 57.6 6 1689.2 23.03 288.55 1650.0 112.9 -250.5 1.50 -25.00 274.7 7 1797.9 23.03 288.55 1750.0 126.4 -290.8 0.00 0.00 317.1 4800- 8 2946.6 57.05 279.25 2617.3 280.0 - 1001.1 3.00 -13.87 1031.6 9 8295.3 57.05 279.25 5526.5 1001.1 - 5431.1 0.00 0.00 5396.7 Total Depth at 12343.50' MD, 6088.20' TVD 10 9716.2 83.00 315.75 6022.6 1631.3 - 6564.3 3.00 60.68 6685.4 - _ 1 11 10016.2 83.00 315.75 6059.2 1844.6 - 6772.1 0.00 0.00 6959.4 KupB v4 T1A 4200- Et'd Dir 11238.20' MD, 6061.70' TVD 12 10181.8 87.99 315.84 6072.2 1963.0 - 6887.2 3.00 1.08 7111.2 1 13 10261.5 87.99 315.84 6075.0 2020.1 - 6942.7 0.00 0.00 7184.5 ODSK - 14 KupB wp04.a 1 1 .0 /10(1 M D, ' 11169.00' 6061.30' TVD 14 10329.4 90.00 315.71 6076.2 2068.8 - 6990.0 3.00 -3.91 7247.0 KupB v3 T2 1 Start Dir 15 10377.1 91.43 315.70 6075.6 2102.9 - 7023.3 3.00 -0.25 7290.8 1 41/2 ' 16 10734.7 91.43 315.70 6066.7 2358.7 - 7272.9 0.00 0.00 7619.8 3600- - _ _ En Dij 10761.60' MD 6066.20' TVD 17 10761.0 90.66 315.89 6066.2 2377.6 - 7291.3 3.00 165.79 7644.1 KupB v3 T3 _ I ' ' 18 10761.6 90.68 315.90 6066.2 2378.1 - 7291.8 3.00 14.87 7644.7 / ` 1 ' Start 3.0/ 100' 10734.70' MD, 6066.70' TVD r 19 11169.0 90.68 315.90 6061.3 2670.5 - 7575.2 0.00 0.00 8019.0 c - L upB v4 T5 1 , 20 11192.5 90.00 315.72 6061.2 2687.4 - 7591.6 3.00 - 165.13 8040.6 KupB v3 T4 ' 3000- 1 / / End Dg 19 MD, 6075.60' TVD 21 11238.2 88.63 315.72 6061.7 2720.1 - 7623.5 3.00 180.00 8082.7 - '1i 22 12343.6 88.63 315.72 6088.2 3511.2 - 8395.0 0.00 0.00 9099.7 KupB v4 T5 + _ KupB v3 T�I - - - - / ,- Start 1 if 3.0/100' 10261.50' MD, 6075.00' TVD - 1 _ I/ 2400- - End Dir 10181.80' MD, 6072.20' TVD *upB v3 - ' _ C - _ -- - - - _ - 1 I End Dir 2946.60' MD, 2617.30' TVD - - Start Dir 3.0/100' 10016.20' MD, 6059.20' TVD • KupB v31�E' t_ r _ - -- End Dir 9716.20' MD, 6022.60' TVD Start Dir 3.0/100'1797.90'MD, 1750.00' TVD O 1800 7 : O - - - - - , E nd Dir 1689.20' MD, 1650.00' TVD cn _ - b� Start Dir 3.0/100' 8295.30' MD, 5526.50' TVD 1 1 t I Ku B p v4 Tt 1 Stan Dir 1.50' /100' 983.30' MD, 979.40' TVD 1200 g c 1 1 t ' y , �„ o 1 1 1 Start Oir 3.0¢/100' 750.00' MD, 749.40' TVD v 0 1 9 5/8" r� •s. $ ° o 1 1 t / 600- 0 1 g 1 i / Or 2.00 /100' 600.00' MD, 599.90' TVD � t . I N O 1 / / v-- ,, t % ,,,y .86. Dir 1.00 /100' 300.00' MD, 300.00' TVD - 0 -600 - I I I I I I i f 11 f I 1 I 1 1 1 1 1 f 1 I I 1 1 1 i 1 T 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 T 1 1 I I 1 1 1 1 1 1 1 1[ 1 I 1 I 1 I 1 1 1 1 1 1 1 1 1 1' I I] 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I l i -10800 -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 - 4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 West( - )/East( +) (1500 ft/in) • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK - 14 KupB Design: ODSK -14 KupB wp04.a 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 ODSK -14 - Slot ODS -14 Well Position +N /-S 0.0 ft Northing: 6,031,071.09ft Latitude: 70° 29' 45.449 N +E / -W 0.0 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSK -14 KupB Magnetics Model Name Sample Date Declination' ,', Dip Angt(e Field Strength ' ( ?) `< :.. ( ?) (nT) IGRF200510 4/14/2009 22.31 80.81 57,730 Design ODSK -14 KupB wp04.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: e Depth From (Try ,,; +N /-S „u. +E/ -W Direction (ft) : ..' .T.) (ft) ( ?) 42.7 0.0 0.0 292.70 11/3/2009 12 :48 :52PM Page 2 COMPASS 2003.16 Build 42 0 • Halliburton Company HALL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -14 KupB Design: ODSK -14 KupB wp04.a Plan Sections Measured Vertical TVD Dogleg BuIK Turn Depth Inclination Azimuth Depth System +N/-S +E!-W Rate Rath :_ ` , Rate Tool Face (ft) ( ?) ( ?) (ft) ft (ft) (ft) ( ?i1OOft) (?J1 ;,, (?l1OOft) ( ?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 0.00 0.00 0.00 0.00 600.0 3.00 300.00 599.9 543.7 3.9 -6.8 1.00 1.00 0.00 300.00 750.0 6.00 300.00 749.4 693.2 9.8 -17.0 2.00 2.00 0.00 0.00 983.3 13.00 300.00 979.4 923.2 29.1 -50.3 3.00 3.00 0.00 0.00 1,689.2 23.03 288.55 1,650.0 1,593.8 112.9 -250.5 1.50 1.42 -1.62 -25.00 1,797.9 23.03 288.55 1,750.0 1,693.8 126.4 -290.8 0.00 0.00 0.00 0.00 2,946.6 57.05 279.25 2,617.3 2,561.1 280.0 - 1,001.1 3.00 2.96 -0.81 -13.87 8,295.3 57.05 279.25 5,526.5 5,470.3 1,001.1 - 5,431.1 0.00 0.00 0.00 0.00 9,716.2 83.00 315.75 6,022.6 5,966.4 1,631.3 - 6,564.3 3.00 1.83 2.57 60.68 10,016.2 83.00 315.75 6,059.2 6,003.0 1,844.6 - 6,772.1 0.00 0.00 0.00 0.00 10,181.8 87.99 315.84 6,072.2 6,016.0 1,963.0 - 6,887.2 3.00 3.01 0.06 1.08 10,261.5 87.99 315.84 6,075.0 6,018.8 2,020.1 - 6,942.7 0.00 0.00 0.00 0.00 10,329.4 90.00 315.71 6,076.2 6,020.0 2,068.8 - 6,990.0 3.00 2.96 -0.20 -3.91 10,377.1 91.43 315.70 6,075.6 6,019.4 2,102.9 - 7,023.3 3.00 3.00 -0.01 -0.25 10,734.7 91.43 315.70 6,066.7 6,010.5 2,358.7 - 7,272.9 0.00 0.00 0.00 0.00 10,761.0 90.66 315.89 6,066.2 6,010.0 2,377.6 - 7,291.3 3.00 -2.91 0.74 165.79 10,761.6 90.68 315.90 6,066.2 6,010.0 2,378.1 - 7,291.8 3.00 2.90 0.77 14.87 11,169.0 90.68 315.90 6,061.3 6,005.1 2,670.5 - 7,575.2 0.00 0.00 0.00 0.00 11,192.5 90.00 315.72 6,061.2 6,005.0 2,687.4 - 7,591.6 3.00 -2.90 -0.77 - 165.13 11,238.2 88.63 315.72 6,061.7 6,005.5 2,720.1 - 7,623.5 3.00 -3.00 0.00 180.00 12,343.6 88.63 315.72 6,088.2 6,032.0 3,511.2 - 8,395.0 0.00 0.00 0.00 0.00 11/3/2009 12:48:52PM Page 3 COMPASS 2003.16 Build 42 • • Halliburton Company HALL: BU R V J Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) . Project: Oooguruk Development MD Reference: 42.7' + 13.5' © 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Ong DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) `' -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,071.09. 469,840.87 • 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 . 300.0 0.00 0.00 300.0 243.8 0.0 0.0 6,031,071.09 469,840.87 0.00 0.00 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 400.0 1.00 300.00 400.0 343.8 0.4 -0.8 6,031,071.53 469,840.12 1.00 0.87 500.0 2.00 300.00 500.0 443.8 1.7 -3.0 6,031,072.85 469,837.85 1.00 3.46 600.0 3.00 300.00 599.9 543.7 3.9 -6.8 6,031,075.04 469,834.09 1.00 7.79 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 700.0 5.00 300.00 699.6 643.4 7.4 -12.8 6,031,078.56 469,828.06 2.00 14.71 750.0 6.00 300.00 749.4 693.2 9.8 -17.0 6,031,080.97 469,823.92 2.00 19.46 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 800.0 7.50 300.00 799.0 742.8 12.7 -22.1 6,031,083.93 469,818.84 3.00 25.29 900.0 10.50 300.00 897.8 841.6 20.6 -35.6 6,031,091.80 469,805.33 3.00 40.80 983.3 13.00 300.00 979.4 923.2 29.1 -50.3 6,031,100.35 469,790.67 3.00 57.64 Start Dir 1.50/100' 983.30' MD, 979.40' TVD 1,000.0 13.23 299.54 995.6 939.4 30.9 -53.6 6,031,102.24 469,787.40 1.50 61.39 1,100.0 14.60 297.07 1,092.7 1,036.5 42.3 -74.8 6,031,113.70 469,766.26 1.50 85.32 1,200.0 16.00 295.01 1,189.1 1,132.9 53.9 -98.5 6,031,125.36 469,742.59 1.50 111.66 1,300.0 17.42 293.29 1,284.9 1,228.7 65.6 -124.7 6,031,137.21 469,716.40 1.50 140.41 1,400.0 18.85 291.81 1,379.9 1,323.7 77.5 -153.5 6,031,149.25 469,687.71 1.50 171.53 1,500.0 20.29 290.54 1,474.2 1,418.0 89.6 -184.7 6,031,161.45 469,656.53 1.50 205.00 1,600.0 21.73 289.43 1,567.5 1,511.3 101.9 -218.4 6,031,173.83 469,622.89 1.50 240.81 1,689.2 23.03 288.55 1,650.0 1,593.8 112.9 -250.5 6,031,185.00 469,590.82 1.50 274.70 End Dir 1689.20' MD, 1650.00' TVD 1,700.0 23.03 288.55 1,659.9 1,603.7 114.3 -254.5 6,031,186.36 469,586.82 0.00 278.91 1,706.8 23.03 288.55 1,666.2 1,610.0 115.1 -257.1 6,031,187.22 469,584.30 0.00 281.57 Base of Permafrost 1,797.9 23.03 288.55 1,750.0 1,693.8 126.4 - 290.8 6,031,198.69 469,550.57 0.00 317.11 Start Dir 3.0/100' 1797.90' MD, 1750.00' TVD 1,800.0 23.09 288.51 1,752.0 1,695.8 126.7 -291.6 6,031,198.96 469,549.79 3.03 317.93 1,900.0 26.01 286.88 1,842.9 1,786.7 139.3 -331.2 6,031,211.71 469,510.26 3.00 359.31 2,000.0 28.95 285.55 1,931.6 1,875.4 152.1 -375.5 6,031,224.74 469,466.01 3.00 405.14 2,100.0 31.90 284.45 2,017.8 1,961.6 165.2 -424.4 6,031,238.02 469,417.16 3.00 455.32 2,200.0 34.85 283.52 2,101.3 2,045.1 178.5 -477.8 6,031,251.51 469,363.84 3.00 509.68 2,300.0 37.81 282.72 2,181.9 2,125.7 191.9 -535.5 6,031,265.18 469,306.20 3.00 568.09 2,400.0 40.78 282.01 2,259.3 2,203.1 205.5 -597.4 6,031,278.98 469,244.40 3.00 630.39 2,431.8 41.73 281.81 2,283.2 2,227.0 209.8 -617.9 6,031,283.39 469,223.88 3.00 651.02 Top West Sak 2,500.0 43.75 281.39 2,333.3 2,277.1 219.1 -663.2 6,031,292.87 469,178.61 3.00 696.41 2,600.0 46.73 280.83 2,403.7 2,347.5 232.8 -732.9 6,031,306.83 469,109.01 3.00 765.96 2,700.0 49.70 280.33 2,470.3 2,414.1 246.5 -806.2 6,031,320.81 469,035.78 3.00 838.85 • 2,800.0 52.68 279.86 2,533.0 2,476.8 260.1 -882.9 6,031,334.77 468,959.13 3.00 914.88 2,900.0 55.66 279.43 2,591.5 2,535.3 273.7 -962.8 6,031,348.67 468,879.28 3.00 993.86 11/3/2009 12 :48 :52PM Page 4 COMPASS 2003.16 Build 42 III Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 14 Survey Calculation Method: Minimum Curvature Welibore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N / -S +E/ -W Northing East • DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 2,561.11 2,946.6 57.05 279.25 2,617.3 2,561.1 280.0 - 1,001.1 6,031,355.12 468,841.03 3.00 1,031.60 End Dir 2946.60' MD, 2617.30' TVD 3,000.0 57.05 279.25 2,646.4 2,590.2 287.2 - 1,045.3 6,031,362.50 468,796.83 0.00 1,075.18 3,100.0 57.05 279.25 2,700.7 2,644.5 300.7 - 1,128.1 6,031,376.32 468,714.07 0.00 1,156.79 3,200.0 57.05 279.25 2,755.1 2,698.9 314.2 - 1,211.0 6,031,390.13 468,631.31 0.00 1,238.41 3,300.0 57.05 279.25 2,809.5 2,753.3 327.6 - 1,293.8 6,031,403.95 468,548.55 0.00 1,320.02 3,400.0 57.05 279.25 2,863.9 2,807.7 341.1 - 1,376.6 6,031,417.76 468,465.79 0.00 1,401.63 3,499.8 57.05 279.25 2,918.2 2,862.0 354.6 - 1,459.3 6,031,431.55 468,383.20 0.00 1,483.08 Tuffaceous Shales 3,500.0 57.05 279.25 2,918.3 2,862.1 354.6 - 1,459.4 6,031,431.58 468,383.03 0.00 1,483.24 3,600.0 57.05 279.25 2,972.7 2,916.5 368.1 - 1,542.3 6,031,445.40 468,300.27 0.00 1,564.85 3,650.2 57.05 279.25 3,000.0 2,943.8 374.9 - 1,583.8 6,031,452.33 468,258.73 0.00 1,605.82 11 3/4" 3,700.0 57.05 279.25 3,027.1 2,970.9 381.6 - 1,625.1 6,031,459.21 468,217.51 0.00 1,646.46 3,800.0 57.05 279.25 3,081.5 3,025.3 395.1 - 1,707.9 6,031,473.03 468,134.75 0.00 1,728.08 3,900.0 57.05 279.25 3,135.9 3,079.7 408.5 - 1,790.7 6,031,486.85 468,051.99 0.00 1,809.69 4,000.0 57.05 279.25 3,190.3 3,134.1 422.0 - 1,873.6 6,031,500.66 467,969.23 0.00 1,891.30 4,100.0 57.05 279.25 3,244.7 3,188.5 435.5 - 1,956.4 6,031,514.48 467,886.47 0.00 1,972.91 4,200.0 57.05 279.25 3,299.0 3,242.8 449.0 - 2,039.2 6,031,528.30 467,803.71 0.00 2,054.52 4,300.0 57.05 279.25 3,353.4 3,297.2 462.5 - 2,122.0 6,031,542.11 467,720.95 0.00 2,136.14 4,400.0 57.05 279.25 3,407.8 3,351.6 475.9 - 2,204.9 6,031,555.93 467,638.19 0.00 2,217.75 4,500.0 57.05 279.25 3,462.2 3,406.0 489.4 - 2,287.7 6,031,569.75 467,555.43 0.00 2,299.36 4,600.0 57.05 279.25 3,516.6 3,460.4 502.9 - 2,370.5 6,031,583.56 467,472.67 0.00 2,380.97 4,700.0 57.05 279.25 3,571.0 3,514.8 516.4 - 2,453.3 6,031,597.38 467,389.91 0.00 2,462.58 4,800.0 57.05 279.25 3,625.4 3,569.2 529.9 - 2,536.1 6,031,611.20 467,307.15 0.00 2,544.20 4,900.0 57.05 279.25 3,679.8 3,623.6 543.4 - 2,619.0 6,031,625.01 467,224.39 0.00 2,625.81 5,000.0 57.05 279.25 3,734.2 3,678.0 556.8 - 2,701.8 6,031,638.83 467,141.63 0.00 2,707.42 5,100.0 57.05 279.25 3,788.6 3,732.4 570.3 - 2,784.6 6,031,652.65 467,058.87 0.00 2,789.03 5,200.0 57.05 279.25 3,843.0 3,786.8 583.8 - 2,867.4 6,031,666.46 466,976.11 0.00 2,870.64 5,300.0 57.05 279.25 3,897.4 3,841.2 597.3 - 2,950.3 6,031,680.28 466,893.35 0.00 2,952.26 5,400.0 57.05 279.25 3,951.7 3,895.5 610.8 - 3,033.1 6,031,694.10 466,810.59 0.00 3,033.87 5,500.0 57.05 279.25 4,006.1 3,949.9 624.2 - 3,115.9 6,031,707.91 466,727.83 0.00 3,115.48 5,600.0 57.05 279.25 4,060.5 4,004.3 637.7 - 3,198.7 6,031,721.73 466,645.07 0.00 3,197.09 5,700.0 57.05 279.25 4,114.9 4,058.7 651.2 - 3,281.6 6,031,735.54 466,562.31 0.00 3,278.70 5,800.0 57.05 279.25 4,169.3 4,113.1 664.7 - 3,364.4 6,031,749.36 466,479.55 0.00 3,360.32 5,900.0 57.05 279.25 4,223.7 4,167.5 678.2 - 3,447.2 6,031,763.18 466,396.79 0.00 3,441.93 6,000.0 57.05 279.25 4,278.1 4,221.9 691.7 - 3,530.0 6,031,776.99 466,314.03 0.00 3,523.54 6,049.8 57.05 279.25 4,305.2 4,249.0 698.4 - 3,571.3 6,031,783.88 466,272.79 0.00 3,564.21 Brook 2b 6,100.0 57.05 279.25 4,332.5 4,276.3 705.1 - 3,612.9 6,031,790.81 466,231.27 0.00 3,605.15 6,200.0 57.05 279.25 4,386.9 4,330.7 718.6 - 3,695.7 6,031,804.63 466,148.51 0.00 3,686.76 6,300.0 57.05 279.25 4,441.3 4,385.1 732.1 - 3,778.5 6,031,818.44 466,065.75 0.00 3,768.38 6,400.0 57.05 279.25 4,495.7 4,439.5 745.6 - 3,861.3 6,031,832.26 465,982.99 0.00 3,849.99 6,500.0 57.05 279.25 4,550.1 4,493.9 759.1 - 3,944.2 6,031,846.08 465,900.23 0.00 3,931.60 6,600.0 57.05 279.25 4,604.4 4,548.2 772.6 - 4,027.0 6,031,859.89 465,817.47 0.00 4,013.21 11/3/2009 12 :48:52PM Page 5 COMPASS 2003.16 Build 42 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 14 - Slot ODS - 14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Planned Survey Measured Vertical Map Map „ Depth Inclination Azimuth Depth TVDss +N /-S +E/-W Northing DLS . Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) '` 4,602.64 6,700.0 57.05 279.25 4,658.8 4,602.6 786.0 - 4,109.8 6,031,873.71 465,734.71 0.00 4,094.82 6,800.0 57.05 279.25 4,713.2 4,657.0 799.5 - 4,192.6 6,031,887.53 465,651.95 0.00 4,176.43 6,900.0 57.05 279.25 4,767.6 4,711.4 813.0 - 4,275.4 6,031,901.34 465,569.19 0.00 4,258.05 7,000.0 57.05 279.25 4,822.0 4,765.8 826.5 - 4,358.3 6,031,915.16 465,486.43 0.00 4,339.66 7,100.0 57.05 279.25 4,876.4 4,820.2 840.0 - 4,441.1 6,031,928.98 465,403.67 0.00 4,421.27 7,200.0 57.05 279.25 4,930.8 4,874.6 853.4 - 4,523.9 6,031,942.79 465,320.91 0.00 4,502.88 7,300.0 57.05 279.25 4,985.2 4,929.0 866.9 - 4,606.7 6,031,956.61 465,238.15 0.00 4,584.49 7,346.0 57.05 279.25 5,010.2 4,954.0 873.1 - 4,644.8 6,031,962.96 465,200.09 0.00 4,622.03 Top Torok Ss 7,400.0 57.05 279.25 5,039.6 4,983.4 880.4 - 4,689.6 6,031,970.43 465,155.39 0.00 4,666.11 7,500.0 57.05 279.25 5,094.0 5,037.8 893.9 - 4,772.4 6,031,984.24 465,072.63 0.00 4,747.72 7,600.0 57.05 279.25 5,148.4 5,092.2 907.4 - 4,855.2 6,031,998.06 464,989.87 0.00 4,829.33 7,700.0 57.05 279.25 5,202.8 5,146.6 920.9 - 4,938.0 6,032,011.88 464,907.11 0.00 4,910.94 7,796.4 57.05 279.25 5,255.2 5,199.0 933.9 - 5,017.9 6,032,025.20 464,827.30 0.00 4,989.64 Base Torok Ss 7,800.0 57.05 279.25 5,257.1 5,200.9 934.3 - 5,020.9 6,032,025.69 464,824.35 0.00 4,992.55 7,900.0 57.05 279.25 5,311.5 5,255.3 947.8 - 5,103.7 6,032,039.51 464,741.59 0.00 5,074.17 8,000.0 57.05 279.25 5,365.9 5,309.7 961.3 - 5,186.5 6,032,053.33 464,658.83 0.00 5,155.78 9 5/8" 8,100.0 57.05 279.25 5,420.3 5,364.1 974.8 - 5,269.3 6,032,067.14 464,576.07 0.00 5,237.39 8,200.0 57.05 279.25 5,474.7 5,418.5 988.3 - 5,352.2 6,032,080.96 464,493.31 0.00 5,319.00 8,295.3 57.05 279.25 5,526.5 5,470.3 1,001.1 - 5,431.1 6,032,094.13 464,414.44 0.00 5,396.78 Start Dir 3.0/100' 8295.30' MD, 5526.50' TVD 8,300.0 57.12 279.39 5,529.1 5,472.9 1,001.8 - 5,435.0 6,032,094.78 464,410.54 3.03 5,400.62 8,400.0 58.63 282.45 5,582.3 5,526.1 1,017.8 - 5,518.1 6,032,111.18 464,327.49 3.00 5,483.51 8,500.0 60.21 285.42 5,633.2 5,577.0 1,038.6 - 5,601.7 6,032,132.26 464,244.04 3.00 5,568.58 8,600.0 61.85 288.28 5,681.6 5,625.4 1,063.9 - 5,685.4 6,032,157.97 464,160.44 3.00 5,655.60 8,700.0 63.56 291.06 5,727.5 5,671.3 1,093.9 - 5,769.0 6,032,188.24 464,076.91 3.00 5,744.33 8,800.0 65.31 293.76 5,770.6 5,714.4 1,128.3 - 5,852.4 6,032,222.97 463,993.69 3.00 5,834.52 8,850.1 66.21 295.08 5,791.2 5,735.0 1,147.2 - 5,894.0 6,032,242.04 463,952.16 3.00 5,880.20 Top Hrz 8,900.0 67.11 296.38 5,811.0 5,754.8 1,167.0 - 5,935.3 6,032,262.09 463,910.99 3.00 5,925.93 9,000.0 68.96 298.94 5,848.4 5,792.2 1,210.1 - 6,017.4 6,032,305.48 463,829.05 3.00 6,018.31 9,100.0 70.84 301.42 5,882.7 5,826.5 1,257.3 - 6,098.5 6,032,353.01 463,748.09 3.00 6,111.41 9,200.0 72.75 303.86 5,914.0 5,857.8 1,308.6 - 6,178.5 6,032,404.57 463,668.33 3.00 6,204.96 9,217.7 73.09 304.28 5,919.2 5,863.0 1,318.1 - 6,192.6 6,032,414.13 463,654.32 3.00 6,221.59 Base Hrz 9,300.0 74.69 306.24 5,942.0 5,885.8 1,363.7 - 6,257.1 6,032,460.01 463,590.00 3.00 6,298.71 9,400.0 76.66 308.58 5,966.8 5,910.6 1,422.5 - 6,334.0 6,032,519.18 463,513.30 3.00 6,392.41 9,500.0 78.65 310.88 5,988.1 5,931.9 1,485.0 - 6,409.2 6,032,581.91 463,438.44 3.00 6,485.80 9,570.6 80.06 312.48 6,001.2 5,945.0 1,531.1 - 6,461.0 6,032,628.28 463,386.79 3.00 6,551.45 Kalubik Mkr 9,600.0 80.65 313.15 6,006.1 5,949.9 1,550.8 - 6,482.2 6,032,648.04 463,365.64 3.00 6,578.63 9,700.0 82.67 315.39 6,020.6 5,964.4 1,619.9 - 6,553.1 6,032,717.37 463,295.09 3.00 6,670.63 11/3/2009 12:48:52PM Page 6 COMPASS 2003.16 Build 42 Ill Halliburton Company H 6 LL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 14 - Slot ODS - 14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Wellbore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 5,966.44 9,716.2 83.00 315.75 6,022.6 5,966.4 1,631.4 - 6,564.3 6,032,728.90 463,283.88 3.00 6,685.44 End Dir 9716.20' MD, 6022.60' TVD 9,800.0 83.00 315.75 6,032.9 5,976.7 1,690.9 - 6,622.4 6,032,788.70 463,226.09 0.00 6,761.97 9,900.0 83.00 315.75 6,045.0 5,988.8 1,762.0 - 6,691.6 6,032,860.07 463,157.13 0.00 6,853.30 10,000.0 83.00 315.75 6,057.2 6,001.0 1,833.1 - 6,760.9 6,032,931.44 463,088.17 0.00 6,944.63 10,014.6 83.00 315.75 6,059.0 6,002.8 1,843.5 - 6,771.0 6,032,941.83 463,078.13 0.00 6,957.92 7 10,016.2 83.00 315.75 6,059.2 6,003.0 1,844.6 - 6,772.1 6,032,943.00 463,077.00 0.00 6,959.41 Start Dir 3.0/100' 10016.20' MD, 6059.20' TVD - Kup C - KupB v4 T1A 10,100.0 85.51 315.80 6,067.6 6,011.4 1,904.4 - 6,830.3 6,033,002.98 463,019.09 3.00 7,036.12 10,181.8 87.99 315.84 6,072.2 6,016.0 1,963.0 - 6,887.2 6,033,061.77 462,962.42 3.02 7,111.22 End Dir 10181.80' MD, 6072.20' TVD 10,200.0 87.99 315.84 6,072.8 6,016.6 1,976.0 - 6,899.8 6,033,074.87 462,949.81 0.00 7,127.95 10,261.5 87.99 315.84 6,075.0 6,018.8 2,020.1 - 6,942.6 6,033,119.13 462,907.18 0.00 7,184.46 Start Dir 3.0/100' 10261.50' MD, 6075.00' TVD 10,300.0 89.14 315.77 6,076.0 6,019.8 2,047.7 - 6,969.5 6,033,146.83 462,880.46 3.00 7,219.86 10,329.4 90.00 315.71 6,076.2 6,020.0 2,068.8 - 6,990.0 6,033,168.00 462,860.00 2.93 7,246.96 KupB v3 T2 10,377.1 91.43 315.70 6,075.6 6,019.4 2,102.9 - 7,023.3 6,033,202.24 462,826.86 3.00 7,290.82 End Dir 10377.10' MD, 6075.60' TVD 10,400.0 91.43 315.70 6,075.0 6,018.8 2,119.3 - 7,039.3 6,033,218.68 462,810.94 0.00 7,311.89 10,500.0 91.43 315.70 6,072.5 6,016.3 2,190.8 - 7,109.1 6,033,290.51 462,741.42 0.00 7,403.91 10,600.0 91.43 315.70 6,070.0 6,013.8 2,262.4 - 7,178.9 6,033,362.33 462,671.90 0.00 7,495.93 10,700.0 91.43 315.70 6,067.5 6,011.3 2,333.9 - 7,248.8 6,033,434.15 462,602.38 0.00 7,587.95 10,734.7 91.43 315.70 6,066.7 6,010.5 2,358.7 - 7,273.0 6,033,459.08 462,578.26 0.00 7,619.88 Start Dir 3.0/104' MD, 6066.70' TVD 10,761.0 90.66 315.89 6,066.2 6,010.0 2,377.6 - 7,291.3 6,033,478.00 462,560.00 3.01 7,644.07 KupB v3 T3 10,761.6 90.68 315.90 6,066.2 6,010.0 2,378.0 - 7,291.7 6,033,478.43 462,559.59 3.00 7,644.62 End Dir 10761.60' MD, 6066.20' TVD 10,800.0 90.68 315.90 6,065.7 6,009.5 2,405.6 - 7,318.4 6,033,506.11 462,532.98 0.00 7,679.91 10,900.0 90.68 315.90 6,064.5 6,008.3 2,477.4 - 7,388.0 6,033,578.19 462,463.69 0.00 7,771.82 315.90 6,063.4 6 007.2 2 549.2 -7 11,000.0 90 68 6, -7,457.6 6,033,650.27 462,394.40 0.00 7,863.72 , 11,100.0 90.68 315.90 6,062.2 6,006.0 2,621.0 - 7,527.2 6,033,722.35 462,325.11 0.00 7,955.63 11,169.0 90.68 315.90 6,061.3 6,005.1 2,670.6 - 7,575.2 6,033,772.09 462,277.31 0.00 8,019.04 Start Dir 3.0/100',11169.00' MD, 6061.30' TVD 11,192.5 90.00 315.72 6,061.2 6,005.0 2,687.4 - 7,591.6 6,033,789.00 462,261.00 3.01 8,040.65 KupB v3 T4 11,200.0 89.77 315.72 6,061.2 6,005.0 2,692.8 - 7,596.8 6,033,794.39 462,255.78 3.00 8,047.56 11,238.2 88.63 315.72 6,061.7 6,005.5 2,720.1 - 7,623.5 6,033,821.84 462,229.23 3.00 8,082.71 End Dir 11238.20' MD, 6061.70' TVD 11,300.0 88.63 315.72 6,063.2 6,007.0 2,764.4 - 7,666.6 6,033,866.25 462,186.28 0.00 8,139.57 11,400.0 88.63 315.72 6,065.6 6,009.4 2,835.9 - 7,736.4 6,033,938.09 462,116.78 0.00 8,231.58 11,500.0 88.63 315.72 6,068.0 6,011.8 2,907.5 - 7,806.2 6,034,009.94 462,047.27 0.00 8,323.59 11,600.0 88.63 315.72 6,070.4 6,014.2 2,979.1 - 7,876.0 6,034,081.79 461,977.77 0.00 8,415.60 11,700.0 88.63 315.72 6,072.8 6,016.6 3,050.6 - 7,945.8 6,034,153.63 461,908.27 0.00 8,507.61 11/3/2009 12:48:52PM Page 7 COMPASS 2003.16 Build 42 4111 411111 . Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -14 - Slot ODS -14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Welibore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) . (ft) - 6,018.99 11,800.0 88.63 315.72 6,075.2 6,019.0 3,122.2 - 8,015.6 6,034,225.48 461,838.77 0.00 8,599.62 11,900.0 88.63 315.72 6,077.6 6,021.4 3,193.8 - 8,085.4 6,034,297.32 461,769.27 0.00 8,691.63 12,000.0 88.63 315.72 6,080.0 6,023.8 3,265.4 - 8,155.2 6,034,369.17 461,699.77 0.00 8,783.64 12,100.0 88.63 315.72 6,082.4 6,026.2 3,336.9 - 8,225.0 6,034,441.02 461,630.27 0.00 8,875.65 12,200.0 88.63 315.72 6,084.8 6,028.6 3,408.5 - 8,294.8 6,034,512.86 461,560.77 0.00 8,967.66 12,300.0 88.63 315.72 6,087.2 6,031.0 3,480.1 - 8,364.6 6,034,584.71 461,491.27 0.00 9,059.67 12,343.5 88.63 315.72 6,088.2 6,032.0 3,511.2 - 8,395.0 6,034,615.96 461,461.04 0.00 9,099.69 Total Depth at 12343.50' MD, 6088.20' TVD . 12,343.6 88.63 315.72 6,088.2. 6,032.0 3,511.2 - 8,395.0 6,034,616.00 461,461.00 0.00 9,099.74 KupB v4 T5 ".. Targets ,1 .. ate""'' y..: ,. Target Name ' "/ , - hit/miss target Dip Angle Dip Dt : ry `' TVD °" +E/ WY'* Northing Easting - Shape ( ?) ( ?) 'f� * „ ' _ (ft) ` . , "z r* . 4) (ft) (ft) KupB v4 T5 0.00 0.00 6,088.2 3,511.2 - 8,395.0 6,034,616.00 461,461.00 - plan hits target - Point KupB v3 T4 0.00 0.00 6,061.2 2,687.4 - 7,591.6 6,033,789.00 462,261.00 - plan hits target - Point KupB v3 T3 0.00 0.00 6,066.2 2,377.6 - 7,291.3 6,033,478.00 462,560.00 - plan hits target - Point KupB v4 T1A 0.00 0.00 6,059.2 1,844.6 - 6,772.1 6,032,943.00 463,077.00 - plan hits target - Point ' KupB v3 T2 0.00 0.00 6,076.2 2,068.8 - 6,990.0 6,033,168.00 462,860.00 - plan hits target - Point 1 Casin ured Vertl -=M .. ; Casing Hole lit aapfabisis peps De Diameter Diameter Name (in) (in) 3,650.2 3,000.0 11 3/4" 11.750 14.500 8,000.0 5,365.9 9 5/8" 9.625 12.250 10,014.6 6,059.0 7" 7.000 8.500 12,343.6 6,088.2 4 1/2" 4.500 6.125 11/3/2009 12 :48 :52PM Page 8 COMPASS 2003.16 Build 42 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 14 - Slot ODS - 14 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -14 Survey Calculation Method: Minimum Curvature Weilbore: ODSK - 14 KupB Design: ODSK - 14 KupB wp04.a Formations Measured Vertical Vertical ^ . Dip Depth Depth Depth SS , Dip Direction (ft) (ft) R Name 1-ogy . "-:„; ' , ( ?) ( ?) 9,570.6 6,001.2 Kalubik Mkr 8,850.1 5,791.2 Top Hrz 6,049.8 4,305.2 Brook 2b 2,431.8 2,283.2 Top West Sak 7,796.4 5,255.2 Base Torok Ss 0.00 7,346.0 5,010.2 Top Torok Ss 0.00 3,499.8 2,918.2 Tuffaceous Shales 9,217.7 5,919.2 Base Hrz 1,706.8 1,666.2 Base of Permafrost 0.00 10,016.2 6,059.2 Kup C Plan Annotations Measured Vertical Local Coordinates .Aµ y Depth Depth +NI-S +E -VIl . '; x,,th't,, ;, .. (ft) (ft) (ft) (ft) ',, Commei 4 >, 3 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 600.0 599.9 3.9 -6.8 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 750.0 749.4 9.8 -17.0 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 983.3 979.4 29.1 -50.3 Start Dir 1.50/100' 983.30' MD, 979.40' TVD 1,689.2 1,650.0 112.9 -250.5 End Dir 1689.20' MD, 1650.00' TVD 1,797.9 1,750.0 126.4 -290.8 Start Dir 3.0/100' 1797.90' MD, 1750.00' TVD 2,946.6 2,617.3 280.0 - 1,001.1 End Dir 2946.60' MD, 2617.30' TVD 8,295.3 5,526.5 1,001.1 - 5,431.1 Start Dir 3.0/100' 8295.30' MD, 5526.50' TVD 9,716.2 6,022.6 1,631.4 - 6,564.3 End Dir 9716.20' MD, 6022.60' TVD 10,016.2 6,059.2 1,844.6 - 6,772.1 Start Dir 3.0/100' 10016.20' MD, 6059.20' TVD 10,181.8 6,072.2 1,963.0 - 6,887.2 End Dir 10181.80' MD, 6072.20' TVD 10,261.5 6,075.0 2,020.1 - 6,942.6 Start Dir 3.0/100' 10261.50' MD, 6075.00' TVD 10,377.1 6,075.6 2,102.9 - 7,023.3 End Dir 10377.10' MD, 6075.60' TVD 10,734.7 6,066.7 2,358.7 - 7,273.0 Start Dir 3.0/100' 10734.70' MD, 6066.70' TVD 10,761.6 6,066.2 2,378.0 - 7,291.7 End Dir 10761.60' MD, 6066.20' TVD 11,169.0 6,061.3 2,670.6 - 7,575.2 Start Dir 3.0/100' 11169.00' MD, 6061.30' TVD 11238.2 6,061.7 2,720.1 - 7,623.5 End Dir 11238.20' MD, 6061.70' TVD 12,343.5 6,088.2 3,511.2 - 8,395.0 Total Depth at 12343.50' MD, 6088.20' TVD I 11/3/2009 12 :48:52PM Page 9 COMPASS 2003.16 Build 42 yy 4 $ u =f' i Well Planning - Pioneer - Oooguruk g Oooguruk Development Oooguruk Drill Site ODSK -14 ODSK -14 KupB ODSK -14 KupB wp04.a Sperry Drilling Services Clearance Summary Anticollision Report 03 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Well Coordinates: 6,031,071.09 N, 469,840.87 E (70° 29' 45.45" N, 150° 14' 47.80" W) • Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 r r,� HALLIBURTDN Sperry Drilling Services SURVEY PROGRAM ANTI - COLLISION SETTINGS Date: 2009-11-03T00:00:00 Validated: Yes Version: FOR USE FROM Interpolation Method: MD, interval: 25.0 - -- Depth Range From: 42.7 To 1600.0 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 1430.1 42.7 1000.0 ODSK -14 KupB wp04.a SR- Gyro-SS Reference: Plan: ODSK -14 KupB wp04.a (ODSK- 14 /ODSK -14 KupB) 1000.0 12343.5 ODSK -14 KupB wp04.a MWD +IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference ODSN-4 PS3 ODSN -5i IS4 i ODSN -0 PS 1003N-911S° ODSK -13i Kupl- From Color To MD Range 0 -1500 I Minor Risk 1/20) 0 =2' ' ODSN -28 PN3 144 \ 1 3 - . ODSN 8 PS 43 250 ' 250 500 330 30 SK -131 Kup 500 750 ODSN -12 PS10 4 �i 1 " 1 OD6 11 i ISi i 750 1000 ODSN -29i IN4 1000 1250 PS14 ODSN30 PN 17.60 1600 # 1 / - 1500 - .. - 1750 1 / 1 7 1750 2000 , ' _ ' Of�SN -15i I313 2000 2250 , 1 � Range O -1600 � ' t i � ,Minor Risk 1110 2250 2500 �� ill::::':' .` 2750 --- _....._ 3000 '',' �I ALL ����, ODSN -7i IS7 270 � ` _, , ., 90 I ' _, ,: , / / / 3000 4000 , ` 1 ''; 11111 ttlikM • 4000 5066 ��� ,: / / . u • 'lSN -10 P 5000 6000 �� r'r • / 7 270 K am \ � ge 0 -1600 6000 7000 ,,,�• i I , id ed • q wr '1111 pillill nor Risk 1/20` 0� , . 4, 4 •'. .j 7666 8000 ♦y4�•I�•;. - ODSN31 8000 soon , ���� *A • i 120 w F �'� 9000 -" -- "- 10000 240 - ', � ' ' .. w i 0 ODSN32i IN 10000 11000 • ` s " 11000 12000 i _ � -. ODSN -151 ISIS ` t tri .. Range 0 -1250 Minor Risk 1/10 " .{ ;� �® . ODSN34PN 12000 - 13000 7 0 ' a) o �� ODSN -1 v i . ODSK -35 Ku H ..,':',,1,,,,,,i ° 1 1 i '` ,•$;';,. 8 t+ /�, 13000 `-' 14000 / 210 fl + . - 15Q s • ' '� � " a 120 14000 ' IMO / - • ✓ 414. -9S 1 • 240 aD ` ,; � ✓ / . T f1 `' !.'''•'' 4 OdSK33 Kup 15000 16000 Range 8 1 i 180 Range 0 -1000 r �i ' ' f !' 16000 17000 Range 0 -1 Minor Risk 1 1 ■ t -'4 ✓ \ , ODSN3( Major Risk ODSN -17i IS1 ODSDW2 -20 Dis pos. �' +'" ` - . 17000 18000 • r /1' Range 0 - 125 p 19fili►. ,�- OD 18000 -- 19000 Major Risk ODSn -48 SW _ - - _ 210 ' 4 4 ' � �� _ +. . Y ^^^‘ 19000 20000 -- -- - . .+� ■ ' ODSK38i KupO - - - - i . ODSK -42i Ku • 20000 21000 Travelling Cylinder Azimuth (TFO +AZI) 1?! vs Centre to Centre Separation 120 ft /inl ODSN -47 SW11 wp01 - j - - 16 ODS -40 PN ODSN-39i IN1 ODSN -46 IN1 F - - " ODSN -43 PN11 ODSDWI -44 Disposil I ODSK -42i KupG ODSK -41 Kup Travelling Cylinder Azimuth (TFO+AZI) [ ?[ vs Centre to Centre Separation [50 ft/inl SECTION DETAILS 1-95 Sac MD Inc AA TVD +N / -B •E/ -W Oleg TFace VS.c Target 427 000 000 423 0.0 00 000 000 0.0 300.0 000 000 3000 00 0.0 0.00 0.00 0.0 8000 3.00 300.00 5999 3.9 -6.8 1.00 300.00 95 750.0 6.00 30000 749.4 9.8 -17.0 2.00 000 185 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk 1889.2 2303 26855 16500 ,12.9 -250.5 1 &8 C6 27 1797.9 2303 28855 17500 1264 -2908 0.00 0.00 317.1 N/E Reference: Well ODSK -14 - Slot ODS -14, True North 29966 57.05 27925 2617.3 260.0 - ,901., 3.00 -13.87 1031.8 Co-ordinate ( ) Calculation Method: Minimum Curvature 8295.3 57.05 27825 5528.5 1081.0 5431.1 0.00 0.00 5398.7 Vertical TVD Reference: 42. + 13.5' 56.2ft (Nabors 19AC) o 9716.2 83.00 315.75 6022.6 16313 -6584.3 3.00 80.68 688.54 ( ) erence: 7' @ ( ) Error System: ISCWSA 1 ,00182 8300 315.75 6059.2 18946 -87721 000 000 8959.4 Kup8 v4 T1A Section (VS) Reference: Slot - ODS- 14(0.0N, O.OE) 2 101818 87.99 31584 6072 2 1983.0 -6887.2 3.00 108 7111 2 Scan Method: Tray. Cylinder North 3 10261.5 67.99 316.91 6075.0 2026.1 -6992.7 0.00 0.00 7184.5 Measured Depth Reference: 42.7 + 73.5' @ 56.2ft (Nabors 19AC) Error Surface: Elliptical Conic 4 10329.4 90.00 315.71 8076.2 2088.6 -6990.0 300 -3.91 7247.0 KupB V3 T2 Calculation Method: Minimum Curvature 5 10377.1 91.43 31570 60758 21029 - 7023.3 3.00 -6.25 7290.8 Warning Method: Rules Based 6 10734.7 91.43 315.70 60867 23587 -72729 0.00 0.00 7619.8 7 10761.0 9088 315.89 60682 2377.8 - 7291.3 300 165.79 7644.1 KupB v3 T3 8 10761.8 90.88 315.90 6066.2 23781 - 7291.8 000 14.87 7644.7 9 11189.0 9088 315.90 60613 28705 - 7575.2 000 0.00 80190 20 11192.5 9000 315.72 6081.2 2687.4 - 7591.6 3.00 - ,65.13 80408 KupB 03 T4 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -14 1 11238.2 68.63 315.72 6061.7 2720.1 - 7623.5 3.00 - 160.00 80827 2 12343.8 88.83 315.72 60882 3511.2 "8395.0 0.00 0.00 9099.7 KupBW T5 Ground Level: 13.5 +N/-S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS -14 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSDW1 -44 - ODSDW1 -44 Disposal- ODSDW1 -44 C 125.0 62.2 125.0 59.9 125.0 27.177 Centre Distance Pass - Major Risk ODSDW1 -44 - ODSDWI -44 Disposal- ODSDW1 -44 C 623.9 64.8 623.9 53.9 625.0 5.959 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 675.3 51.3 675.3 38.8 675.0 4.107 Centre Distance Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 774.7 52.1 774.7 37.6 775.0 3.611 Clearance Factor Pass - Major Risk ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05 300.0 7.0 300.0 4.4 300.0 2.637 Centre Distance Pass - Haar Risk 1/200 ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05 649.9 7.9 649.9 3.3 650.0 1.706 Ckwarasice Factor Pass • Maw Risk 11200 ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 298.7 55.7 298.7 50.3 300.0 10.351 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 768.1 61.7 768.1 48.0 775.0 4.497 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 Kup? 298.7 55.7 298.7 50.3 300.0 10.351 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 Kup? 768.1 61.7 768.1 48.0 775.0 4.497 Clearance Factor Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 150.0 45.5 150.0 42.7 150.0 16.177 Centre Distance Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 424.1 47.1 424.1 39.6 425.0 6.243 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 223.7 32.3 223.7 28.2 225.0 7.811 Centre Distance Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 373.3 33.2 373.3 26.4 375.0 4.878 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 48.7 39.0 48.7 37.9 50.0 34.234 Centre Distance Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 398.2 40.6 398.2 33.4 400.0 5.586 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 48.7 39.0 48.7 37.9 50.0 34.234 Centre Distance Pass - Major Risk III ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 398.2 40.6 398.2 33.4 400.0 5.586 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.1 100.0 43.1 100.0 41.2 100.0 23.003 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.t 474.2 45.9 474.2 37.4 475.0 5.405 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 75.0 43.1 75.0 41.5 75.0 26.926 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 374.7 44.1 374.7 37.2 375.0 6.371 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 300.0 113.0 300.0 107.4 300.0 19.991 Centre Distance Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 374.6 113.6 374.6 106.6 375.0 16.229 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - 6 300.0 39.0 300.0 33.4 300.0 6.904 Centre Distance Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - 6 649.0 41.8 649.0 29.8 650.0 3.493 Clearance Factor Pass - Major Risk ODSN -11 i - ODSN -11 i IS11 - ODSN -11 i IS11 wp11 tef. 300.0 32.0 300.0 26.4 300.0 5.663 Centre Distance Pass - Major Risk ODSN -11 i - ODSN -11 i IS11 - ODSN -11 i IS11 wp11 te: 798.8 34.9 798.8 20.0 800.0 2.335 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:07 Page 2 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 300.0 25.0 300.0 19.5 300.0 4.496 Centre Distance Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 724.0 28.0 724.0 14.8 725.0 2.116 Clearance Factor Pass - Major Risk ODSN -15i - ODSN -15i IS13 - ODSN -15i IS13 wp08 750.1 6.7 750.1 3.0 750.0 1.813 Centre Ofetance Pass - Mhor Maki/10 IP ODSN -15i - ODSN -15i IS13 - ODSN -15i 1S13 wp08 775.1 6.8 775.1 3.0 775.0 1.790 Clearance Factor Pass - Mkwr Risk 1/10 ODSN -16 - ODSN -16 PS14 - ODSN -16 PS14 wp09 500.0 13.5 500.0 9.6 500.0 3.481 Cam Distance Pis - Minor (skc 1/200 ODSN -16 - ODSN -16 PS14 - ODSN -16 PS14 wp09 550.0 13.6 550.0 9.5 550.0 3.276 Clearance Facts' Pass - Mior Rbsc 1/200 ODSN -17i - ODSN -17i 1S15 - ODSN -17i IS15 wp08 450.1 20.6 450.1 12.3 450.0 2.472 Centre Distance Pass - Major Risk ODSN -17i - ODSN -17i IS15 - ODSN -17i IS15 wp08 675.1 22.5 675.1 10.2 675.0 1.829 Clearance Factor Pass - Major Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 275.0 27.9 275.0 22.8 275.0 5.388 Centre Distance Pass - Major Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 875.6 32.1 875.6 15.5 875.0 1.932 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 300.0 106.0 300.0 100.4 300.0 18.753 Centre Distance Pass - Major Risk OQSN-2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 449.3 106.7 449.3 98.4 450.0 12.761 Clearance Factor Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 298.7 117.6 298.7 112.0 300.0 20.889 Centre Distance Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 372.9 118.3 372.9 111.4 375.0 17.077 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 300.0 110.9 300.0 105.3 300.0 19.620 Centre Distance Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 423.7 111.7 423.7 103.8 425.0 14.127 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 300.0 104.2 300.0 98.6 300.0 18.436 Centre Distance Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 473.2 105.7 473.2 96.9 475.0 11.990 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 300.0 97.6 300.0 92.0 300.0 17.271 Centre Distance Pass - Major Risk • ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 374.3 98.3 374.3 91.4 375.0 14.172 Clearance Factor Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 300.0 91.1 300.0 85.4 300.0 16.114 Centre Distance Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 423.8 91.9 423.8 84.0 425.0 11.650 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 300.0 84.6 300.0 78.9 300.0 14.962 Centre Distance Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 473.4 86.2 473.4 77.4 475.0 9.779 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31 PB1 PN6 S 300.0 67.9 300.0 62.3 300.0 12.118 Centre Distance Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31 PB1 PN6 S 374.4 68.4 374.4 61.6 375.0 10.018 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 300.0 67.9 300.0 62.3 300.0 12.118 Centre Distance Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 374.4 68.4 374.4 61.6 375.0 10.018 Clearance Factor Pass - Major Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 150.0 61.9 150.0 59.1 150.0 22.309 Centre Distance Pass - Major Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 399.2 62.8 399.2 55.6 400.0 8.728 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:07 Page 3 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. . Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 150.0 61.9 150.0 59.1 150.0 22.309 Centre Distance Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 399.2 62.8 399.2 55.6 400.0 8.728 Clearance Factor Pass - Major Risk ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 300.0 49.0 300.0 43.5 300.0 8.922 Centre Distance Pass - Major Risk • ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 374.5 49.5 374.5 42.8 375.0 7.371 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 300.0 49.0 300.0 43.5 300.0 8.922 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 341PB1 IN9 - ODSN- 34iPB1 IN9 374.5 49.5 374.5 42.8 375.0 7.371 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 300.0 49.0 300.0 43.5 300.0 8.922 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 374.5 49.5 374.5 42.8 375.0 7.371 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 300.0 49.0 300.0 43.5 300.0 8.922 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 374.5 49.5 374.5 42.8 375.0 7.371 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 175.0 40.9 175.0 37.6 175.0 12.371 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 324.8 41.4 324.8 35.5 325.0 7.086 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 175.0 40.9 175.0 37.6 175.0 12.371 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 324.8 41.4 324.8 35.5 325.0 7.086 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 175.0 40.9 175.0 37.6 175.0 12.371 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 324.8 41.4 324.8 35.5 325.0 7.086 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 349.7 32.4 349.7 26.0 350.0 5.005 Centre Distance Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 399.4 32.7 399.4 25.4 400.0 4.482 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 42.7 33.5 42.7 32.5 42.7 33.326 Centre Distance Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 324.9 35.2 324.9 29.2 325.0 5.889 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 42.7 33.5 42.7 32.5 42.7 33.326 Centre Distance Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 324.9 35.2 324.9 29.2 325.0 5.889 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 300.0 99.0 300.0 93.4 300.0 17.646 Centre Distance Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 548.8 100.7 548.8 90.6 550.0 9.919 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 300.0 92.1 300.0 86.4 300.0 16.284 Centre Distance Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 424.5 93.1 424.5 85.2 425.0 11.750 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 42.7 35.6 42.7 34.6 44.0 35.383 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 323.6 36.7 323.6 30.8 325.0 6.196 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 42.7 35.6 42.7 34.6 44.0 35.383 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 323.6 36.7 323.6 30.8 325.0 6.196 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:07 Page 4 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 42.7 35.6 42.7 34.6 44.0 35.383 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 323.6 36.7 323.6 30.8 325.0 6.196 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 298.7 56.4 298.7 50.8 300.0 10.012 Centre Distance Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 373.4 57.0 373.4 50.1 375.0 8.305 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 42.7 68.3 42.7 67.2 42.7 62.382 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 324.9 70.4 324.9 64.3 325.0 11.380 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 42.7 68.3 42.7 67.2 42.7 62.382 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 324.9 70.4 324.9 64.3 325.0 11.380 Clearance Factor Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 300.0 74.5 300.0 68.9 300.0 13.179 Centre Distance Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 374.8 75.1 374.8 68.2 375.0 10.915 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 298.7 80.9 298.7 75.3 300.0 14.370 Centre Distance Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 373.5 81.5 373.5 74.6 375.0 11.879 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 298.7 87.3 298.7 81.7 300.0 15.506 Centre Distance Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 373.5 87.9 373.5 81.0 375.0 12.794 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i 154 - ODSN -5i 154 wp08 300.0 85.0 300.0 79.4 300.0 15.040 Centre Distance Pass - Major Risk ODSN -5i - ODSN -51 IS4 - ODSN -5i 134 wp08 499.2 86.4 499.2 77.1 500.0 9.310 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 300.0 78.0 300.0 72.4 300.0 13.804 Centre Distance Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 474.4 79.6 474.4 70.8 475.0 9.032 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 300.0 60.0 300.0 52.4 300.0 7.857 Centre Distance Pass - Major Risk • ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 648.4 63.6 648.4 46.4 650.0 3.694 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K hor 300.0 53.0 300.0 47.5 300.0 9.529 Centre Distance Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K hor 524.4 54.6 524.4 45.0 525.0 5.666 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K Hor 300.0 46.0 300.0 40.4 300.0 8.267 Centre Distance Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K Hor 599.4 48.7 599.4 37.7 600.0 4.428 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:07 Page 5 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Survey tool program From To Survey /Plan Survey Tool (ft) (ft) SR-Gyro-SS 42.7 1,000.0 ODSK -14 KupB wp04.a SR -G Y 1,000.0 12,343.5 ODSK -14 KupB wp04.a MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. • Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 03 November, 2009 - 14:07 Page 6 of 8 COMPASS n Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 ODSK -14 KupB ODSK -14 KupB wp04.a Sperry Drilling Services Clearance Summary Anticollision Report 03 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a • Well Coordinates: 6,031,071.09 N, 469,840.87 E (70° 29' 45.45" N, 150° 14' 47.80" W) Datum Height: 42.7' + 13.5' © 56.2ft (Nabors 19AC) Scan Range: 1,600.0 to 12,343.6 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 r - 1 HALLIBURTON h Sperry Drillirlig Services SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2009- 11- 03T00:00:00 Validated: Yes Version: IFOR USE FROM Interpolation Method: MD, interval: 25.0 Depth Range From: 1600.0 To 12343.6 Depth From Depth To Survey /Plan Tool 1600' TO TD Results Limited By: Centre Distance: 1430.1 42.7 1000.0 ODSK -14 KupB wp04.a SR- Gyro -SS Reference: Plan: ODSK -14 KupB wp04.a (ODSK- 14IODSK -14 KupB) 1000.0 12343.5 ODSK -14 KupB wp04.a MWD+IFR2 +MS +sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference ODSK -13i KupH Range 1600 -225,) Major Risk ODSK -13i KupH ° Range 1600 - 1750 From Color To MD "0, ��� p Major Risk 330 ' ' 0 C �� 30 43 250 330 \ `\` 30 ' 1 �r� = � � A \ tt, 250 500 _. � .. 0 , . ' ....46.1%.,,,,1,%111, � ODSN -11i IS11 500 750 •� 200r j..($%sSo � ftiPJ ,, 60 • / ,- 1tit 2750 3000 , �� ,, akm141 t1 '',;, �� �� ' , z7o '''' // i 11111 1► t.t :. • 90 4000 _ 5000 1 %Wig( ��,r + � - - 5000 6000 ,, ` 1 4 , �D SN - 15i iS1s 000 8000 t ''' t, 3� ' �� ' ; ; j Range 1600 - 225? 3000 4000 6 ,, ,, - ,, ` t 240 , ` , 120, ` ``� `� 8000 , ,, , i , `� 9000 10000 ,, , 20 ,� ‘11k 10000 - -- -- 11000 , � ` / . 12000 t � � ODSK -13i KupB 11000 ,` ' 1 -1750 ` ` 50 / /�� / / /� ; �� � .� 11000 --------- 13000 210 ` � ' 150 a `` � � / / 717//fi,i r'i'i1� �,' 120 13000 14000 30 Mor Rrsk • j z40 ` ` l�l / l � t �I �l 14000 15000 180 ` // /// / '• // �/ - 15000 16000 ` ` ' '� l ., �/ / I ODSN -18 PS16 ,,,.///// : l /� ' - - - Range 16000 17000 ■ l / sk - 2500 ' II jjj // Major Risk 17000 18000 18000 19000 210 -- 150 - _._ 19000 20000 Travelling Cylinder Azimuth (TFO+AZI) r] vs Centre to Centre Separation 120 ft /inl _�_� ODSN -36 PN10 20000 21000 180 '-• Range 10000 - 11000 Major Risk SECTION DETAILS Si e MD Inc AP TVD 251S •E/ -W DLe9 TFace VSec Target 1 427 000 0.00 42/ 0.0 0.0 000 000 00 2 3000 000 000 300.0 00 00 000 000 00 Travelling Cylinder Azimuth (TFO +AZI) ?' vs Centre to Centre Separation X50 ft /inl 3 6000 3.00 300.00 5999 3.9 -68 1.00 30000 7.8 4 750 0 6.00 300.00 749.4 9.8 -17 0 2 00 0.00 19.5 5 9833 1100 300.00 9794 29.1 -503 300 0.00 57.6 6 1889.2 2103 288.55 1650 0 1129 -250 5 150 -2500 274.7 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk 7 1797.9 2303 28855 17500 126.4 -2908 000 0.00 317.1 8 29466 57.05 279.25 26173 280.0 - 1001.1 3.00 -13.87 10318 9 8295.3 57.05 27925 55285 1001.1 - 5431.1 000 0.00 5396/ 10 9716.2 8100 315 75 6022 8 1631.3 65643 100 60.68 68854 Co- ordinate (N /E) Reference: Well ODSK -14 - Slot ODS -14, True North Calculation Method: Minimum Curvature 11 100162 6300 315.75 60592 1844.6 - 8772.1 0.00 000 6959.4 KupB v4 T1A Vertical (ND) eference: 42.T + 13.5' 56.2ft (Nabors 19AC 12 10181.8 8799 315.84 60722 19830 - 8887.2 300 1.08 7111 2 ) @ ( ) Error System: ISCWSA 13 10261.5 8799 315.84 6075.0 20201 6942.7 000 0.00 71845 Section (VS) Reference: Slot - ODS- 14(0.0N, 0.0E) 14 103294 9000 315.71 6076.2 20688 69900 3.00 -191 72470 KupB 03 T2 Measured Depth Reference: 42.7'+ 13.5' @ 56.2ft (Nabors 19AC) Scan Method: Tray. Cylinder North 181 1 9jg3 sls70 6075.6 0 2102 -inze 30 0.2 MO Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 17 10761.0 90.66 315.89 60662 2377.6 - 7291.3 3.00 18579 76441 KupB v3 T3 Warning Method: Rules Based 18 10761 90.88 31590 6086.2 2378.1 9291.8 3.00 1487 7644.7 g 6 19 111690 90.68 315 913 6061.3 2870.5 - 7575.2 000 0.00 8019.0 20 111928 90.00 31572 6061.2 28871 -75918 3.00 - 185.13 8040 6 60564904 21 112382 88.63 31572 6061 7 27201 - 76215 100 - 180.00 8082.7 22 123435 8883 31572 60882 35112 - 8395.0 0.00 000 9099.7 KupB v4 T5 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -14 Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031071.09 469840.87 70° 29' 45.449 N 150° 14' 47.798 W ODS -14 Well Planning - Pioneer - Oooguruk H ALLI BU RTO N Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 1,600.0 to 12,343.6 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site • ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 C 1,612.3 271.0 1,612.3 244.7 1,675.0 10.282 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 1,615.8 310.1 1,615.8 283.9 1,700.0 11.822 Clearance Factor Pass - Major Risk ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05 1,621.4 52.6 1,621.4 22.1 1,625.0 1.724 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 1,608.6 166.1 1,608.6 140.8 1,650.0 6.552 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 KupF 1,608.6 166.1 1,608.6 140.8 1,650.0 6.552 Clearance Factor Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 1,608.5 263.4 1,608.5 238.3 1,675.0 10.507 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 1,616.0 431.5 1,616.0 405.8 1,750.0 16.779 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 1,600.0 415.5 1,600.0 389.8 1,725.0 16.118 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 1,600.0 415.5 1,600.0 389.8 1,725.0 16.118 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.1 1,613.9 401.6 1,613.9 374.4 1,725.0 14.787 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 1,618.1 392.2 1,618.1 363.9 1,725.0 13.843 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 1,600.0 504.6 1,600.0 476.2 1,750.0 17.785 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - E 1,619.3 154.6 1,619.3 126.0 1,650.0 5.396 Clearance Factor Pass - Major Risk ODSN -11i - ODSN -11i IS11 - ODSN -11i IS11 wp11 te: 1,609.7 93.5 1,609.7 61.2 1,625.0 2.897 Clearance Factor Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 1,600.0 132.0 1,600.0 105.7 1,625.0 5.022 Clearance Factor Pass - Major Risk ODSN -15i - ODSN -15i IS13 - ODSN -15i IS13 wp08 1,616.9 56.9 1,616.9 28.8 1,625.0 2.025 Clearance Factor Pass - Major Risk ODSN -16 - ODSN -16 PS14 - ODSN -16 PS14 wp09 1,603.4 119.7 1,603.4 92.6 1,625.0 4.414 Clearance Factor Pass - Major Risk ODSN -17i - ODSN -17i IS15 - ODSN -17i IS15 wp08 1,607.5 126.1 1,607.5 97.1 1,625.0 4.353 Clearance Factor Pass - Major Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 1,620.6 69.4 1,620.6 38.2 1,625.0 2.227 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 1,616.9 467.0 1,616.9 437.0 1,750.0 15.591 Clearance Factor Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 1,600.0 624.7 1,600.0 596.9 1,825.0 22.464 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 1,615.1 515.0 1,615.1 485.6 1,775.0 17.515 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 1,600.0 478.4 1,600.0 450.5 1,750.0 17.171 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 1,610.0 600.7 1,610.0 572.3 1,825.0 21.144 Clearance Factor Pass - Major Risk ODSN -291 - ODSN -29i IN4 - ODSN -29i IN4 wp06 1,606.7 512.1 1,606.7 484.7 1,775.0 18.711 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 1,600.0 507.5 1,600.0 480.6 1,775.0 18.853 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31PB1 PN6 S 1,605.8 552.8 1,605.8 525.7 1,800.0 20.459 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 1,605.8 552.8 1,605.8 525.7 1,800.0 20.459 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:35 Page 2 of 6 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a Scan Range: 1,600.0 to 12,343.6 ft. Measured Depth. Scan Radius is 1,430.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 1,600.0 459.9 1,600.0 432.4 1,750.0 16.719 Clearance Factor Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 1,600.0 459.9 1,600.0 432.4 1,750.0 16.719 Clearance Factor Pass - Major Risk ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 1,610.7 535.2 1,610.7 509.0 1,800.0 20.382 Clearance Factor Pass - Major Risk III ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 1,610.7 535.2 1,610.7 509.0 1,800.0 20.382 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 1,610.7 535.2 1,610.7 509.0 1,800.0 20.382 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 1,610.7 535.2 1,610.7 509.0 1,800.0 20.382 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 10,434.4 241.3 10,434.4 114.2 16,850.0 1.898 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 1,600.0 807.2 1,600.0 780.1 1,975.0 29.742 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 1,600.0 807.2 1,600.0 780.1 1,975.0 29.742 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 1,605.1 503.0 1,605.1 475.8 1,775.0 18.518 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 1,612.4 502.4 1,612.4 476.0 1,775.0 19.028 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 1,612.4 502.4 1,612.4 476.0 1,775.0 19.028 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 1,604.0 379.1 1,604.0 348.8 1,700.0 12.525 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 1,617.9 291.2 1,617.9 257.8 1,675.0 8.726 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 1,607.0 556.1 1,607.0 530.1 1,800.0 21.324 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 1,607.0 556.1 1,607.0 530.1 1,800.0 21.325 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 1,607.0 556.1 1,607.0 530.1 1,800.0 21.325 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 1,614.6 610.3 1,614.6 582.4 1,825.0 21.865 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 1,604.0 448.3 1,604.0 421.7 1,725.0 16.830 Clearance Factor Pass - Major Risk • ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 1,604.0 448.3 1,604.0 421.6 1,725.0 16.829 Clearance Factor Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 1,611.3 454.1 1,611.3 424.4 1,725.0 15.297 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 1,607.7 488.2 1,607.7 459.4 1,725.0 16.922 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 1,615.2 439.3 1,615.2 409.7 1,700.0 14.806 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 1,616.4 276.7 1,616.4 247.9 1,675.0 9.622 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 1,608.9 246.3 1,608.9 215.2 1,650.0 7.909 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 1,600.0 287.9 1,600.0 252.0 1,675.0 8.004 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K' hor 1,608.8 209.5 1,608.8 1 80.5 1,650.0 7.238 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K' Hor 1,600.0 153.0 1,600.0 123.2 1,625.0 5.120 Clearance Factor Pass - Major Risk 03 November, 2009 - 14:35 Page 3 of 6 COMPASS Well Planning - Pioneer - Oooguruk g g HALLIBURTON Oooguruk Development Anticollision Report for ODSK -14 - ODSK -14 KupB wp04.a Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 42.7 1,000.0 ODSK -14 KupB wp04.a SR- Gyro -SS 1,000.0 12,343.5 ODSK -14 KupB wp04.a MWD +IFR2 +MS +sag • Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 03 November, 2009 - 14:35 Page 4 of 6 COMPASS N C C Project: Oooguruk Development 9000 I O 1 V L L jjj Site: Oooguruk Drill Site - I ,; '1' t _ ADS 7500 _ _ 3� KupH .05 -• • ■ •••••• ■� - _ ' _ 1 111••••••••••• ■ ..M.=- • ' :: . ' IN7 .. I ME®EM� _ 1 ■ ■■ 1112/........ ■■■■ IMM 6000 - ■M�� - IIIEi.ji.r , in _-.. , 6 . 1 1 1 1 ■ ■■ ■III► a, ` 1 ■ ■1 ■ ■�■■ 4500 , • u : _ • ® 111 I!! a _ u ■ I ■ ■■ 311e1011•1, ■ , \� ■ • ■ , 1111 II 1 ■■ .. :.. !� 11\\ ma \ ��1■ No ■ I ■ __■ 11miie��■■ ►I• ■■ w 1 500 -� ■_ ■= ■■ ■�iu� 1C\1�•• 0 U• ■■ i1■IS 1 ■ ILUI1I A iipmeam 1 v o 0 - _. _ �■ _ —■ _ ■ ■,._—.`\ JI —, ... � ■d. ■ ■O ■ ■��� /I.► .. :.,■�� ....�.. Z • 1 ® ®■■ �■II■iI ■ ■ro■ OD' K.3. �, i ■ ■ ■ ■■1■ ■■■ _ 11 1••• \II■1■■► • -3t .. A,�� 1■ -1500 N - ■ _ - w ' : ODSN • OPB2 PN E o _ ■ ■I■■■ �Ne limimummmIEI ■ ■ ■ ■1 •■...,.i, _,. : . •: o. -K 3P-ing_ o... -3000 ■■�■___ ■ 1111:= ww■w■■■►�-33 uP I' � . ,__■_ _ MI ■ ■ 1■■P II ,1■12��,// • I■ ■1■ ■ • ■ ■ ■Ir 1 ICY ■ ■ /III I UUI11■ ■1 ■■ ■ ME� ■___ ■ ■- 1 ■�1_ _■ ►'rin►i i 11111A■■■ \`� I 6000 ■■■�■■= == ■■�∎MMM�e■■e ■L�E■■■■■� MM� o� _ ■ ii■i rfl■■ ■IIA ■1■■■ ,■ ■ -7500- H rill ' � : a KPG4i1 " III ■I•■■ „ Ii11 • H 9000 1111 II lift _ r -10500 16500 15000 -13500 -12000 10500 ! 9000 I I i75 I I i i I I I I __ i I 1 i I i i i i i 1 1 I i i i IM I I i i r i I i I 00 - 6000 -4500 -3000 -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -) /East( +) (3000 ft/in) N I I _,,,p, Legend - -- - ti �:a • :. 1 7._ I ` p 'b ° � 11 As —buNt Conductor k ° — 'IR w"� g 0 • Pro of l000tkn '"(''_ ° b o 1 '1" �� ° ° , " tru ° tig - °.-°„ 1 . ;`' 41 in. CP° 0 0 0 /t ..:: 41S 7I4i -- }. N ry 'vl ieY: s D ,� o o q . vs n a Location Map N • GRAPHIC SCALE �' ° ° 30 _ 15 0 30 0 _SV1� ,� • � 4," 4 A X 11 4 0 7 N • yj�� 0 • ° � ilr G. Davis i o • 1 ,� o, 0 9 s&�s No. 41104 0.5 "• ` : � 4 a 9) ° , o � 0 • 0 0 ,� 4� O a..«° *Cr 4. rye. ti 0 o tQ ,; RQ °FSSiONNO rt. ° 0 k'� ri�aww• C 0 kti Cl,' o `� 012. ` 0 e I- 1, i.. ,of a "T ; f a f I A'. a r ° tip 0 kA Pioneer Natural Resouoes JOB NAME: Oooguruk Drill Site DRAWN BY: BL I CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: 1 " ..30' Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian Notes: NANUQ JOB NO. SHEET Coordinates are listed on sheets 3 and 4 DESCRIPTION: Alaska Nad 27. Zone 4 Conductor As —built Plan 05204 1 of 4 • • 1 G i z t i _ s , i I l •-District 8oundry I 9 i 1 ` I SE Corner of BOOcURUK SITE Protracted Section 1 11 I ,` It K • ,` S a NJ I $; - j1 Coordinates ill N 6028111.04 J 1 E 470989.01 1 o PI-2s I ` �� g I m 4 / Ref: AK BLM s i o: " ` 1 ` Ni i Harrison. Boy Tract "A" , , I ♦ -24.` rowi ----- _ . - % ;, _ la u� I zt `� \' �, A 12, if-- IP . —--- S A S l - - _ Q` I Offshore Icerood =5.99 AJfes 1 � • eor Shore lceroa4 =3 -82 -Li - 13 a 20 to Doz.:wro k Site I 11 � PI 7 to P1 20 a :s ■ s 1 ffi a l � 1 t - 1, `~ Pa'14 �` ` PI-2 ` / 151-15 3 % . 64 _ 17 Tundra leered A • P �_ Roods to Ulu ...iiiiii , Pi— ..11. 1 Ti B UC ; � ' ,/ Basis of Location . t' EN� DS -3H West Monument if : . V Coordinates :Ili N 6001016.61 ' ' E 498081.23 -STAKED PI INFORMATION ONLY 4. ?h' Cl m ' . j i ,. t _�,. � '• Ref. Lownsbury & Assoc. II W h La , D : , f :' s Drawing No. Ct a� ----^ NSK 6.01 –d672 44■ OF A41%1 �•M• . • • .• $ ,�; ,7 I a � "+ ,,, -..'7,1-: * i. 'I 1 -i M .•.� ••• �T s L s i 1 10 . ilipG.Davis o% 1 Pioneer Natural Resouces JOB NAME: Ooogu'ruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 . 2 of 4 . . ; Welo -------- AI,WS, - t - td - P - Ib :::--- T --------------- l N, - • - 'Pa FEL - -- 1 6,031,151,32 469,920,0 . 70 29 46,24160 150 1445:464.68 . 3035 1077 13,50 . ' 2 6,031,10,3..5 4-69,915,52 70 29 46,19252 150 14 45,00922 3030 1082 . 13,50 r, . .. • , . 6,031,141,39 469,910,59 70 29 40,143.54 150 14 45,75375 3025 1007 13,50 4 .. 6,031,130,46 469905,67 • 70 29 46.09485 150 14 45,89799 3020 1092 13.50 -• : 5 - 6,031,131,45 469,900,74 ' 70 29 46,04538 150 14 4604252 3015 - 1097 - 13,50 6 0,031,126,51 469,895,80 70 29 45,99000 150.14 46,18735 3010 1102 13,50 0,031,113,73 409,083,13 70 29 45,87039 . 150 14 46,55879 2997 1115 , 13,50 - 8 6,031,108,73 469,878,21 70729 45,82102 150 14 46.,70303 2992 1120 - 13,50 i • 9 0,031,103.75 469,873,26 70 29 45.77184 150 14 46,84814 2987 1125 ; 1$,50 "10T 6,0'1,098,79 469,868,3 70 29 45,72286 150 14 46,99179 2982 1130 1 • 13,50 • 11 , 0,031,093,84 469,863,39 70 29 45,07398 150 14 47,13750 2977 1135 r 13,50 '- 1 0,031,058,87 469,858,47 70 29 45,02490 150 14 47,28174 2972 1140 13,50 •' 5,031,070,06 469,845,81 70 29 45,49840 150 14 47,65288 2950 _1152 1a,50 - ..... --> 14 0,031,071,09 .7 469,840,87 . , 70 29 45,44932 150 14 47,79770 2955 • 1157 - •13,50 • - .. 15 6,031,000.15 469,835,96.. 70 29 45,40053 150 14 47,94105 2950 1162 13,50 16 6,031,061-1S 409,831,04 70 29 45,35145 150 14 48,08588 294$ - 11R 13,50 - - 17 0,031,056,25 469,826,11 70 29 45,30277 150 -14 48,23042 2940 1172 13,50. . - 18 6,031,051,27 469,821,18 70 29 -45,253'59 150 14 48,37495 2935 1177 1350 .- • 19 0,031,038,52 409,808,50 70 29 45,12768 150 14 4(3,74660. 2922 1189 1350 20 0,031,033,50 469,003,59 70 29 45,07811 150 14 48,89061 2917 . 1194 13,50 • • . 21 6,031,020,53 469,798,62 70 29 45,02903 150 14 49,03632 ' 2912 1199 13,50 -- 22 • 6,031,023,58 409,793,07 70 29 44,98014 150 14 49,18144 2907 1204 • • 13,50 • • • 23 0,031,010,57 409,788,76 70 29 44,93067 150 14 49,32537 2902 1209 7- 0,50 • • 24 0,031,013,00 469,783,84 70 29 44,88159 . 150 14 49,40960 2897 1214 13,50 .„,:votite ar 'S ..** .: .. ••• 4- i , . or CO io •44:,.. - 1/ 6 • 17 Pt r j e ,„,, 9 :''''." \ * 2 • IND •• /m.o. ., wimp. •• • • - 0 t • • • •• '. 13:M e ,,,:::;::''',._73 . t Philip G. Davis 1 ei(5. P4 4110.5 • P 1 ...:4ar . .: • s% . s..........e;: ..• 4 . - - - ;'"'•1$14'j•'.-'i....t 1 : 7 .. - ..-i- ' : • ii,..:."•:;:)4 ii 4. ve............"0" -.,,:,,-..% --, .::•..e4*_ --...-4, .. - • ..V;;; .'' '...::. - -4!!: . Notes: 1. Elevations ore based on BP Mean Sea Level, ' ----.•.,..._._.: •-..-- 2 Coordinotes ore Posed. on Alaska State Plane Nod 27, Zone 4, . 3, M conductors ore within Protrocted Section 11, . pioneer Noturol Resouces .• . JOB NAME; Oooguruk Drill Site Conductors DRAWN BY; BL CHECKED BY; MD LOCATION; ' ' Protrocted Section 1 I SCALE: N/A Township 13 North - . Ronge 7 Ecist DATE: - 7-12-07 Umiot meridion . ____ _ NAN JOE3 NO, SHEET C.IESCRIPTION: As-bu II t Coordinates • . • 05204 3 of 4 Well No. Alaska State PI• Latitude (N) Longitude (� , Section Line Offset Pad Elev. Y X FSL FEL 25 6,031,128.32 469, 943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469, 938.69 70 29 45.96722 150 14 44.92442 3008 1060 13.50 27 6,031,118.33 469, 933.76 70 29 45.91765 150 14 45.06895 300 1065 13.50 28 6,031,113.39 469,928.86 70 29 45.86887 150 14 45.21260 2997 1070 13.50 29. 6,031,108.44 469, 923.95 , 70 29 45.81999 150 14 45.35655 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50 31 6, 031, 090.65 469, 906.38 70 29 45.64431 150 14 45.87163 2975 1092 13.50 . 32 6, 031, 085.68 469, 901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6, 031, 080.67 469, 896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 . 1106 13.50 35 6, 031, 070.76 469, 886.60 70 29 45.44789 150 14 46.45152 2955 1111 . 13.50 36 6, 031, 065.83 469, 881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6, 031, 053.00 469, 869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 15014 47.25478 2927 1139 13.50 40 6, 031, 038.10 469, 854.21 70 29 45.12537 150 14 47.40108 2922 1144 13.50 41 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6, 031, 028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 - 1154 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6, 031, 000.54 469, 816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 469,811.98 70 29 44.70469 150 14 48.63910 2879 1186 13.50 48 6, 030, 990.58 469, 807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 , o 4 Z �.'.NvIet ►t SURVEYOR'S CERTIFICATE .r,_.< •..¢ $ I HEREBY CERTIFY THAT I AM • Jo h : ` • 9 i PROPERLY REGISTERED AND • ;*14. ' ; * ► d � AND THAT I BELIEVE THAT ALL LICENSED TO PRACTICE LAND j••• • "'• " 1 SURVEYING IN THE STATE OF y �,., - 0 • `..... . ALASKA AND THAT THIS PLAT ,: f , �� �� � 1 � 1 • ili G. Davis ill REPRESENTS A SURVEY DONE BY + , t , F ± F a s >� N 41103 •,4 i ME OR UNDER MY SUPERVISION i � } ? . � a i 9eo �• ••« • • - c. 4 , ` F ti , ` x : , z ' DIMENSIONS AND OTHER DETAILS 5. i °; a1 4�,. . w ARE CORRECT AS SUBMITTED TO , ,� - x ME BY NANUQ, INC. AS OF JULY - ,`- -° 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD. LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET . DESCRIPTION: As -built Coordinates 05204 4 of 4 Page 1 of 1 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson @pxd.com] Sent: Friday, December 11, 2009 3:35 PM To: Schwartz, Guy L (DOA) Cc: Vaughan, Alex; Franks, James Subject: ODSK -14 Permit to Drill Application Guy, As discussed, the cement calculations for the second intermediate hole should read 86 sx instead of 286 sx. Also, the estimated reservoir pressure range for the Kuparuk reservoir is 2800 psi -3000 psi. This translates to 8.9 -9.5 ppge at the reservoir. To clarify our plans for Managed Pressure Drilling (MPD), we plan to drill intermediate hole into the reservoir (8- 1/2" hole) with 9.8 ppg mud, holding 12.5 ppge with MPD for wellbore stability. Static mud weight will be higher than the expected range of reservoir pressures. After setting casing in zone, we plan to drill the horizontal section in the Kuparuk sand with 8.6 -8.8 ppg mud, holding kill weight equivalent with MPD. During trips, we will displace to kill weight fluid plus trip margin prior to disengaging the MPD equipment. Please call if you have any further questions or need clarification. Regards, Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2111 office 907 - 575 -9430 cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/11/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ODSK -14 PTD# 2091550 X Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Oooguruk POOL: Oooguruk, Oooguruk- Kuparuk Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) 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 * ,_ - s'' Field & Pool OOOGURUK, KUPARUK OIL - 576100 a � � : Well Name: OOOGURUK KUPODSK -14 Program DEV Well bore seg ❑ PTD#: 2091550 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class /Type DEV / PEND GeoArea 973 Unit 11550 On /Off Shore On Annular Disposal ❑ Administration 1 1 Permit fee attached NA 12 Lease number appropriate Yes Entire well in ADL 355036 3 Unique well name and number Yes 4 Well located in a defined pool Yes 1 5 Well located proper distance from drilling unit boundary Yes 000GURUK, KUPARUK OIL - 576100, governed by Conservation Order No. 596 and AIO No. 33 - 6 Well located proper distance from other wells Yes CO 596 specifies no restrictions as to well spacing except no pay open within 500' 7 Sufficient acreage available in drilling unit Yes of external property line. of external property line. Well will be >2000' from exterior boundary of '8 If deviated, is wellbore plat included Yes Oooguruk Unit. 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 1 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 12/1/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production Less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers, A10 33 Conclusion 3 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons No OH slotted liner completion. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 1 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Passes all major risk criteria. 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in area. 20 AAC 25.035(h) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3073 psi (9.8 ppg EMW) will drill with 8.6 -9.8 ppg mud and MPD technique. l GLS 12/7/2009 1 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2410 psi Will test BOP to 4500 psi. 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No No H2S expected. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA ; Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S monitors will be operational. Geology 36 Data presented on potential overpressure zones Yes Expected max. pressure is 9.8 ppg EMW; will be drilled using 9.2 -9.6 ppg mud and managed Appr Date 37 Seismic analysis of shallow gas zones NA pressure drilling to keep equivalent circulating density between 10.5 and 12.5 ppg as required. SFD 12/1/2009 38 Seabed condition survey (if off-shore) NA No shallow gas or hydrates expected at this development location. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Co missioner:, Date Commissioner Date ' /2 -Az • Well History File APPEND I nfoi mation 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. 1 HALLI BU RTO Sperry C�rilllrr R' Drilling I I END OF WELL REPORT 1 ODSK -14 Oooguruk Development I I I - A 1 4 ���f: .s — .. l i Surface Data Logging Services I I 1 0 06'6 HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1 1. General Information 1 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 I End of Well Report in PDF format ADI Backup 1 1 1 HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION 1 Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSK -14 ODSK -14 PB1 1 ODSK -14 PB2 Field: Oooguruk 1 Borough: North Slope Borough State: Alaska Country: United States API Number: 50- 703 - 20610 -00 1 Sperry Job Number: AK -AM- 6852353 Job Start Date: 02 Feb 2010 1 Spud Date: 01- Nov -2009 Total Depth: Production Section to 13,582' MD, 6,166TVD 1 North Reference: True Declination: 21.782° 1 Dip Angle: 80.901° Total Field Strength: 57648 nT 1 Date Of Magnetic Data: 10 Jan 2010 Wellhead Coordinates N: North 70° 29' 45.45" 1 Wellhead Coordinates W: West 150° 14' 47.80" Drill Floor Elevation 56.20' 1 Ground Elevation: 13.5 Permanent Datum: Mean Sea Level 1 SDL Engineers: Dan Sherwood, Colby Marks, Mark Lindloff SDL Sample Catchers: Herman Lilgreen, Josh Beckham, Chris Woolley 1 Company Geologist: Jim Stewart, Mindaugas Kuzminskas Company Representatives: Joe Polya Rod Klepzig, Joey Cortez, Jim ' Brown SSDS Unit Number: 123 1 1 HALLIBURTON I Sperry Drilling DAILY SUMMARY ODSK -14 02/11/2010 All SDL personnel arrive on location, new crew were oriented accordingly and given necessary safety briefings. SDL equipment had been previously rigged up prior to arrival of new personnel. Circulate at 7,781' while replacing electric motor on MPD HPU. RIH on elevators from 7,781' to 10,344', ream from 10,344' to 10,390'. Circulate 50 bbls 12 ppg hi vis sweep around and RIH and tag bottom. POOH to 10,390' and weight up to 12.5 ppg. Ream from 10,344' to 10,390' Circulate 50 bbls12.0 ppg hi -vis sweep. Uninstall RCD bearing © base of HRZ 5,985' MD. Weight up fluid system from 12.8 ppg — 13.0 ppg. 02/12/2010 Circulate 13 ppg w/ good returns to surface, spot 70 bbls from 10,390' to 10,139' POOH from 10,390' to 7,781' w tight spots @ 10,105', 9,936', 9,734' and 9,650' Pump slug and POOH to ' surface. Lay down BHA and download MWD data. Install 7" pipe rams and test. Sperry recorded a 10.89 bbl loss while POOH. ' 02/13/2010 Test BOP's R/U casing running equipment, RIH with 74 joints of 7" casing. Fill pipe with fill up tool and M/U circulate swedge and establish circulation w % bbl and clear auto fill float shoe. Stage pumps to 1 bpm in 1/2 bbl increments and shut down pumps. Continue to RIH with 7" casing of 9349'. Sperry observed a 28.9 bbl gain over calculated displacement due to auto fill floats sticking. 02/14/2010 Continue to RIH with 7" casing from 9349' to 10,351'. Worked pipe over edges @ 9,901', 10,255', 10,280', 10,312' and 10,320'. Filling pipe every 3 joints due to auto fill shoe blockage. ' Total observed displacement was 77.79 bbls over calculated. While filling pipe a total of 73.04 bbls was observed. With a surplus of 4.75 bbls over calculated metal displacement. Land hanger on seat and rig down Franks Fill Up Tool and rig up cement head and lines. Establish circulate with 11 ppg mud displacing 13 ppg @ % bbls. Utilize step rate method increasing in 1 /4 bbl increments until 3 bbls per min was achieved. Sperry observed a 1.36 bbl loss under calculated volume pumped while displacing. Max gas while displacing was 2,388 units with back ground gas of 375 units. Conduct cement job pumping 20 bbls 15.8 ppg cement and displace ' 11 ppg fluid with full returns throughout displacement. Rig down cement head and lines. Test 7" pack off seals, install mouse hole and lay down 54 joints of 5" drill pipe. ' 02/15/2010 Replace 4" BOP's, Lay down 130 joints of 5" drill pipe and 12 joints of HWDP. Remove mouse hole and lay down 128 joints of 5" DP. Change pipe rams, test BOP's. Slip and cut DL, and P/U 4" drill pipe. 02/16/2010 1 Pick up 4" drill pipe. Test BOPs. TIH with 4" drill pipe and circulate. Stand back drill pipe. 1 1 HALLIBURTON I Sperry Drilling 02/17/2010 ' Pick up new BHA and RIH with same. Perform shallow pulse test with MWD tools. Drill cement shoe track and ahead to 10385' and displace 11 ppg mud with new 8.9 ppg mud. Install RCD bearing. Finish drilling cement and 10' of new formation. Perform formation integrity test. Drill ' ahead to 10513' and perform formation pressure test to 8.79 EMW. Max gas for the past 24 hr was 3278 units, with an average of 1120 units, varying depending upon ROP. Observed losses for 24 hrs period was 24 bbls. ' 02/18/2010 Drilled to 11,207'. MWD not functioning normally. POOH to 10095' and pump 25bb1 spacer. Pull 7 more stands to 9595' and displace with 10.2ppg kill mud. POOH at report time. Max gas for the past 24 hrs was 1722 units. Total losses were 251 bbls. 02/19/2010 ' Continue to POOH to surface and lay down BHA. Pick up new BHA and test MWD tools. RIH to shoe and install RCD bearing. Displace 10.2 kill weight brine with 8.6 drilling fluid. Continue RIH. 02/20/2010 Conduct MADD Pass from casing shoe to 11,185'. Washed and reamed tight hole from 11,185 to 11,207 ft. Drilled to 11,574'. Nothing but shale coming over the shakers. No connection gas or trip gas was noted. Decision was made to pull back to 10726' and side track. Time drilling at report time @ 10729'. 02/21/2010 Washed and reamed from 10,706' to 10,726'. Sidetracked and time drilled to 10,746'. Down hole losses at 45 bbls /hr. Pumped 45 bbl LCM pill with losses reduced to 20 bbls /hr. Noticed pressure loss at 10,745'. Turned off rotary, pressure came back up 200 psi. Trip to casing 1 shoe to troubleshoot pressure drop. No visible damage found. RIH circulating each stand down. At 10715' MWD signal dropped, and a 370 psi loss in SPP was observed. POOH to shoe. 02/22/2010 POOH, displaced above spacer with 10.2 ppg brine. Rig down RCD Head. POOH, found washout in the Jars. Lay down BHA. Start Picking up new BHA. 42 bbl difference between calculated and observed displacement while POOH. 02/23/2010 RIH with BHA 16 to 10, 315. Rig up RCD head, Displace 10.2 for 8.7 ppg, Continue to RIH to 10746'. Time drilled 2 ft/hr to 10,751'. Currently drilling ahead at report time. Samples show good staining and good fluorescence. Most mud losses are over the shakers 360 bbls, 36 bbls down hole. 02/24/2010 ' Drill ahead to 11,340'. Conduct MADD pass after sliding. Back reamed from 11,340' to 11,280'. Waited for evaluation of situation, decided to continue to drill ahead to 11,600'. Service top drive and continue to drill ahead. Samples show good staining and good fluorescence. At 11255', samples turned shaley then returned to good sand at 11450'. Most mud losses are over the ' shakers 480 bbls, 200 bbls down hole. 1 HALLIBURTON I Sperry Drilling 02/25/2010 Drill from 11,600' to 11,955', making MADD passes after slides and taking surveys every 30', continue drilling to 12956' MADD passing and taking 50' surveys. Most mud losses are over the shakers 480 bbls, 54 bbls down hole. 1 02/26/2010 Drilling ahead, drilled out of sands and into shale trying to get back in sands. Drilling slow. Gas ' minimal. Most mud losses are over the shakers 480 bbls, 54 bbls down hole. 02/27/2010 Drilled to 13488'. Revised plan to drill to 13844'. Drill ahead picking up singles. Samples turning ' sandy, fluorescence weak, gas has picked up but not to the levels of the previous sands. 24 hr mud loss 86 bbls, seepage of 3.6 bbl /hr average. ' 02/28/2010 Drilled to TD - 13582' MD. Circulate bottoms up 2x. Short trip to casing shoe. Short trip out displacement showed 8.2 bbls lost to hole. 24 hr mud loss of 78 bbls equals seepage of 3.3 ' bbls per hour to hole. Trip back in the hole from the shoe. Short trip went well. 03/01/2010 Short Tripped to inside casing shoe at 10315'. Hole took 8.2 bbls POOH. Ran to bottom. Hole took 8.6 bbls. Circulated Hi Vis sweep and circulated hole clean. POOH to inside casing shoe at 10095'. Pumped 25 bbl Hi Vis spacer and displaced drill pipe with 10.1 ppg kill mud. POOH to 9543'. Displace well with 10.1 ppg mud. POOH and Lay down MWD. Test BOPs. Losses from trip out, 47 bbls. Most mud losses for last 24 hrs, 69 bbls down hole. Hole seepage ' equals 2.9 bbls /hr. Both sample catchers and one mudlogger depart Island. 1 1 1 1 1 1 1 1 I Customer: Pioneer Natural Res. Report #: 1 _ HALLJBURTON Well: ODSK -14 Date: 2/12/2010 -04:00 I Area: Oooguruk 04:00 Depth 10400' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH w Casing Job No.: AK -AM- 0006852353 Report For: J. Polya /R. Klepzig 1 Daily Charges $5,572.27 Total Charges: 46.769.69 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 - R.O.P. ft/hr SO =- Flow In • .m 0 SPP •si NA Gas (units) -- Flow In (spm) 0 Gallons /stroke 3.5175 Hole Condition De.th On Bot Hrs Ann Corr Av. Diam PWD All Drillin• Circ _ Min _ Av. _ Max _ Min _ Avg _ Max ii • Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out sec/•t • •b E• cP Ib /100ft m1/30min m. /I 10400' 13.00 13.00 62 9.0 29 31 7.4 8.90 20K 20.6 ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff (current) Gas Breakdown I H2S Data 1 Sample Line 'Max: Avg: I Ambient Air Pit Room Max: !Avg: I I Gas (units) Chromatograph (ppm) to to I to to to I to to to to 1 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: I tz �L.. „ Increased MW to 13.0 ppg using sack Barite on rig and bulk Barite at RCS. Pumped 18 bbls (70 ppb) LCM pill and spotted on well bottom. Pulled up to shoe, slug pipe and POOH for 7" casing run. L/D BHA. Tested BOPs. 1 I Nil 111 '. Logging Engineer: Dan Sherwood /Runnoe Connally * 10000 units = 100% Gas In Air ill 1 1 1 A, Customer: Pioneer Natural Res. Report #: 2 NAL.LIBURTON Well: ODSK -14 Date: 2/13/2010 -04:00 Area: Oooguruk 04:00 Depth 10400' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: TIH w/casing Job No.: AK -AM- 0006852353 Report For: J. Polya /R. Klepzig I Daily Charges $5,572.27 Total Charges: $52,341.96 `1. ROP & Gas Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 R.O.P. ft/hr -- Flow In • •m 0 SPP .si NA Gas (units) Flow In (spm) 0 Gallons /stroke Hole Condition De•th On Bot Hrs Ann Corr Av. Diam PWD Drillin• Min Av. - -- All Circ Min Avg Max Mud Data Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids y De•th ft in out (sec/.t) ••b E• cP Ib /100ft ml /30min m. /I % 1 k' 10400' 13.00 13.00 56 9.0 20 24 6.0 9.30 20K 19.6 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 1 Gas Breakdown I H2S Data 1 Sample Line Max: Avg: 1 Ambient Air Pit Room Max: lAvg: 1 ' Gas (units) Chromatograph (ppm) Depth to to I to to t i ' 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... I 24 hr Recap. Rig up and run 7" casing. Verify every 5th stand. Monitor mud gains in Trip Tanks. Monitor mud loss when pumping. Watch for any trends with mud. Monitor mud transfers between pits. Gas trap air line backflushed. 1 1 1 Logging Engineer: Dan Sherwood /Runnoe Connally * 10000 units = 100% Gas In Air �4 f ' 1 1 1 1 61111°2"v149W.74:17. ir ' jilt' t Cu;t::: ' Pioneer Natural Res. ''''' ' Re 4 pOrt;: 1 3 l'I' ' IALLJBURTON Well: ODSK-14 Date: 2/14/2010-04:00 I Area: Oooguruk ' Sperry Drilling Services Location: Rig: Nabors 19AC 04:00 Depth Progress 24 hrs: 0' 9 10400 North Slope Pro ' Rig Activity: Cementing Job No.: AK-AM-0006852353 Report For: J. Polya/R. Klepzig ;-, I Daily Charges $4,209.87 Total Charges: $56,551.83 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. ft/hr Flow In • •m 0 SPP .si NA Gas (units) 0 NA 2338 BU Flow In (spm) 0 Gallons/stroke 3.5175 Hole Condi Depth On Bot Hrs Ann Corr Av• Diam PWD Drillin. Min Av. Max u ........ I All Circ Min III. Avg Mil Max - '-i Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out (sec/.t) ..b E. cP (Ib/100ft m1/30min m./I % I 10400 11.00 11.00 50 5.0 13 26 7.8 9.00 20K 12.5 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I I (current) Gas Breakdown 1 H2S Data 1 Sample Line 'Max: Avg: I Ambient Air Pit Room !Max: lAvg: I I Depth Gas (units) Chromatograph (ppm) to _ to _ I to to _ to to to - to - to - II Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; VVTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation... ; E-- - Early... I 24 hr Recap: Ran 7' casing to 10,495. Circulated slowly and reduced MW to 11.0 ppg. Highest MW at FL was 13.6 ppg on BU. Increased flow rate to 6 bbl/min. Pumped 20 bbls cmt. Chased cement w 11.0 ppg mud. Max gas 2338 Units. 1 1 1 . , Logging Engineer: Dan Sherwood/Runnoe Connally * 10000 units = 100% Gas In Air 1 ''' _: 47. - , *-'4' ..-- Ikr..• ailialliftWAINVIMIIIIMININIKVOMMOMPINSWMMINIMANNIMMIS 1 1 A, Customer: Pioneer Natural Res. Report #: 4 HALLIBURTON Well: ODSK -14 Date: 2/15/2010 -04:00 Area: Oooguruk 04:00 Depth 10400' I Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK -AM- 0006852353 Report For: J. Polya /R. Klepzig I Daily Charges $4,209.87 Total Charges: $60,761.70 .', '... .. -_ . .. X tt. w x . ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I 1 R.O.P. (ft/hr) Flow In (gpm) 0 SPP (psi) NA Gas (units) 0 NA 0 NA Flow In (spm) 0 Gallons /stroke 3.5175 Hole Condition De On Bot Hrs Ann Corr Avg Diam pwD Drilling Min Avg Max All Circ Min _ Avg Max I Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft m1/30min mg /I % I 10400' 11.00 11.00 47 5.0 13 25 8.0 9.00 20K 12.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ", Gas Breakdown I H2S Data 1 Sample Line 'Max: Avg: I Ambient Air Pit Room Max: 'Avg: I I Gas (units) Chromatograph (ppm) Depth to to I to to to to to to to I 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... 1 I 24 hr Recap: L/D 5" drill pipe. Tested BOP. Slipped and cut drill line. P/U 4" drill pipe. l 1 1 1 Logging Engineer: Dan Sherwood /Runnoe Connally * 10000 units = 100% Gas In Air I 1 ■ Customer: Pioneer Natural Res. Report #: 5 HALLIBURTON Well: ODSK -14 Date: 2/16/2010 -04:00 I Area: Oooguruk 04:00 Depth 10400' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK -AM- 0006852353 Report For: J. Polya /R. Klepzig Daily Charges $5,572.27 Total Charges: $66,333.97 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I , R.O.P. ft/hr - - -- Flow In • •m 0 SPP .si NA Gas (units) 0 1 6 NA Flow In (spm) 0 Gallons /stroke 3.5175 Death On Bot Hrs Ann Corr Av• Diam PWD Drillin• _ Min _ Av. _ Max - ' 4 Hole Condition - - -- All Circ _ Min _ Avg _ Max ■ . .., Mud Data: ataf Density (p ogt (sec/ t •Mb E. PV (Ib /1 Oft ml /gl0mi'n pH Chlorides Cor Solids I 10400' 11.00 11.00 47 5.0 11 19 9.0 11.10 20K 12.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition MI NM Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) ®_ ®--- _ Milli -IIIIIMI-IIIIIIIII Gas Breakdown I H2S Data 1 Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: I Gas (units) Chromatograph (ppm) Depth to to to to to to ■ to to to I 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: P/U 4" drill pipe. Test BOPs. TIH with 4" drill pipe and circulate. Stand back drill pipe. ir ■ ■ Logging Engineer: Dan Sherwood /Runnoe Connally * 10000 units = 100% Gas In Air ■ 1 1 Customer: Pioneer Natural Res. Report #: 5 HALLieuRTDN Well: ODSK -14 Date: 2/17/2010 Area: Oooguruk 04:00 Depth 10400' I Location: North Slope Progress 24 hrs: 269' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J. Polya /R. Klepzig PA Daily Charges $5,572.27 Total Charges: $68,534.37 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I • R.O.P. (ft/hr) 0.0 76.8 202.0 10464' Flow In (gpm) 0 SPP (psi) NA Gas (units) 371 1120 3278 10457' Flow In (spm) 0 Gallons /stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max 13" I All Circ Min Avg 3.54 N/A 6. Max I q Mud Data: D ens it y (ppg) Viscosit MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft m1/30min mg /I % 10505' 8.70 8.70 41 2.0 7 16 5.0 9.40 21K 1.3 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 Security DBS PDC 6.125 0.389 10400' Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 100 Gas Breakdown I H2S Data 1 Sample Line Max: IAvg: l Ambient Air Pit Room IMax: Avg: I I Gas (units) Chromatograph (ppm) Depth 10,400 to 10,457 3278 1345 279257 16356 7691 3233 1067 GP 10,457 to 10,550 1924 1050 161358 10895 5248 2526 1014 GP 1 to to to to III 1 to to to 1 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... I 24 hr Recap: P/U new BHA and RIH with same. Perform shallow pulse test with MWD tools. Drill cement shoe track and ahead to 10385' and displace 11 ppg mud with new 8.9 ppg mud. Install RCD bearing. Finish drilling cement and 10' of new formation. Perform formation integrity test. Drill ahead to 10513' and perfom formation pressure test to 8.79 EMW. Currently drilling ahead I at time of report. Max gas for the past 24 hr was 3278 units, with and average of 1120 units, varying depending upon ROP. Observed losses for the past 24 hrs was 24 bbls. 1 1 Lgineer: Dan Sherwood /Colby Marks * 10000 units = 100% Gas In Air 1 1 1 Customer: Pioneer Natural Res. Report #: 7 HALLIBURTON Well: ODSK -14 Date: 2/18/2010 1 Area: Oooguruk 04:00 Depth 11208' 4 Location: North Slope Progress 24 hrs: 559' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis Daily Charges $5,572.27 Total Charges: $74,106.64 I ROP Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I ; x R.O.P. ft/hr 0.0 133.4 275.2 1106' Flow In • •m 0 SPP .si NA Gas (units) 0 525 1722 10694' Flow In (spm) 0 Gallons /stroke 3.5175 Hole Condition Death On Bot Hrs Ann Corr Av. Diam PW Drillin• 9.62 Min 10.07 Ave 11.71 Max 11208' 13.5 11 bbls 6.13" All Circ 9.62 Min 10.07 Avg 11.71 Max Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides CorSolids Death ft in out (sec/.t) • •b E. cP (Ib /100ft ml /30min m. /I % I it 11207' 8.70 8.70 38 2.0 6 14 5.3 8.70 21K 1.9 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 Securit DBS PDC 6.125 0.389 - 10400' -- I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 I - - -- -_ - - -, Gas Breakdown I H2S Data 1 Sample Line Max: Avg: I Ambient Air Pit Room Max: !Avg: I I Gas (units) Chromatograph (ppm) Depth 10,614 to 10,629 1510 1048 135330 7698 3414 1592 711 10,678 to 10,706 1722 1433 144710 9801 4601 2057 908 1 10,719 to 10,761 1610 1090 137520 9404 4564 2080 890 10,807 to 10,809 925 529 191698 8026 3340 1285 472 10,810 to 10,860 422 200 196839 8347 3505 1363 501 11,101 to 11,153 930 643 71717 5924 3272 1695 867 1 to to to 1 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... I 24 hr Recap: Drilled to 1,207'. MWD failure. POOH to 10095' and pump 25bb1 spacer. Pull 7 more stands to 9595' and displace with 10.2ppg kill mud. POOH at report time. Max gas for the past 24 hrs was 1722 units. Total losses were 251 bbls. I 1 Logging Engineer: Dan Sherwood /Colby Marks * 10000 units = 100% Gas In Air I igo: ''''*' 1 1 Customer: Pioneer Natural Res. Report #: 8 ' HALLIBURTON Well: ODSK -14 Date: 2/19/2010 Area: Oooguruk 04:00 Depth 11208' Location: North Slope Progress 24 hrs: Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis I 1 Daily Charges $6,410.67 Total Charges: $88,937.45 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) Flow In (gpm) 0 SPP (psi) NA Gas (units) 2 Flow In (spm) 0 Gallons /stroke 3.5175 Dep B1ot s Ann Corr Av am 9... Hole Condition PWD I ; 11208th ' On 13 Hr 11 bbls 6.13 All Circ Drilling 9.62 62 Min Min 10 07 Avg Avg 11 71 M ax M ax '1' . 'x '- Mud Data: Density (ppg) Viscosity MBT PV YP pH Chlorides Cor Solids Depth ft in out (seGgt) (ppb Eq) cP (Ib /100ft ml /30min API Filt mg /I % ' 8.70 8 70 38 2.0 6 14 5.3 8.70 21K 1.9 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 Security DBS PDC 6.125 0.389 13.53 10400' 11207' 807' 1- 6- BT- N- X- I- LT -DTF I Security DBS PDC 6.125 0.389 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) Gas Breakdown 1 H2S Data 1 Sample Line Max: 'Avg: l Ambient Air Pit Room Max: !Avg: 1 I Gas (units) Chromatograph (ppm) to to I to to to I to to to to 1 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... I 24 hr Recap: Cont to POOH to surface L/D BHA and P/U new BHA, test MWD tools. RIH to shoe and install RCD bearing. Displace 10.2 kill weight brine with 8.6 drilling fluid. Continue RIH at report time. 1 s , 1 4 i Logging Engineer: Dan Sherwood /Colby Marks * 10000 units = 100% Gas In Air I 1 1 Customer: Pioneer Natural Res. , Report #: 9 HALLIBURTON Well: ODSK -14 Date: 2/20/2010 Area: Oooguruk 04:00 Depth 10728' III li Location: North Slope Progress 24 hrs: 367' .w 47, Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis I Daily Charges $6,410.67 Total Charges: $95,348.12 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 1.0 55.0 129.0 11385' Flow In (gpm) 0 I SPP (psi) 2178 Gas (units) 11 91 167 11444' Flow In (spm) 70 Gallons /stroke 3.5175 Depth 10726 On Bot 11 Hrs 11 9 Corr Avg 13" PWD All Diam Drilling 10.541 I M in 11.07 I Avg 11.64 I Max Hole Condition Circ 10.35 Min 10.98 Avg 11.69 Max Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib /100ft m1/30min mg /I % 1 8.80 8.80 40 3.0 8 17 4.4 9.30 30k 1.9 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 Security DBS PDC 6.125 0.389 13.53 10400' 11207' 807' 1- 6- BT- N- X- I- LT -DTF Security DBS PDC 6.125 0.389 I I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 5 95 Gas Breakdown H2S Data 1 Sample Line Max: !Avg: 1 Ambient Air Pit Room jMax: !Avg: 1 I Gas (units) Chromatograph (ppm) to I to to to to ;i to to to to I 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 x ue .s% . �k, ��_ � r �� hr Recap: Conduct MADD Pass from casing shoe to 11,185, MD, Washed and reamed tight hole from 11,185 to 11,207 ft. Drilled to 11,574' md, Nothing but shalecoming over the shakers. No connection gas or trip gas was noted. Decision was made to pull back to 10726' and side track. Time drillingat report time. 10729'. 1 I Logging Engineer: Mark Lindloff /Colby Marks * 10000 units = 100% Gas In Air 1 1 1 Customer: Pioneer Natural Res. Report #: 10 HALLIBURTON Well: ODSK -14 Date: 2/21/2010 Area: Oooguruk 04:00 Depth 10728' I Location: North Slope Progress 24 hrs: 18" Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis Daily Charges $5,572.27 Total Charges: $100,920.37 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 0.0 0.8 2.9 10741' Flow In (gpm) 0 SPP (psi) 1867 Gas (units) 7 10 57 10745' Flow In (spm) 70 Gallons /stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Av i g D a m PWD Drilling 9.94 Min 10.50 Avg 10.58 Max 10746' 17.58 11 bbls 6.13" All Circ 9.55 Min 10.39 Avg 10.58 Max II Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft m1/30min mg /I % 8.70 8.70 40 2.0 8 17 3.9 9.30 27k 1.6 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 Security DBS PDC 6.125 0.389 13.53 10400' 11207' 807' 1- 6- BT- N- X- I- LT -DTF I Security DBS PDC 6.125 0.389 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GVI Tuff I I (current) 5 95 Gas Breakdown I H2S Data 1 Sample Line 'Max: IAY9 1 Ambient Air Pit Room Max: Avg: I Gas (units) Chromatograph (ppm) Depth to to I to to to to I #' 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... I 24 hr Recap: Pumped 45 bbl LCM pill, Losses reduced to 20 bbls /hr. Noticed pressure loss at 10,745 ft. Turned off rotary, psi came back up 200 psi. Trip to casing shoe to troubleshoot pressure drop. I No visible damage found. RIH circulating each stand down. At 10715 MWD signal dropped, and a 370 psi loss in SPP was observed. Currently POH to shoe. 1 Logging Engineer: Mark Lindloff /Colby Marks * 10000 units = 100% Gas In Air 1 1 Customer: Pioneer Natural Res. Report #: 11 .: .i ALLIBURTON Well: ODSK -14 Date: 2/22/2010 I f s Area: Oooguruk 04:00 Depth 10728' Location: North Slope Progress 24 hrs: 0' =KK Sperry Drilling Services Rig: Nabors 19AC Rig Activity: P/U BHA 9 Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis 'r Daily Charges $5,572.27 Total Charges: $106,492.64 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In • •m 0 SPP •si 0 Gas (units) 0 0 0 0' Flow In (spm) 0 Gallons /stroke 3.5175 Hole Condition Death On Bot Hrs Ann Corr Av. Diam PWD Drillin• 0.00 Min 0.00 Ave 0.00 Max 10746' 17.58 11 bbls 6.13" All Circ 9.00 Min 9.00 Avg 9.00 Max . Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Death ft in out sec/•t • •b E. cP (Ib /100ft m1/30min m•/I 1 10746' 8.70 8.70 42 2.0 7 14 5.2 9.60 26k 1.6 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB = Condition 8 Securit DBS PDC 6.125 0.389 16.38 10726' 10743' 17' I EMI Security DBS PDC 6.125 0.389 - -_ - -- Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I I (current) 5 95 Gas Breakdown 1 H2S Data 1 Sample Line Max: Avg: I Ambient Air Pit Room 'Max: Avg: J I Gas (units) Chromatograph (ppm) Depth to to to 1 t� to 1 to to to to 1 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... I 24 hr Recap: POOH, Displaced above spacer with 10.2 ppg brine. Rig down RCD Head. POOH, found washout in the Jars. Laydown BHA, Start Picking up new BHA. -42 bbl difference between calculated and observed displacement while POOH.A0150 1 111 II Logging Engineer: Mark Lindloff /Colby Marks 10000 units = 100% Gas In Air 1 1 1 Customer: Pioneer Natural Res. Report #: 12 "iALLIBURTON Well: ODSK -14 Date: 2/23/2010 Area: Oooguruk 04:00 Depth 11079' I Location: North Slope Progress 24 hrs: 351' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis Daily Charges $5,572.27 Total Charges: $112,064.91 L. ROP & G as: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: (ft/hr) 92.0 100.0 257.0 11072' Flow In (gpm) 70 SPP (psi) 1937 R.O.P. O Gas (units) 240 895 2819 10813' Flow In (spm) 250 Gallons /stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.90 Min 10.03 Avg 10.14 Max 11079' 6.7 11 bbls 6.13" All Circ 8.70 Min 10.05 Avg 10.64 Max a. Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib /100ft m1/30min mg /I % 1 8.70 8.70 40 1.5 7 16 5.1 9.60 26k 1.6 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' I Security DBS PDC 6.125 0.389 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff I (current) 100 0 Gas Breakdown 1 H2S Data I Sample Line !Max: IAvg: I Ambient Air Pit Room !Max: 'Avg: I Gas (units) Chromatograph (ppm) Depth 10,829 to 10,855 1506 1131 152303 9962 5000 2097 845 GP 10,970 to 10,987 1416 1856 148015 10373 5433 2430 1000 GP I 11,028 to 11,052 1451 2051 180937 11450 5325 2162 878 GP to to I to to to to II 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... I 24 hr Recap: RIH with BHA 16 to 10, 315. Rig up RCD head, Displace 10.2 for 8.7 ppg, Continue to RIH to 10746 Time drilled 2 ft/hr to 10,751 ft. Currently drilling ahead at report time. Samples show good staining and good flouresence. 1 Most mud losses are over the shakers 360 bbls, 36 bbls down hole. 1 ala Logging Engineer: Mark Lindloff /Colby Marks * 10000 units = 100% Gas In Air 1 ,i;"17,*''''', 1 1 ' Customer: Pioneer Natural Res. Report #: 13 4ALLIBURTON Well: ODSK -14 Date: 2/24/2010 Area: Oooguruk 04:00 Depth 11747' I Location: North Slope Progress 24 hrs: 668' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis I Daily Charges $5,572.27 Total Charges: $117,637.18 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 92.0 81.2 467.0 11539' Flow In (gpm) 70 SPP (psi) 1842 Gas (units) 802 518 2211 11244' Flow In (spm) 250 Gallons /stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.98 Min 10.08 Avg 10.20 Max Hole Condition 11079' 17.27 11 bbls 6.13" PWD All Circ 9.84 Min 10.09 Avg 10.37 Max Mud Da Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib /100ft m1/30min mg /I % I 8.70 8.70 40 2.5 7 15 5.0 9.20 28k 1.5 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 J Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' ' Security DBS PDC 6.125 0.389 I I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 5 Gas Breakdown H2S Data l Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: I Gas (units) Chromatograph (ppm) 11,185 to 11,257 1600 2190 175008 12357 6047 2490 1059 GP 11,519 to 11,574 851 1982 149476 11361 6334 2993 1094 GP 1 to to to I to to '` to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ; 't POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip... ; F -- - Formation...; E -- - Early.. 24 hr Recap: Drilling ahead to 11,340 ft. Cunduct MADD Pass after sliding, Back Reamed from 11,340 ft to 11,280 ft., Waited for evaluation of situation, decided to continue to drill ahead to 11,600 ft. Service top drive and continue to drill ahead Samples show good staining and good flouresence. 11255' samples turned shaley then returned to good sand at 11450 ft I Most mud losses are over the shakers 480 bbls, 200 bbls down hole. ',„ 1 1 Logging Engineer: Mark Lindloff /Col Marks * 10000 units = 100% Gas In Air .„..,..........„„„„............:......,„,„,...„...,.,, I 11 1 Customer: Pioneer Natural Res. Report #: 14 HALLIBURTON Well: ODSK -14 Date: 2/25/2010 Area: Oooguruk 04:00 Depth 12508' I Location: North Slope Progress 24 hrs: 759' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ S Lewis 1 Daily Charges $6,410.67 Total Charges: $117,637.18 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 .4, R.O.P. (ft/hr) 56.0 87.5 406.0 11539' Flow In (gpm) 70 SPP (psi) 2195 '' Gas (units) 1748 812 2149 11244' Flow In (spm) 250 Gallons /stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.96 Min 10.13 Avg 13.25 Max Hole Condition 12596' 28.34 46 bbls 7.50" All Circ 9.62 Min 10.14 Avg 13.25 Max Mud Data: ' Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec,/qt) (ppb Eq) cP (Ib/100ft m1/30min mg /I % 8.80 8.80 39 2.5 8 18 4.6 9.10 27k 1.5 I BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' I Security DBS PDC 6.125 0.389 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 90 5 Gas Breakdown 1 H2S Data 1 Sample Line Max: 'Avg: ( Ambient Air Pit Room 'Max: 'Avg: I Gas (units) Chromatograph (ppm) Depth 12,400 to 12,440 2149 1427 176023 11421 5515 2533 1015 GP 12,438 to 12,484 851 1982 117019 8032 4136 1996 837 GP 1 to to to I to to to to 1 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: Drill from 11,600 to 11,955', making MADD Passes after slides and taking surveys every 30', continue drilling to 12956' MADD Passing and taking 50' surveys. Most mud losses are over the shakers 480 bbls, 54 bbls down hole. • Increase in cost for extra man (Tom Mansfield) 1 1 Logging Engineer: Mark Lindloff /Tom Mansfield * 10000 units = 100% Gas In Air iiatinnESSIONEM .120/10.ingikiiig*MalnitUNIENIMMIIMINIIIIMILI.,;.„.. :'27, ,,.%;.-.. „. �. 1 1 If I Customer: Pioneer Natural Res. Report #: 15 HALLIBURTON Well: ODSK-14 Date: 2/26/2010 Area: Oooguruk 04:00 Depth 12952' ., Location: North Slope Progress 24 hrs: 444' I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling F,...' Job No.: AK-AM-0006852353 Report For: J Brown/ R, Klepzig 1 Daily Charges $5,572.27 Total Charges: $123,209.45 R:11flirti :4metkiwAsizi' , ,,,,.,::,,,,,, , i , •=0. - ..1. , ...,. , :- ...._ & G as: Ktir at u Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 79.0 54.0 141.0 11539 Flow In (gpm) 70 SPP (psi) 2195 Gas (units) 53 427 3944 12577' Flow In (spm) 250 Gallons/stroke 3.5175 1 D 2 e 5 p 9 t 6 h , On 3 B 8 o 5 t 3 H r s A5n8n bbls Co r r Avg 5 D 0 i a m PWD All i I irilrgc 9.83 Min n M 1 1 0 0 , 1 A A v v g g 1 1 0 0,4 48 6 M M a a x x Hole Condition I Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft m1/30min mg/I % 12340' 8.75 8.75 40 I ---.--- - - 2.0 10 19 4.4 9.30 26K 1.8 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' I i Security DBS PDC 6.125 0.389 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 25 35 40 Gas Breakdown • 1 H2S Data I Sample Line 'Max: Avg: I Ambient Air Pit Room !Max: 'Avg: I 111 IL* , Depth Gas (units) Chromatograph (ppm) '' 12,546 to 12,584 3950 1225 325365 21885 10754 4737 1665 GP I _ to to to _ to - I to to - to to 1 ' Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; VVTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip... ; F-- - Formation...; E-- - Early... I 24 hr Recap: Drilling ahead, Drilled out of sands and into shale trying to get back in sands. Drilling slow. Gas minimal. I Most mud losses are over the shakers 480 bbls, 54 bbls down hole. 1 :-. 1 '',. I Logging Engineer: Mark Lindloff/Tom Mansfield * 10000 units = 100% Gas In Air 1 1 Customer: Pi Natural Res. Re #: 16 HALLIBURTON Well: ODSK -14 Date: 2/27/2010 Area: Oooguruk 04:00 Depth 13577' Location: North Slope Progress 24 hrs: 625' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0006852353 Report For: J Brown/ R, Klepzig Daily Charges $5,572.27 Total Charges: $128,781.72 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 58.0 67.0 139.0 13545' Flow In (gpm) 70 SPP (psi) 2264 Gas (units) 237 267 1743 13527' Flow In (spm) 250 Gallons /stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.93 Min 10.18 Avg 10.37 Max Hole Condition 13577 49 63 bbls 7.138.1a 6" PWD All CirC 9.93 Min 10.18 Avg 10.41 Max '. Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib /100ft m1/30min mg /I % I 8.80 8.80 38 2.5 6 17 4.4 9.30 24k 2.2 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' I Security DBS PDC 6.125 0.389 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 70 15 15 II Gas Breakdown I H2S Data 1 Sample Line Max: 'Avg: I Ambient Air Pit Room Max: Avg: I I Gas (units) Chromatograph (ppm) Depth 13,404 to 13,436 963 487 83251 4931 2399 1080 416 GP 13,503 to 13,534 1737 644 146285 8118 3966 1694 640 GP I to to to I to I to to to 1 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... I 24 hr Recap: Revised plan to drill to 13844' md. Drilling ahead at report time., Samples turning sandy, fluorescence weak, gas has picked up but not to the levelsof the previous sands. Most mud losses 93 bbls down hole. 1 1 1 Logging Engineer: Mark Lindloff /Tom Mansfield * 10000 units = 100% Gas In Air 1 1 /� Customer: Pioneer Natural Res. Report #: 17 HALLIBURTON Well: ODSK -14 Date: 2/28/2010 I Area: Oooguruk 04:00 Depth 13852' ation: North Slope Progress 24 hrs: 276 perry rng ervces Rig: Nabors 19AC Rig Activity: Short Trip Job No.: AK -AM- 0006852353 Report For: J Brown/ R, Klepzig 1 Daily Charges $5,572.27 Total Charges: $134,353.99 4' 4 4 "- ROP & G as: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: 1 R.O.P. (ft/hr) 0.0 63.0 153.0 13639' Flow In (gpm) 0 SPP (psi) 0 Gas (units) 0 267 1743 13527' Flow In (spm) 0 Gallons /stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.96 Min 10.14 Avg 10.29 Max Hole Condition 12852' 56.89 63 bbls 7.6" PWD All Circ 9.80 Min 10.14 Avg 10.45 Max -. rte ''' s;', • III Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids A Depth ft in out (sec/qt) (ppb Eq) cP (Ib /100ft m1/30min mg /I % 8.70 8.70 38 2.5 8 15 4.0 9.50 32k 0.8 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 8 Security DBS PDC 6.125 0.389 16.38 10726' 10743' 17' Security DBS PDC 6.125 0.389 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I _ (current) 45 15 40 -tip • t.,. i . Gas Breakdown H2S Data i Sample Line Max: 'Avg: 1 Ambient Air Pit Room Max: 'Avg: 1 Gas (units) Chromatograph (ppm) Depth to I to to to 1 to to to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ',1'-: POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T -- - Trip...; F -- - Formation...; E -- - Early... 24 hr Recap: Drilled to 13582, TD. CBU 2x, Currently short tripping Back in the hole from the shoe. I Most mud losses 78 bbls down hole. 1 ! 1 1 !!!, L ogging Engineer: Mark Lindloff/Tom Mansfield * 10000 units = 100% Gas In Air rR 1 Customer: Pioneer Natural Res. Report #: 18 ALLUBUR ON Well: ODSK -14 Date: 3/1/2010 Area: Oooguruk 04:00 Depth 13852' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Test BOPS Job No.: AK -AM- 0006852353 Report For: J Brown/ R, Klepzig I Daily Charges $3,997.97 Total Charges: $138,353.96 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 13852' Flow In (gpm) 0 SPP (psi) 0 Gas (units) 0 22 222 13852' Flow In (spm) 0 _ Gallons /stroke 3.5175 k ` Hole Condition De On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max 12852' 56.8 69 bbls 7.6" All Circ Min Avg Max M D ata: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft m1/30min mg /I % 1 ' ` 10.10 10.10 28 148K 3.6 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition a .; 8 Hughes QD505HX 6.125 0.552 56.80 10746' 13852' 3106' 0- 1- CT- G- X- 1- NO -DSF 1 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GVI Tuff (current) 45 _ 15 40 Gas Breakdown H2S Data 1 Sample Line Max: Avg: 1 Ambient Air Pit Room 'Max: !Avg: I Gas (units) Chromatograph (ppm) Depth to 1 to to to I to to to to I 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... I 24 hr Recap: Short Tripped to inside casing shoe at 10315'. Hole took 8.2 bbls POH. Ran to bottom. Hole took 8.6 bbls. Circulated Hi Vis sweep and circulated hole clean. POOH to inside casing shoe at 10095'. Pumped 25 bbl Hi Vis spacer and displaced drill pipe with 10.1 ppg kill mud. POOH to 9543'. Displace well with 10.1 ppg mud. POOH and UD MWD. Test BOPs. Losses from trip out, 47 bbls. Most mud losses for last 24 hrs, 69 bbls down hole equals seepage of 2.9 bbls /hr. 1 1 Logging Engineer: Tom Mansfield * 10000 units = 100% Gas In Air 1 1 Customer: Pioneer Natural Res. Report #: 19 HALLIBURTON Well: ODSK -14 Date: 3/2/2010 Area: Oooguruk 04:00 Depth 13852' 1 Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Set Liner Job No.: AK -AM- 0006852353 Report For: J Brown/ R, Klepzig Daily Charges $3,947.57 Total Charges: $142,301.53 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 Flow In ..m 500 SPP .si 2610 Gas (units) 0= 30 13852' Flow In (spm) 140 Gallons /stroke 3.5175 Hole Condition Death On Bot Hrs Ann Corr Av. Diam PWD Drilling _ Min Ave _ _ Max 12852' 56.8 69 bbls 7.6" All Circ _ Min _ Avg _ Max Mud Data: Density (ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Death ft in out (sec/•t) • •b E. cP Ib /100ft m1/30min m • /I % 1 10.10 10.10 28 -� - - 148K . 3.6 BHA Run # I Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 8 Hughes QD505HX 6.125 0.552 56.80 10746' 13852' 3106' 0- 1- CT- G- X- 1- NO -DSF i r� Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff f. I (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: ( � Gas (units) Chromatograph (ppm) 1 Depth to to to 1 to to to to 1 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... I . 24 hr Recap: Finish testing BOPs. Picked up 4" DP. RIH w /ith 4.5" completion liner on 4 " DP to 10334' and circulated DP volume. Continue to RIH to 13709 and circulate completion fluid. 1 1 1 Logging Engineer: Tom Mansfield * 10000 units = 100% Gas In Air 1 IIIIIIIIIIIIIIIIIIIIIIIIIMINIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIIIIIIIINIIIIIIIIIIIIIIIINIIIIIIINMIIIIIIIIOII 1-11A11-LIESUF111-C3Fol WELL NAME: ODSK -14 LOCATION: Oooguruk OPERATOR: Pioneer Natural Resources AREA: North Slope =p4seray =lining; MUD CO: Baroid STATE: Alaska RIG: Nabors 19AC SPUD: 9- Jan -10 SPERRY JOB: AK- AM- 6852353 TD: 27- Feb -10 BIT RECORD BHA# SDL Bit # Bit Type Bit Depth Depth Footage Bit TFA AVG WOB RPM SPP FLOW GPM Bit Grade Remarks RUN # Size In Out Hours ROP (max) (max) (max) (max) 1 100 1 MXL -1V 14.50 158 3566 3408 31.20 0.699 109.0 35 80 1850 750 3- 2- BT- M- E- 1 -WT -TD TD Surface 2 200 2 MDSi716LTBPXC 10.63 3566 4246 680 8.28 0.907 82.0 30 60 2200 700 O- O- CT- CS- X- I- NO-DTF POOH for MWD 3 300 2rr MDSi716LTBPXC 10.63 4246 4246 0 0.00 0.907 0.0 0 Q 0 0 O- 0- CT- CS- X -I-NO -DTF POOH for MWD 4 400 2rr2 MDS1716LTBPXC 10.63 4246 6444 2198 23.75 0.907 93.0 35 120 3750 800 1- 1- CT- CS- X- I- NO-DTF POOH for Geo-pilot 5 500 2rr3 MDSi716LTBPXC 10.63 6444 6493 49 3.13 0.907 16.0 30 60 3600 700 1- 1- CT- CS- X -I-NO -DTF POOH for Geo -pilot 6 600 3 MDSi716 10.63 6493 7853 1360 16.89 1.036 81.0 37 90 3800 775 0- 0- NO- A- X- I -NO -TD Cleanout run 7 700 2rr4 MDSi716LTBPXC 10.63 7853 7853 0 0.00 0.537 0.0 0 0 0 0 1- 1- CT- CS- X- I -NO -DTF Reamer Run Sidetrack End of ODSK- 14 -PB1, Pull back to 4660' md. Continue ODSK -14 8 800 3rr1 MDSi716 10.63 4660 7054 2394 0.00 0.537 0.0 0 0 0 0 O- O- NO- A- X- I- NO-DTF 9 900 3rr2 MDSi716 10.63 7054 7863 809 9.56 1.036 85.0 40 90 3750 775 0- 1- CT- G- X- I -NO-TD TD for 9 5/8 casing 11 1000 4 FSF -2463 8.50 9341 9645 304 3.79 0.877 80.0 18 75 3550 650 1- 0- CT- C-X -I -NO -DTF POOH for MWD 12 1100 5 FSF -2463 8.50 9645 10400 755 14.64 0.887 52.0 23 125 3775 600 3- 6- BT- NT- X- I -ER -TD TD 7" Casing point 14 1200 6 FMFX6412 6.13 10400 11207 807 13.53 0.389 59.5 30 100 2200 255 1- 6- BT- N- X -I -LT -DTF 15 1300 7 FMF3641Z 6.13 11207 11574 367 16.40 0.389 22.4 30 82 2180 249 Pulled Back to Side Track End of ODSK- 14 -PB2, Pull back to 10426' md, Continue ODSK -14 15A 1400 7 FMF3641Z 6.13 10726 10746 20 0.00 0.389 0.0 0 0 0 0 0- 1- CT- G- X- I- NO -DSF POOH for Washout 16 1500 8 QD 50 5HX 6.13 10746 13852 3106 56.80 0.389 77.2 7 so 2625 250 0- 1- CT- G- X- I -ER -TD T.D. I' r - = 1 MI = III = - - - I M II = - M IM HALLIBURTD11111 WELL NAME: ODSK -14 LOCATION: Oooguruk OPERATOR: Pioneer Natural Resources AREA: North Slope Sperry C3I'IHI g MUD CO: Baroid STATE: Alaska RIG: Nabors 19AC SPUD: 9- Jan -10 SPERRY JOB: AK -AM- 6852353 TD: 27- Feb -10 Water- and Oil -Based Mud Record R600/R300/R200/R1 00/ Date Depth Wt Vis PV YP Gels Filt R6 /R3 Cake Solids o (Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft-MD ppg sec lb /100 Ib /100ft2 m/30m Rheometer 32nds % % % mg/1 Ca++ 8-Feb 9874 10.20 43 16 24 10/18/- 6.8 56/40/33/25/11/9 2/- 9.0 4.5/85.5 0.20 0.10 9.1 8.0 .1/1.56 20K 680 P/U BHA, TIH,Drill to 9,874' 10-Feb 10400 12.70 49 19 33 15/22/- 6.8 71/52/42/32/13/11 2/- 17.0 3.5/78.5 0.20 0.25 9.3 9.0 .05/2.46 21K 720 Drill to 10,400 Disp w /13ppg 11 -Feb 10400 13.00 62 29 31 12/18/- 4.0 89/60/44/32/10/8 2/- 20.6 3.5/75 0.20 0.15 8.9 9.0 .05/2.5 20K 700 Cont to Disp w /13ppg/POOH 12 -Feb 10400 13.00 56 20 24 12/16/- 6.0 64/44/35/26 2/- 19.6 3.5/76 0.20 0.19 9.3 9.0 .1/2.6 20K 680 R/U and RIH w/7" csg 13-Feb 10400 11.00 50 13 26 11/18/- 7.8 52/39/32/25/10/8 2/- 12.5 2.5/84 0.20 0.10 9.0 5.0 .05/2 20K 800 RIH w /CSG Disp to 11 ppg 14-Feb 10400 11.00 47 12 25 9/14/- 8.0 46/34/25/17/8/7 2/- 12.5 2.5/84 0.10 9.0 5.0 .05/1.8 20K 640 P/U Drill pipe 15-Feb 10400 11.00 47 11 19 9/12/- 9.0 41/30/25/19/7/6 2/- 12.5 2.5/84 0.90 11.1 5.0 .11/2.7 20K 400 Tripping 16-Feb 10513 8.70 41 7 16 7/11/- 5.0 30/23/19/15/6/5 1/- 1.3 2.5/95.5 0.18 9.4 2.0 .04/.64 21K 1520 Drilling 17 -Feb 11207 8.70 38 6 14 7/9/- 5.3 26/20/17/14/6/5 1/- 1.9 3.5/93.5 0.10 0.08 8.7 2.0 .03/75 21K 1100 Cond mud and circ 18-Feb 11207 8.80 37 6 10 5/7/- 5.2 22/16/13/10/4/3 1/- 1.9 3/93.5 0.10 0.04 8.0 1.5 0.02/0.75 30k 1200 Tripping 19 -Feb 20 -Feb 10746 8.70 40 8 17 8/10/- 3.9 33/25/22/17/7/6 1/- 1.6 3.5/93.5 0.10 0.32 9.3 2.0 0.19/0.63 27k 1440 Drilling 21 -Feb 10746 8.70 42 7 14 6/8/- 5.2 28/21/18/14/5/4 1/- 1.6 3.5/93.5 0.10 0.23 9.6 2.0 0.10/0.75 26k 1600 Waiting on tools 22 -Feb 10828 8.70 40 7 16 8/10/- 5.1 30/23/20/16/6/5 1/- 1.6 3.5/93.5 0.00 0.27 9.6 1.5 0.15/0.70 26k 1600 Drilling 23-Feb 11570 8.70 40 7 15 7/9/- 5.0 29/22/19/15/6/5 1/- 1.5 3.5/93.5 0.20 0.30 9.2 2.5 0.18/0.82 28k 1700 Drilling 24-Feb 12340 8.80 39 8 18 9/11/- 4.6 34/26/22/18/8/7 1/- 2.1 3.0/93.5 0.25 0.05 9.1 2.5 0.12/0.90 27k 1640 Drilling 25-Feb 12889 8.75 40 10 19 10/12/- 4.4 39/29/26/21/10/9 1/- 1.8 4.0/92.8 0.10 0.10 9.3 2.0 0.10/1.00 26k 1640 Drilling 26-Feb 13450 8.80 38 6 17 8/10/- 4.4 29/23/19/15/8/6.5 1/- 2.2 4.0/92.5 0.25 0.05 9.3 2.5 0.15/1.20 24k 1160 Drilling 27 -Feb 13852 8.70 38 8 15 7/9/- 4.0 30/22.5/19/14.5 /6/5 1/- 0.8 5.0/92.5 0.25 0.05 9.5 2.0 0.10/0.65 32k 1560 Tripping Casing Record 16" Conductor @ 153' 10 3/4" Surface @ 3289' 7 5/8" Intermediate @ 8654' INNOMMINENNIMINEMMINMENIMINIMENNINNIMMINNIMMENIMN HALLIBURT ©N Sperry Drilling ODSK -14 Formation Tops Marker MD INC AZ TVD TVDSS PROG ND PROG SS +i- towp4b Comment Base of Permafro. 1,707' 25.29 288.47 1668 1612 1,666' 1,610' 2 Top West Sak 2,450' 43.99 282.27 2293.79 2238 2,283' 2,227' 11 Tuffaceous Shale 3,458' 56.48 277.42 2883.45 2,827' 2,918' 2,862' -35 SCP 3,557' 57.15 278.86 2937.7 2,882' 3,000' 2,944' -62 Sidetrack from PE 4,660' 56.62 281.79 3537.21 3,481' Brook 2B 6,032' 55.79 278.69 4285.1 4,229' 4,305' 4,249' -20 • Torok Top 7,370' 57.01 277.75 5024.59 4,968' 5,010' 4,954' 14 Torok Base 7,798' 57.72 281.18 5254.31 5,198' 5,255' 5,199' -1 ICP1 7,853' 58.06 281.74 5283.65 5,227' 5,366' 5,310' -82 Top HRZ 9,006' 69.57 299.01 5846.92 5,791' 5,791' 5,735' 56 Base HRZ 9,527' 77.15 310.95 5984.99 5,929' 5,919' 5,863' 66 Kalubik Marker 9,912' 78.67 315.89 6065.04 6,009' 6,001' 5,945' 64 ICP2 - T1A 10,394' 84.03 316.46 6142.06 6,086' 6,059' 6,003' 83 Kuparuk 10,395' 84.05 316.46 6142.15 6,086' 6,059' 6,003' 83 T2 Invert #1 10,580' 90 318.83 6151.93 6,096' 6,076' 6,020' 76 Marker MD INC AZ ND TVDSS PROG ND PROG SS +1- to wp05 Comment Sidetrack from PE 10,726' 92.79 316.72 6148.2 6,092' Fault Kuparuk/LC 11,255' 89.24 323.41 6149.3 6,093' 8' DTSE Invert 11,318' 90.13 324.51 6149.91 6,094' LCU 11,440' 92.03 323.4 6146.88 6,091' Kuparuk/Kalubik 12,651' 91.89 318.27 6138.67 6,082' App dip 0.4° DTSE Revert in Kalubik 12,728' 90 318.95 6136.96 6,081' Fault in Kalubik 12,795' 89.26 319.76 6137.44 6,081' -5 feet DTNW Fault in Kalubik 12,975' 89.36 319.6 6142.88 6,087' -3.5 feet DTNW Kuparuk 13,185' 87.8 321.22 6147.54 6,091' LCU 13,775' 87.73 324.66 6164.58 6,108' 77 feet of LCU TD 13,852' 89.7 324.82 6165.95 6,110' 6,147' 6,091' 18 1 1 1 1 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -14 PB1 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -70 1 1 Sperry Drilling Services p �/ 9 1 Definitive Survey Report 04 March, 2010 1 1 1 1 HALLI BURTON Sperry Drilling Services 1 I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 I Project: Oooguruk Development ND Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB Database: .Pioneer Alaska I Project Oooguruk Development Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level I Geo Datum: Map Zone: NAD 1927 (NADCON CONUS) Using Well Reference Point Alaska Zone 04 Using geodetic scale factor Well ODSK -14 - Slot ODS -14 A Well Position +N / -S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft I Wellbore ODSK -14 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I ( ?) ( ?) (nT) IGRF200510 1/6/2009 22.43 80.81 57,719 Design ODSK -14 PB1 KupB Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From (ND) +N/-S +E/ -W Direction I (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 I Survey Program Date 3/2/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date I 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.85 7,812.94 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: I Survey Map Map Vertical MD Inc Az! ND NDSS +N/-S +E/ -W Northing Easting DLS Section I (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 6,031,071.09 469,840.87 0.00 0 .00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro -SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro-SS (1) I 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR-Gyro-SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro-SS (1) I 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro-SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro-SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro-SS (1) I 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR-Gyro-SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) I 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 3/4/2010 3:38:35PM Page 2 COMPASS 2003.16 Build 42B 1 Halliburton Company Definitive Survey Report I . Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.T + 13.5 © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5 @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK-14 PB1 KupB Database: .Pioneer Alaska I Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °I1 00') (ft) Survey Tool Name 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro -SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro-SS (1) I 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) I 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) I 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) I 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) I 1,906.65 26.44 287.58 1,846.91 1,790.71 1,945.28 27.92 283.81 1,881.28 1,825.08 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) I 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 W - 417.66 6,031,249.68 469,423.97 1.57 453.58 MD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) I 2,239.17 35.18 282.18 2,131.92 2,075.72 2,286.17 37.94 282.10 2,169.67 2,113.47 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) I 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 W - 580.29 6,031,285.59 469,261.51 2.58 617.21 MD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) I 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) I 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) I 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 W - 929.88 6,031,350.94 468,912.21 4.61 964.40 MD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) I 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 -1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MVVD+IFR2+MS+sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 1 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 3 COMPASS 2003.16 Build 42B I I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) I Site: Well: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) ODSK -14 North Reference: True Wel!bore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD Inc Azi ND TVDSS +N /-S +E/ -W Northing Easting DLS Section (ft) Inc ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) I 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) I 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 -1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) I 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 -1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) I 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 -1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 4,150.23 57.31 276.50 3,262.26 3,206.06 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) I 4,223.28 56.59 276.24 3,302.10 3,245.90 4,318.73 57.54 276.13 3,353.99 3,297.79 443.06 -2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 4,415.77 58.21 278.64 3,405.60 3,349.40 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) I 4,507.67 57.40 279.24 3,454.56 3,398.36 4,603.17 57.18 280.81 3,506.17 3,449.97 474.34 -2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 4,696.47 56.26 282.43 3,557.37 3,501.17 504.03 - 2,455.72 6,031,585.03 467,387.46 1.75 2,460.00 MWD +IFR2 +MS +sag (2) I 4,795.92 55.38 283.19 3,613.24 3,557.04 4,888.73 56.43 282.13 3,665.27 3,609.07 522.27 -2,535.94 6,031,603.59 467,307.32 1.09 2,541.05 MWD +IFR2 +MS +sag (2) 539.11 - 2,610.93 6,031,620.73 467,232.41 1.47 2,616.72 MWD +IFR2 +MS +sag (2) 4,985.32 57.16 281.02 3,718.16 3,661.96 555.32 - 2,690.10 6,031,637.26 467,153.32 1.22 2,696.02 MWD +IFR2 +MS +sag (2) I 5,083.15 57.86 278.93 3,770.72 3,714.52 5,177.31 57.67 277.08 3,820.94 3,764.74 569.61 -2,771.37 6,031,651.88 467,072.12 1.94 2,776.50 MWD +IFR2 +MS +sag (2) 580.70 - 2,850.23 6,031,663.29 466,993.31 1.67 2,853.54 MWD +IFR2 +MS +sag (2) 5,273.02 57.15 277.99 3,872.50 3,816.30 591.27 - 2,930.17 6,031,674.18 466,913.42 0.97 2,931.37 MWD +IFR2 +MS +sag (2) 5,368.00 57.45 277.58 3,923.81 3,867.61 602.10 - 3,009.36 6,031,685.33 466,834.28 0.48 3,008.60 MWD +IFR2 +MS +sag (2) I 5,463.25 56.12 278.80 3,975.99 3,919.79 613.44 - 3,088.24 6,031,696.99 466,755.46 1.76 3,085.74 MWD +IFR2 +MS +sag (2) 5,558.44 55.81 280.01 4,029.26 3,973.06 626.33 - 3,166.06 6,031,710.20 466,677.70 1.10 3,162.51 MWD +IFR2 +MS +sag (2) 5,654.03 58.44 280.69 4,081.15 4,024.95 640.76 - 3,245.02 6,031,724.94 466,598.80 2.82 3,240.93 MWD +IFR2 +MS +sag (2) I 5,748.48 58.02 281.56 4,130.88 4,074.68 656.25 -3,323.81 6,031,740.75 466,520.08 0.90 3,319.59 MWD +IFR2 +MS +sag (2) 5,843.77 57.68 281.07 4,181.58 4,125.38 672.08 - 3,402.92 6,031,756.90 466,441.05 0.56 3,398.68 MWD +IFR2 +MS +sag (2) 5,938.67 56.64 280.79 4,233.05 4,176.85 687.20 - 3,481.21 6,031,772.34 466,362.83 1.12 3,476.74 MWD +IFR2 +MS +sag (2) I 6,034.66 56.29 280.93 4,286.08 4,229.88 702.28 -3,559.79 6,031,787.73 466,284.32 0.38 3,555.05 MWD +IFR2 +MS +sag (2) 6,129.07 55.43 280.95 4,339.06 4,282.86 717.10 - 3,636.51 6,031,802.87 466,207.67 0.91 3,631.55 MWD +IFR2 +MS +sag (2) 6,224.45 56.14 280.30 4,392.69 4,336.49 731.64 - 3,714.03 6,031,817.72 466,130.22 0.93 3,708.67 MWD +IFR2 +MS +sag (2) I 6,319.42 55.74 280.69 4,445.88 4,389.68 745.98 -3,791.39 6,031,832.36 466,052.92 0.54 3,785.57 MWD +IFR2 +MS +sag (2) 6,415.19 55.12 280.91 4,500.22 4,444.02 760.75 - 3,868.85 6,031,847.45 465,975.53 0.67 3,862.74 MWD +IFR2 +MS +sag (2) 6,502.10 54.78 279.48 4,550.14 4,493.94 773.35 - 3,938.87 6,031,860.33 465,905.57 1.40 3,932.20 MWD +IFR2 +MS +sag (2) 1 6,597.96 55.78 279.06 4,604.73 4,548.53 786.04 - 4,016.63 6,031,873.34 465,827.86 1.10 4,008.83 MWD +IFR2 +MS +sag (2) 3/4/2010 3:38:35PM Page 4 COMPASS 2003.16 Build 42B I 1 Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB1 KupB Database: .Pioneer Alaska I Survey Map Map Vertical MD Inc Azi ND TVDSS +N!-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °M00') (ft) Survey Tool Name 6,692.29 57.01 278.23 4,656.94 4,600.74 797.84 - 4,094.30 6,031,885.45 465,750.25 1.50 4,085.04 MWD +IFR2 +MS +sag (2) 6,788.05 58.28 277.61 4,708.19 4,651.99 808.98 - 4,174.42 6,031,896.92 465,670.18 1.43 4,163.26 MWD +IFR2 +MS +sag (2) I 6,883.73 57.65 278.16 4,758.94 4,702.74 820.11 - 4,254.77 6,031,908.37 465,589.90 0.82 4,241.67 MWD +IFR2 +MS +sag (2) 6,978.84 57.20 278.05 4,810.15 4,753.95 831.41 - 4,334.11 6,031,919.99 465,510.60 0.48 4,319.23 MWD +IFR2 +MS +sag (2) 7,073.56 58.55 276.57 4,860.52 4,804.32 841.61 - 4,413.67 6,031,930.51 465,431.09 1.94 4,396.56 MWD +IFR2 +MS +sag (2) I 7,168.75 57.36 277.30 4,911.02 4,854.82 851.35 -4,493.77 6,031,940.57 465,351.05 1.41 4,474.21 MWD +IFR2 +MS +sag (2) 7,264.19 58.45 277.16 4,961.73 4,905.53 861.52 - 4,573.98 6,031,951.07 465,270.89 1.15 4,552.13 MWD +IFR2 +MS +sag (2) 7,359.11 57.98 278.70 5,011.73 4,955.53 872.65 - 4,653.89 6,031,962.53 465,191.03 1.47 4,630.15 MWD +IFR2 +MS +sag (2) 1 7,454.19 56.86 279.20 5,062.93 5,006.73 885.11 -4,733.03 6,031,975.31 465,111.95 1.26 4,707.97 MWD +IFR2 +MS +sag (2) 7,548.93 56.20 280.22 5,115.18 5,058.98 898.44 - 4,810.93 6,031,988.95 465,034.11 1.14 4,784.97 MWD +IFR2 +MS +sag (2) 7,644.32 57.23 280.20 5,167.53 5,111.33 912.57 - 4,889.40 6,032,003.40 464,955.70 1.08 4,862.83 MWD +IFR2 +MS +sag (2) I 7,737.27 57.17 279.72 5,217.88 5,161.68 926.09 -4,966.36 6,032,017.22 464,878.81 0.44 4,939.03 MWD +IFR2 +MS +sag (2) 7,812.94 57.58 279.59 5,258.68 5,202.48 936.77 - 5,029.18 6,032,028.17 464,816.04 0.56 5,001.12 MWD +IFR2 +MS +sag (2) I 1 I I I I I II I I I 3/4/2010 3:38:35PM Page 5 COMPASS 2003.16 Build 42B I 1 Well Planning - Pioneer - Oooguruk Oooguruk Development ' Oooguruk Drill Site ODSK -14 PB2 Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -71 1 Sperry Drilling Services Definitive Survey Report 04 March, 2010 1 11 1 HALLIBURTON Sperry Drilling Services 1 I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Weilbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska I Project Oooguruk Development Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level I Geo Datum: Map Zone: NAD 1927 (NADCON CONUS) Using Well Reference Point Alaska Zone 04 Using geodetic scale factor Well ODSK -14 - Slot ODS-14 I Well Position +N / -S +E / -W 0.00 ft Northing: Easting: 6,031,071.09 ft Latitude: Longitude: 70° 29' 45.449 N 0.00 ft 469,840.87 ft 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Weilbore ODSK -14 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I IGRF200510 12/31/2009 ( ( (nT) 21.99 80.81 57,759 Design ODSK -14 PB2 KupB I Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,660.00 Vertical Section: Depth From (ND) +NI-S +E/-W Direction I () (ft) () ( 42.70 0.00 0.00 292.70 I Survey Program Date 3/4/2010 From To (ft) (ft) Survey (Weilbore) Tool Name Description Survey Date 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4,740.90 11,539.05 ODSK -14 PB2 MWD (ODSK -14 PB2) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1; I Survey . Map Map Vertical I MD (ft) Inc Azi (7) (7) ND TV +N/-S +EI W Northing Easting DLS Section (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 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro -SS (1) I 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro -SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro-SS (1) 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) I 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro -SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro-SS (1) 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR- Gyro-SS (1) I 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR-Gyro-SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) I 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) 3/4/2010 3:40:41 PM Page 2 COMPASS 2003.16 Build 42B 1 Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi TVD TVDSS +141/-S I-S +EI -W Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °I100') (ft) Survey Tool Name 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro-SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro-SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 - 119.23 6,031,151.61 469,721.97 2.74 140.89 MWD +IFR2 +MS +sag (2) I 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 - 134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 -164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) I 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 -208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) I 1,716.34 25.67 288.18 1,676.89 1,620.69 1,768.92 26.31 286.70 1,724.15 1,667.95 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) I 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) I 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) I 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) I 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) I 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) I 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 W - 893.64 6,031,345.02 468,948.42 0.89 928.75 MD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 - 967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) I 2,952.86 57.50 278.73 2,610.36 2,554.16 2,995.69 57.90 279.14 2,633.25 2,577.05 288.00 -1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) I 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3/4/2010 3:40:41PM Page 3 COMPASS 2003.16 Build 428 I I Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi TVD TVDSS +N/-S Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 - 1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) I 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 1 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 -1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 - 1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MWD +IFR2 +MS +sag (2) I 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 -1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 - 1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) I 3,864.09 56.51 280.43 3,105.92 3,049.72 3,959.70 56.84 279.68 3,158.45 3,102.25 398.98 -1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) 4,054.10 56.90 278.73 3,210.04 3,153.84 425.57 - 1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) I 4,150.23 57.31 276.50 3,262.26 3,206.06 4,223.28 56.59 276.24 3,302.10 3,245.90 436.26 -2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) 4,318.73 57.54 276.13 3,353.99 3,297.79 451.69 - 2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) I 4,415.77 58.21 278.64 3,405.60 3,349.40 4,507.67 57.40 279.24 3,454.56 3,398.36 462.26 -2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) 4,603.17 57.18 280.81 3,506.17 3,449.97 488.33 - 2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) I 4,660.00 56.62 281.79 3,537.21 3,481.01 4,740.95 55.40 279.20 3,582.47 3,526.27 497.65 -2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag (3) I 4,836.40 54.98 280.65 3,637.02 3,580.82 4,879.42 55.71 280.39 3,661.48 3,605.28 523.93 -2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 - 2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 1 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 - 2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) I 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 -2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 - 2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) I 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 -2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) 5,450.50 56.87 281.90 3,966.96 3,910.76 614.98 - 3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) I 5,546.29 56.76 281.72 4,019.39 3,963.19 5,641.35 56.95 279.09 4,071.38 4,015.18 631.39 -3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031,743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41PM Page 4 COMPASS 2003.16 Build 428 I I Halliburton Company Definitive Survey Report 1 Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wel!bore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi TVD TVDSS +Nt-S +E! -W Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 - 3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) I 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag (3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 - 3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) I 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 . 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 - 4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) I 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 -4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) 6,878.72 56.92 279.21 4,758.80 4,702.60 803.14 - 4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) I 6,974.00 57.33 278.74 4,810.52 4,754.32 7,070.69 58.44 280.02 4,861.92 4,805.72 815.62 -4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) 7,164.65 57.01 278.08 4,912.10 4,855.90 841.48 - 4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) I 7,259.49 56.57 276.96 4,964.04 4,907.84 7,354.90 56.92 277.34 5,016.36 4,960.16 851.87 -4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) 7,451.12 57.52 279.93 5,068.46 5,012.26 873.95 - 4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) I 7,545.34 57.71 279.62 5,118.93 5,062.73 7,640.14 57.14 280.28 5,169.97 5,113.77 887.46 -4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 - 4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) I 7,819.80 57.61 281.36 5,265.98 5,209.78 7,892.32 58.60 282.43 5,304.29 5,248.09 929.54 -5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) I 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 -5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032,114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) I 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032,154.95 464,244.87 2.51 5,576.60 MWD +IFR2 +MS +sag (3) 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) I 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032,242.53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) I 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032,318.39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032,362.71 463,771.84 2.61 6,093.25 MWD +IFR2 +MS +sag (3) 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) I 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD +IFR2 +MS +sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 3/4/2010 3:40:41PM Page 5 COMPASS 2003.16 Build 42B I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -14 PB2 KupB Database: .Pioneer Alaska I Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD +IFR2 +MS +sag (3) I 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6,032,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 1 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD +IFR2 +MS +sag (3) 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) I 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) I 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) 10,765.16 93.44 316.30 6,146.08 6,089.88 2,398.43 - 7,276.13 6,033,498.78 462,575.27 1.98 7,638.07 MWD +IFR2 +MS +sag (3) I 10,862.85 90.30 314.19 6,142.89 6,086.69 2,467.75 - 7,344.86 6,033,568.37 462,506.82 3.87 7,728.23 MWD +IFR2 +MS +sag (3) 10,964.23 86.00 312.52 6,146.16 6,089.96 2,537.30 - 7,418.52 6,033,638.21 462,433.46 4.55 7,823.02 MWD +IFR2 +MS +sag (3) 11,056.05 90.61 319.69 6,148.88 6,092.68 2,603.38 - 7,482.09 6,033,704.54 462,370.16 9.28 7,907.17 MWD +IFR2 +MS +sag (3) I 11,151.70 86.98 318.44 6,150.89 6,094.69 2,675.61 - 7,544.73 6,033,777.02 462,307.82 4.01 7,992.83 MWD +IFR2 +MS +sag (3) 11,247.97 85.96 319.38 6,156.82 6,100.62 2,748.03 - 7,607.88 6,033,849.68 462,244.97 1.44 8,079.04 MWD +IFR2 +MS +sag (3) 11,345.12 86.46 317.68 6,163.24 6,107.04 2,820.66 - 7,672.07 6,033,922.57 462,181.08 1.82 8,166.29 MWD +IFR2 +MS +sag (3) 1 11,440.88 86.76 316.50 6,168.91 6,112.71 2,890.67 - 7,737.16 6,033,992.83 462,116.28 1.27 8,253.35 MWD +IFR2 +MS +sag (3) 11,539.05 86.21 314.71 6,174.93 6,118.73 2,960.68 - 7,805.70 6,034,063.12 462,048.03 1.90 8,343.60 MWD +IFR2 +MS +sag (3) I I I I I I 3/4/2010 3:40:41 PM Page 6 COMPASS 2003.16 Build 428 I I 1 I Well Planning - Pioneer - Oooguruk Oooguruk Development I Oooguruk Drill Site ODSK -14 I Permit to Drill: 209 -155 API: 50- 703 - 20610 -00 -00 I I r Drilling l l in Services �rper y g 1 Definitive Survey Report 04 March, 2010 1 I 4 114 I 1 I 1 , I .:.; i 4 ' ` ` HALLIBURTON Sperry Drilling Services I 7 , . I 1 Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development ND Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Weilbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska I 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 ODSK -14 - Slot ODS -14 Well Position +NI-S 0.00 ft Northing: 6,031,071.09 ft Latitude: 70° 29' 45.449 N +E / -W 0.00 ft Easting: 469,840.87 ft Longitude: 150° 14' 47.798 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft I Welibore ODSK -14 Magnetics Model Name Sample Date Declination Dip Angle Field Strength I ( ?) ( ?) (nT) IGRF200510 1/7/2008 22.87 80.81 57,678 Design ODSK -14 KupB I Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,726.00 Vertical Section: Depth From (ND) +N /-S +E/-W Direction I (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 292.70 I Survey Program Date 3/4 /2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date I 100.00 1,293.00 ODSK -14 PB1 Gyro (ODSK -14 PB1 Kup SR- Gyro -SS Fixed:v2:surface readout gyro single shot 1/8/2010 12: 1,335.90 4,603.20 ODSK -14 PB1 MWD (ODSK -14 PB1 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/11/2010 1: 4 ,740.90 10,669.40 ODSK -14 PB2 MWD (ODSK -14 PB2 Kur MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 1/25/2010 1: 10,726.00 13,820.93 ODSK -14 MWD (ODSK -14) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 2/20/2010 1: I Survey I Map Map Vertical MD Inc Azl ND NDSS +NI-S +Et -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,071.09 469,840.87 0.00 0.00 UNDEFINED I 100.00 0.65 320.02 100.00 43.80 0.25 -0.21 6,031,071.34 469,840.66 1.13 0.29 SR- Gyro-SS (1) 139.00 0.84 261.85 139.00 82.80 0.38 -0.63 6,031,071.47 469,840.24 1.91 0.73 SR- Gyro-SS (1) 199.00 1.02 299.62 198.99 142.79 0.58 -1.53 6,031,071.68 469,839.34 1.04 1.64 SR- Gyro-SS (1) I 259.00 1.04 300.11 258.98 202.78 1.12 -2.47 6,031,072.22 469,838.41 0.04 2.71 SR- Gyro-SS (1) 350.00 1.51 313.67 349.96 293.76 2.36 -4.05 6,031,073.47 469,836.83 0.61 4.65 SR- Gyro -SS (1) 440.00 2.07 320.60 439.91 383.71 4.43 -5.94 6,031,075.55 469,834.95 0.67 7.19 SR- Gyro-SS (1) I 533.00 2.76 315.95 532.83 476.63 7.34 -8.56 6,031,078.47 469,832.34 0.77 10.73 SR-Gyro-SS (1) 628.00 3.17 311.38 627.70 571.50 10.72 -12.13 6,031,081.86 469,828.79 0.50 15.32 SR- Gyro-SS (1) 722.00 5.42 309.46 721.43 665.23 15.26 -17.50 6,031,086.42 469,823.43 2.40 22.04 SR- Gyro -SS (1) I 817.00 6.49 309.21 815.92 759.72 21.51 -25.13 6,031,092.70 469,815.83 1.13 31.48 SR- Gyro-SS (1) 3/4/2010 3 :18 :37PM Page 2 COMPASS 2003.16 Build 42B I Halliburton Company Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska Survey Map Map Vertical I 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 912.00 7.53 307.15 910.21 854.01 28.66 -34.25 6,031,099.89 469,806.74 1.13 42.66 SR- Gyro -SS (1) 1,008.00 10.27 308.31 1,005.04 948.84 37.77 -45.98 6,031,109.04 469,795.05 2.86 56.99 SR- Gyro -SS (1) 1,101.00 13.62 302.30 1,096.02 1,039.82 48.76 -61.75 6,031,120.10 469,779.33 3.84 75.78 SR- Gyro -SS (1) 1,197.00 14.85 301.23 1,189.07 1,132.87 61.18 -81.82 6,031,132.59 469,759.31 1.31 99.09 SR- Gyro-SS (1) 1,293.00 18.78 295.19 1,280.95 1,224.75 74.14 - 106.33 6,031,145.65 469,734.85 4.47 126.71 SR- Gyro -SS (1) 1,335.85 19.89 294.04 1,321.39 1,265.19 80.05 W - 119.23 6,031,151.61 469,721.97 2.74 140.89 MD +IFR2 +MS +sag (2) 1,384.46 19.26 293.34 1,367.19 1,310.99 86.59 -134.15 6,031,158.22 469,707.09 1.38 157.17 MWD +IFR2 +MS +sag (2) 1,483.34 19.75 291.78 1,460.39 1,404.19 99.25 - 164.63 6,031,171.00 469,676.66 0.72 190.18 MWD +IFR2 +MS +sag (2) 1,525.35 19.85 292.19 1,499.92 1,443.72 104.58 - 177.83 6,031,176.38 469,663.48 0.41 204.41 MWD +IFR2 +MS +sag (2) 1,577.32 19.81 291.81 1,548.81 1,492.61 111.18 - 194.18 6,031,183.05 469,647.17 0.26 222.04 MWD +IFR2 +MS +sag (2) 1,620.65 21.71 291.05 1,589.32 1,533.12 116.79 - 208.47 6,031,188.71 469,632.89 4.43 237.39 MWD +IFR2 +MS +sag (2) 1,673.60 24.04 289.43 1,638.11 1,581.91 123.90 - 227.79 6,031,195.90 469,613.61 4.56 257.95 MWD +IFR2 +MS +sag (2) 1,716.34 25.67 288.18 1,676.89 1,620.69 129.68 - 244.79 6,031,201.75 469,596.63 4.01 275.87 MWD +IFR2 +MS +sag (2) 1,768.92 26.31 286.70 1,724.15 1,667.95 136.58 - 266.77 6,031,208.74 469,574.68 1.73 298.82 MWD +IFR2 +MS +sag (2) 1,811.98 27.57 286.92 1,762.53 1,706.33 142.23 - 285.45 6,031,214.46 469,556.03 2.94 318.22 MWD +IFR2 +MS +sag (2) 1,858.63 26.93 288.45 1,804.01 1,747.81 148.71 - 305.80 6,031,221.02 469,535.71 2.03 339.50 MWD +IFR2 +MS +sag (2) 1,906.65 26.44 287.58 1,846.91 1,790.71 155.38 - 326.30 6,031,227.78 469,515.23 1.31 360.99 MWD +IFR2 +MS +sag (2) 1,945.28 27.92 283.81 1,881.28 1,825.08 160.14 - 343.29 6,031,232.60 469,498.27 5.88 378.49 MWD +IFR2 +MS +sag (2) 2,000.95 30.29 282.26 1,929.92 1,873.72 166.23 - 369.67 6,031,238.80 469,471.92 4.47 405.18 MWD +IFR2 +MS +sag (2) 2,096.35 31.76 282.83 2,011.67 1,955.47 176.92 - 417.66 6,031,249.68 469,423.97 1.57 453.58 MWD +IFR2 +MS +sag (2) 2,142.14 31.23 283.15 2,050.71 1,994.51 182.29 - 440.97 6,031,255.15 469,400.69 1.21 477.16 MWD +IFR2 +MS +sag (2) 2,192.07 33.18 283.02 2,092.96 2,036.76 188.32 - 466.89 6,031,261.28 469,374.80 3.91 503.39 MWD +IFR2 +MS +sag (2) 2,239.17 35.18 282.18 2,131.92 2,075.72 194.08 - 492.71 6,031,267.15 469,349.00 4.36 529.44 MWD +IFR2 +MS +sag (2) 2,286.17 37.94 282.10 2,169.67 2,113.47 199.97 - 520.08 6,031,273.15 469,321.66 5.87 556.96 MWD +IFR2 +MS +sag (2) I 2,332.78 39.75 280.95 2,205.97 2,149.77 205.80 - 548.72 6,031,279.10 469,293.04 4.18 585.64 MWD +IFR2 +MS +sag (2) 2,382.54 40.90 281.83 2,243.91 2,187.71 212.17 - 580.29 6,031,285.59 469,261.51 2.58 617.21 MWD +IFR2 +MS +sag (2) 2,431.14 42.85 282.03 2,280.09 2,223.89 218.87 - 612.03 6,031,292.42 469,229.80 4.02 649.08 MWD +IFR2 +MS +sag (2) 2,477.50 45.64 282.61 2,313.30 2,257.10 225.78 - 643.62 6,031,299.45 469,198.23 6.08 680.90 MWD +IFR2 +MS +sag (2) 2,526.06 46.81 281.83 2,346.89 2,290.69 233.20 - 677.89 6,031,307.01 469,164.00 2.67 715.37 MWD +IFR2 +MS +sag (2) 2,571.55 48.04 280.04 2,377.67 2,321.47 239.55 - 710.78 6,031,313.49 469,131.14 3.96 748.16 MWD +IFR2 +MS +sag (2) 2,623.19 48.63 279.49 2,412.00 2,355.80 246.09 - 748.80 6,031,320.19 469,093.15 1.39 785.76 MWD +IFR2 +MS +sag (2) 2,667.78 50.17 279.53 2,441.02 2,384.82 251.68 - 782.19 6,031,325.92 469,059.79 3.45 818.72 MWD +IFR2 +MS +sag (2) 2,719.73 50.62 279.86 2,474.13 2,417.93 258.42 - 821.64 6,031,332.82 469,020.37 0.99 857.72 MWD +IFR2 +MS +sag (2) 2,762.30 52.50 279.34 2,500.60 2,444.40 263.98 - 854.52 6,031,338.51 468,987.52 4.52 890.19 MWD +IFR2 +MS +sag (2) 2,812.13 52.91 279.12 2,530.79 2,474.59 270.34 - 893.64 6,031,345.02 468,948.42 0.89 928.75 MWD +IFR2 +MS +sag (2) 2,857.51 55.00 278.96 2,557.49 2,501.29 276.10 - 929.88 6,031,350.94 468,912.21 4.61 964.40 MWD +IFR2 +MS +sag (2) I 2,904.11 56.37 278.40 2,583.76 2,527.56 281.91 -967.93 6,031,356.90 468,874.19 3.10 1,001.74 MWD +IFR2 +MS +sag (2) 2,952.86 57.50 278.73 2,610.36 2,554.16 288.00 - 1,008.33 6,031,363.14 468,833.82 2.39 1,041.36 MWD +IFR2 +MS +sag (2) 2,995.69 57.90 279.14 2,633.25 2,577.05 293.62 - 1,044.09 6,031,368.91 468,798.09 1.24 1,076.52 MWD +IFR2 +MS +sag (2) I 3,047.95 57.89 279.26 2,661.02 2,604.82 300.70 - 1,087.79 6,031,376.17 468,754.42 0.20 1,119.56 MWD +IFR2 +MS +sag (2) 3/4/2010 3:18:37PM Page 3 COMPASS 2003.16 Build 428 I I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi TVD TVDSS +N /-S +E/ -W Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °11001 on Survey Tool Name 3,092.97 58.23 278.11 2,684.84 2,628.64 306.46 - 1,125.55 6,031,382.09 468,716.68 2.30 1,156.63 MWD +IFR2 +MS +sag (2) 3,142.41 57.88 278.45 2,711.00 2,654.80 312.51 - 1,167.07 6,031,388.30 468,675.20 0.92 1,197.26 MWD +IFR2 +MS +sag (2) I 3,190.13 57.33 276.99 2,736.56 2,680.36 317.92 -1,206.99 6,031,393.87 468,635.30 2.83 1,236.18 MWD +IFR2 +MS +sag (2) 3,237.66 57.03 276.61 2,762.33 2,706.13 322.65 - 1,246.66 6,031,398.76 468,595.66 0.92 1,274.60 MWD +IFR2 +MS +sag (2) 3,282.53 57.08 276.36 2,786.73 2,730.53 326.90 - 1,284.07 6,031,403.17 468,558.27 0.48 1,310.75 MWD +IFR2 +MS +sag (2) I 3,332.86 56.57 276.65 2,814.27 2,758.07 331.67 - 1,325.92 6,031,408.11 468,516.44 1.12 1,351.21 MWD +IFR2 +MS +sag (2) 3,381.36 56.37 277.03 2,841.06 2,784.86 336.49 - 1,366.07 6,031,413.08 468,476.32 0.77 1,390.10 MWD +IFR2 +MS +sag (2) 3,427.82 56.43 277.12 2,866.77 2,810.57 341.26 - 1,404.47 6,031,418.01 468,437.94 0.21 1,427.37 MWD +IFR2 +MS +sag (2) I 3,507.51 56.57 277.92 2,910.75 2,854.55 349.95 -1,470.35 6,031,426.97 468,372.10 0.86 1,491.50 MW1J+IFR2 +MS +sag (2) 3,579.48 57.41 279.29 2,949.96 2,893.76 358.99 - 1,530.02 6,031,436.24 468,312.48 1.98 1,550.03 MWD +IFR2 +MS +sag (2) 3,672.05 56.32 279.02 3,000.56 2,944.36 371.32 - 1,606.55 6,031,448.89 468,236.01 1.20 1,625.39 MWD +IFR2 +MS +sag (2) I 3,768.99 57.04 280.12 3,053.81 2,997.61 384.79 -1,686.42 6,031,462.68 468,156.20 1.20 1,704.28 MWD +IFR2 +MS +sag (2) 3,864.09 56.51 280.43 3,105.92 3,049.72 398.98 - 1,764.70 6,031,477.18 468,077.98 0.62 1,781.97 MWD +IFR2 +MS +sag (2) 3,959.70 56.84 279.68 3,158.45 3,102.25 412.93 - 1,843.36 6,031,491.45 467,999.39 0.74 1,859.92 MWD +IFR2 +MS +sag (2) I 4,054.10 56.90 278.73 3,210.04 3,153.84 4,150.23 57.31 276.50 3,262.26 3,206.06 425.57 -1,921.39 6,031,504.41 467,921.41 0.85 1,936.79 MWD +IFR2 +MS +sag (2) 436.26 - 2,001.39 6,031,515.42 467,841.47 1.99 2,014.71 MWD +IFR2 +MS +sag (2) 4,223.28 56.59 276.24 3,302.10 3,245.90 443.06 - 2,062.24 6,031,522.46 467,780.65 1.03 2,073.47 MWD +IFR2 +MS +sag (2) I 4,318.73 57.54 276.13 3,353.99 3,297.79 4,415.77 58.21 278.64 3,405.60 3,349.40 451.69 -2,141.88 6,031,531.42 467,701.05 1.00 2,150.28 MWD +IFR2 +MS +sag (2) 462.26 - 2,223.37 6,031,542.32 467,619.61 2.30 2,229.53 MWD +IFR2 +MS +sag (2) 4,507.67 57.40 279.24 3,454.56 3,398.36 474.34 - 2,300.20 6,031,554.71 467,542.85 1.04 2,305.07 MWD +IFR2 +MS +sag (2) I 4,603.17 57.18 280.81 3,506.17 3,449.97 4,660.00 56.62 281.79 3,537.21 3,481.01 488.33 -2,379.32 6,031,569.01 467,463.79 1.40 2,383.46 MWD +IFR2 +MS +sag (2) 497.65 - 2,426.00 6,031,578.53 467,417.15 1.75 2,430.13 MWD +IFR2 +MS +sag (3) 4,740.95 55.40 279.20 3,582.47 3,526.27 509.89 - 2,491.99 6,031,591.03 467,351.22 3.05 2,495.72 MWD +IFR2 +MS +sag (3) 4,784.37 55.12 280.66 3,607.21 3,551.01 516.04 - 2,527.13 6,031,597.33 467,316.11 2.84 2,530.52 MWD +IFR2 +MS +sag (3) I 4,836.40 54.98 280.65 3,637.02 3,580.82 523.93 - 2,569.04 6,031,605.38 467,274.23 0.27 2,572.22 MWD +IFR2 +MS +sag (3) 4,879.42 55.71 280.39 3,661.48 3,605.28 530.39 - 2,603.83 6,031,611.98 467,239.47 1.77 2,606.82 MWD +IFR2 +MS +sag (3) 4,928.90 56.07 280.79 3,689.23 3,633.03 537.92 - 2,644.10 6,031,619.67 467,199.24 0.99 2,646.87 MWD +IFR2 +MS +sag (3) I 4,975.73 56.82 279.53 3,715.11 3,658.91 544.80 -2,682.52 6,031,626.71 467,160.86 2.76 2,684.96 MWD +IFR2 +MS +sag (3) 5,022.93 57.63 279.55 3,740.67 3,684.47 551.38 - 2,721.65 6,031,633.45 467,121.75 1.72 2,723.61 MWD +IFR2 +MS +sag (3) 5,069.44 57.64 279.44 3,765.56 3,709.36 557.86 - 2,760.40 6,031,640.08 467,083.03 0.20 2,761.85 MWD +IFR2 +MS +sag (3) I 5,121.01 58.64 278.68 3,792.78 3,736.58 564.75 -2,803.65 6,031,647.15 467,039.81 2.31 2,804.42 MWD +IFR2 +MS +sag (3) 5,165.63 59.18 279.88 3,815.83 3,759.63 570.91 - 2,841.36 6,031,653.47 467,002.13 2.60 2,841.58 MWD +IFR2 +MS +sag (3) 5,214.88 58.84 279.01 3,841.18 3,784.98 577.84 - 2,883.01 6,031,660.57 466,960.52 1.66 2,882.68 MWD +IFR2 +MS +sag (3) I 5,260.19 58.65 280.84 3,864.69 3,808.49 584.52 -2,921.16 6,031,667.39 466,922.40 3.48 2,920.45 MWD +IFR2 +MS +sag (3) 5,310.13 57.87 279.64 3,890.97 3,834.77 592.07 - 2,962.95 6,031,675.12 466,880.64 2.57 2,961.92 MWD +IFR2 +MS +sag (3) 5,355.17 57.25 281.22 3,915.13 3,858.93 598.95 - 3,000.34 6,031,682.15 466,843.29 3.26 2,999.06 MWD +IFR2 +MS +sag (3) I 5,450.50 56.87 281.90 3,966.96 3,910.76 5,546.29 56.76 281.72 4,019.39 3,963.19 614.98 -3,078.72 6,031,698.49 466,764.98 0.72 3,077.56 MWD +IFR2 +MS +sag (3) 631.39 - 3,157.19 6,031,715.22 466,686.59 0.19 3,156.28 MWD +IFR2 +MS +sag (3) 5,641.35 56.95 279.09 4,071.38 4,015.18 645.76 - 3,235.46 6,031,729.90 466,608.38 2.33 3,234.04 MWD +IFR2 +MS +sag (3) I 5,737.41 57.43 279.19 4,123.43 4,067.23 658.58 - 3,315.17 6,031,743.05 466,528.73 0.51 3,312.52 MWD +IFR2 +MS +sag (3) 3/42010 3:18:37PM Page 4 COMPASS 2003.16 Buikl 428 I 1 Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Welibore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska 1 Survey Map Map Vertical I MD Inc Azi ND TVDSS +141/-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name 5,832.97 56.75 280.30 4,175.35 4,119.15 672.16 - 3,394.24 6,031,756.95 466,449.73 1.21 3,390.70 MWD +IFR2 +MS +sag (3) 5,928.46 56.88 278.29 4,227.62 4,171.42 685.07 - 3,473.10 6,031,770.17 466,370.93 1.77 3,468.43 MWD +IFR2 +MS +sag (3) I 6,021.70 55.78 278.69 4,279.31 4,223.11 696.52 -3,549.84 6,031,781.93 466,294.24 1.23 3,543.66 MWD +IFR2 +MS +sag (3) 6,120.05 55.88 278.67 4,334.55 4,278.35 708.80 - 3,630.29 6,031,794.54 466,213.86 0.10 3,622.61 MWD +IFR2 +MS +sag (3) 6,211.89 56.07 277.78 4,385.94 4,329.74 719.69 - 3,705.62 6,031,805.73 466,138.58 0.83 3,696.30 MWD +IFR2 +MS +sag (3) I 6,307.87 55.88 278.96 4,439.65 4,383.45 731.27 -3,784.32 6,031,817.63 466,059.93 1.04 3,773.37 MWD +IFR2 +MS +sag (3) 6,401.87 55.91 277.36 4,492.35 4,436.15 742.31 - 3,861.36 6,031,828.99 465,982.95 1.41 3,848.71 MWD +IFR2 +MS +sag (3) 6,497.51 56.14 278.43 4,545.80 4,489.60 753.21 - 3,939.92 6,031,840.20 465,904.44 0.96 3,925.39 MWD +IFR2 +MS +sag (3) I 6,595.53 55.72 279.41 4,600.71 4,544.51 765.80 -4,020.13 6,031,853.11 465,824.29 0.93 4,004.24 MWD +IFR2 +MS +sag (3) 6,689.05 55.60 279.22 4,653.47 4,597.27 778.29 - 4,096.33 6,031,865.92 465,748.15 0.21 4,079.37 MWD +IFR2 +MS +sag (3) 6,783.67 56.27 278.91 4,706.47 4,650.27 790.64 - 4,173.73 6,031,878.58 465,670.80 0.76 4,155.54 MWD +IFR2 +MS +sag (3) I 6,878.72 56.92 279.21 4,758.80 4,702.60 6,974.00 57.33 278.74 4,810.52 4,754.32 803.14 -4,252.09 6,031,891.39 465,592.50 0.73 4,232.65 MWD +IFR2 +MS +sag (3) 815.62 - 4,331.13 6,031,904.19 465,513.52 0.60 4,310.39 MWD +IFR2 +MS +sag (3) 7,070.69 58.44 280.02 4,861.92 4,805.72 828.97 - 4,411.93 6,031,917.87 465,432.79 1.60 4,390.07 MWD +IFR2 +MS +sag (3) I 7,164.65 57.01 278.08 4,912.10 4,855.90 7,259.49 56.57 276.96 4,964.04 4,907.84 841.48 -4,490.37 6,031,930.69 465,354.40 2.32 4,467.27 MWD +IFR2 +MS +sag (3) 851.87 - 4,569.03 6,031,941.40 465,275.79 1.09 4,543.85 MWD +IFR2 +MS +sag (3) 7,354.90 56.92 277.34 5,016.36 4,960.16 861.80 - 4,648.20 6,031,951.65 465,196.67 0.50 4,620.71 MWD +IFR2 +MS +sag (3) I 7,451.12 57.52 279.93 5,068.46 5,012.26 7,545.34 57.71 279.62 5,118.93 5,062.73 873.95 -4,728.17 6,031,964.12 465,116.76 2.35 4,699.18 MWD +IFR2 +MS +sag (3) 887.46 - 4,806.58 6,031,977.95 465,038.42 0.34 4,776.73 MWD +IFR2 +MS +sag (3) 7,640.14 57.14 280.28 5,169.97 5,113.77 901.26 - 4,885.26 6,031,992.07 464,959.80 0.84 4,854.64 MWD +IFR2 +MS +sag (3) I 7,733.96 58.03 280.67 5,220.26 5,164.06 915.66 -4,963.14 6,032,006.78 464,881.98 1.01 4,932.05 MWD +IFR2 +MS +sag (3) 7,819.80 57.61 281.36 5,265.98 5,209.78 929.54 - 5,034.46 6,032,020.95 464,810.73 0.84 5,003.19 MWD +IFR2 +MS +sag (3) 7,892.32 58.60 282.43 5,304.29 5,248.09 942.23 - 5,094.70 6,032,033.89 464,750.55 1.85 5,063.67 MWD +IFR2 +MS +sag (3) 7,936.93 58.06 282.59 5,327.71 5,271.51 950.46 - 5,131.77 6,032,042.26 464,713.52 1.25 5,101.04 MWD +IFR2 +MS +sag (3) 8,030.95 58.00 283.17 5,377.50 5,321.30 968.23 - 5,209.52 6,032,060.35 464,635.85 0.53 5,179.63 MWD +IFR2 +MS +sag (3) 8,126.69 57.50 282.68 5,428.58 5,372.38 986.35 - 5,288.44 6,032,078.78 464,557.01 0.68 5,259.42 MWD +IFR2 +MS +sag (3) 8,223.64 56.98 282.71 5,481.05 5,424.85 1,004.26 - 5,367.97 6,032,097.02 464,477.56 0.54 5,339.71 MWD +IFR2 +MS +sag (3) I 8,318.22 57.18 282.49 5,532.45 5,476.25 1,021.58 - 5,445.46 6,032,114.65 464,400.15 0.29 5,417.87 MWD +IFR2 +MS +sag (3) 8,412.22 57.92 284.03 5,582.89 5,526.69 1,039.78 - 5,522.66 6,032,133.16 464,323.03 1.59 5,496.12 MWD +IFR2 +MS +sag (3) 8,507.55 58.80 286.64 5,632.90 5,576.70 1,061.25 - 5,600.92 6,032,154.95 464,244.87 2.51 5,576.60 MWD +IFR2 +MS +sag (3) I 8,602.68 61.22 289.43 5,680.45 5,624.25 1,086.78 - 5,679.24 6,032,180.79 464,166.66 3.59 5,658.70 MWD +IFR2 +MS +sag (3) 8,698.71 63.48 291.09 5,725.02 5,668.82 1,116.24 - 5,759.02 6,032,210.57 464,087.00 2.81 5,743.68 MWD +IFR2 +MS +sag (3) 8,793.38 65.63 292.35 5,765.69 5,709.49 1,147.88 - 5,838.43 6,032,242.53 464,007.73 2.57 5,829.15 MWD +IFR2 +MS +sag (3) I 8,887.77 67.29 295.26 5,803.40 5,747.20 1,182.82 - 5,917.58 6,032,277.78 463,928.73 3.33 5,915.65 MWD +IFR2 +MS +sag (3) 8,983.47 69.08 298.66 5,838.97 5,782.77 1,223.10 - 5,996.75 6,032,318.39 463,849.74 3.79 6,004.23 MWD +IFR2 +MS +sag (3) 9,078.80 71.14 300.14 5,871.40 5,815.20 1,267.11 - 6,074.84 6,032,362.71 463,771.84 2.61 6,093.25 MWD +IFR2 +MS +sag (3) I 9,173.71 73.15 302.97 5,900.50 5,844.30 1,314.39 - 6,151.80 6,032,410.29 463,695.08 3.54 6,182.50 MWD +IFR2 +MS +sag (3) 9,268.02 75.39 305.66 5,926.07 5,869.87 1,365.56 - 6,226.76 6,032,461.77 463,620.33 3.63 6,271.40 MWD +IFR2 +MS +sag (3) 9,305.89 76.15 306.82 5,935.38 5,879.18 1,387.27 - 6,256.36 6,032,483.58 463,590.82 3.58 6,307.09 MWD +IFR2 +MS +sag (3) 1 9,365.66 77.18 306.81 5,949.17 5,892.97 1,422.12 - 6,302.92 6,032,518.62 463,544.40 1.72 6,363.49 MWD +IFR2 +MS +sag (3) 3/4!2010 3:18:37PM Page 5 COMPASS 2003.16 Build 428 I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wel!bore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi ND TVDSS +N / -S +E! -W Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 9,460.82 77.18 308.84 5,970.29 5,914.09 1,479.01 - 6,376.21 6,032,575.81 463,471.36 2.08 6,453.06 MWD +IFR2 +MS +sag (3) 9,555.69 77.13 311.87 5,991.38 5,935.18 1,538.90 - 6,446.69 6,032,635.97 463,401.13 3.11 6,541.18 MWD +IFR2 +MS +sag (3) I 9,652.30 78.09 313.01 6,012.11 5,955.91 1,602.57 - 6,516.32 6,032,699.93 463,331.76 1.52 6,630.00 MWD +IFR2 +MS +sag (3) 9,746.64 78.06 315.19 6,031.61 5,975.41 1,666.81 - 6,582.60 6,032,764.42 463,265.75 2.26 6,715.93 MWD +IFR2 +MS +sag (3) 9,842.04 78.35 315.72 6,051.11 5,994.91 1,733.36 - 6,648.11 6,032,831.23 463,200.52 0.62 6,802.05 MWD +IFR2 +MS +sag (3) I 9,935.98 78.78 315.95 6,069.73 6,013.53 1,799.41 - 6,712.26 6,032,897.53 463,136.64 0.52 6,886.72 MWD +IFR2 +MS +sag (3) 10,031.18 78.70 316.16 6,088.32 6,032.12 1,866.64 - 6,777.05 6,032,965.02 463,072.13 0.23 6,972.44 MWD +IFR2 +MS +sag (3) 10,126.66 80.28 316.33 6,105.74 6,049.54 1,934.44 - 6,841.98 6,033,033.08 463,007.49 1.66 7,058.50 MWD +IFR2 +MS +sag (3) 1 10,221.55 81.60 316.13 6,120.68 6,064.48 2,002.11 - 6,906.80 6,033,101.00 462,942.95 1.41 7,144.41 MWD +IFR2 +MS +sag (3) 10,317.62 83.21 316.00 6,133.38 6,077.18 2,070.68 - 6,972.87 6,033,169.83 462,877.16 1.68 7,231.82 MWD +IFR2 +MS +sag (3) 10,379.61 83.59 316.37 6,140.50 6,084.30 2,115.12 - 7,015.50 6,033,214.44 462,834.72 0.85 7,288.30 MWD +IFR2 +MS +sag (3) I 10,476.16 86.49 316.95 6,148.85 6,092.65 2,185.07 - 7,081.51 6,033,284.65 462,769.00 3.06 7,376.19 MWD +IFR2 +MS +sag (3) 10,573.14 89.87 318.94 6,151.93 6,095.73 2,257.02 - 7,146.42 6,033,356.86 462,704.38 4.04 7,463.85 MWD +IFR2 +MS +sag (3) 10,669.40 91.84 317.32 6,150.49 6,094.29 2,328.69 - 7,210.66 6,033,428.78 462,640.44 2.65 7,550.76 MWD +IFR2 +MS +sag (3) I 10,726.00 92.79 316.72 6,148.20 6,092.00 2,370.07 - 7,249.21 6,033,470.31 462,602.06 1.98 7,602.30 MWD +IFR2 +MS +sag (4) 10,766.12 90.31 317.66 6,147.12 6,090.92 2,399.48 - 7,276.47 6,033,499.83 462,574.93 6.61 7,638.79 MWD +IFR2 +MS +sag (4) 10,797.83 89.47 317.75 6,147.18 6,090.98 2,422.94 - 7,297.80 6,033,523.37 462,553.69 2.66 7,667.53 MWD +IFR2 +MS +sag (4) I 10,830.72 88.97 316.86 6,147.63 6,091.43 2,447.11 - 7,320.11 6,033,547.63 462,531.49 3.10 7,697.43 MWD +IFR2 +MS +sag (4) 10,853.73 89.33 317.61 6,147.97 6,091.77 2,464.00 - 7,335.73 6,033,564.58 462,515.94 3.62 7,718.36 MWD +IFR2 +MS +sag (4) 10,895.73 91.42 319.05 6,147.69 6,091.49 2,495.37 - 7,363.65 6,033,596.06 462,488.15 6.04 7,756.22 MWD +IFR2 +MS +sag (4) I 10,928.96 89.36 317.27 6,147.47 6,091.27 2,520.13 - 7,385.81 6,033,620.90 462,466.09 8.19 7,786.22 MWD +IFR2 +MS +sag (4) 10,958.52 88.95 316.64 6,147.90 6,091.70 2,541.73 - 7,405.99 6,033,642.58 462,446.00 2.54 7,813.17 MWD +IFR2 +MS +sag (4) 10,991.76 89.68 316.41 6,148.30 6,092.10 2,565.85 - 7,428.85 6,033,666.79 462,423.24 2.30 7,843.57 MWD +IFR2 +MS +sag (4) 11,024.17 91.03 318.21 6,148.10 6,091.90 2,589.67 - 7,450.83 6,033,690.70 462,401.36 6.94 7,873.04 MWD +IFR2 +MS +sag (4) 1 11,055.41 89.88 318.65 6,147.85 6,091.65 2,613.04 - 7,471.55 6,033,714.15 462,380.73 3.94 7,901.18 MWD +IFR2 +MS +sag (4) 11,088.59 89.44 320.28 6,148.05 6,091.85 2,638.25 - 7,493.12 6,033,739.45 462,359.27 5.09 7,930.80 MWD +IFR2 +MS +sag (4) 11,120.48 89.88 321.08 6,148.24 6,092.04 2,662.92 - 7,513.32 6,033,764.20 462,339.17 2.86 7,958.96 MWD +IFR2 +MS +sag (4) I 11,151.77 89.91 321.48 6,148.30 6,092.10 2,687.33 - 7,532.90 6,033,788.69 462,319.70 1.28 7,986.44 MWD +IFR2 +MS +sag (4) 11,201.20 89.31 323.11 6,148.63 6,092.43 2,726.44 - 7,563.13 6,033,827.91 462,289.63 3.51 8,029.42 MWD +IFR2 +MS +sag (4) 11,248.49 89.27 323.35 6,149.22 6,093.02 2,764.32 - 7,591.43 6,033,865.90 462,261.48 0.51 8,070.15 MWD +IFR2 +MS +sag (4) I 11,280.78 89.11 323.67 6,149.67 6,093.47 2,790.28 - 7,610.63 6,033,891.94 462,242.39 1.11 8,097.88 MWD +IFR2 +MS +sag (4) 11,308.60 89.89 324.83 6,149.92 6,093.72 2,812.85 - 7,626.88 6,033,914.58 462,226.23 5.02 8,121.59 MWD +IFR2 +MS +sag (4) 11,344.71 90.80 323.60 6,149.70 6,093.50 2,842.14 - 7,648.00 6,033,943.95 462,205.24 4.24 8,152.37 MWD +IFR2 +MS +sag (4) I 11,376.32 91.90 323.30 6,148.96 6,092.76 2,867.53 - 7,666.82 6,033,969.41 462,186.52 3.61 8,179.53 MWD +IFR2 +MS +sag (4) 11,409.34 91.77 322.69 6,147.90 6,091.70 2,893.89 - 7,686.68 6,033,995.84 462,166.77 1.89 8,208.02 MWD +IFR2 +MS +sag (4) 11,441.10 92.04 323.43 6,146.84 6,090.64 2,919.26 - 7,705.76 6,034,021.29 462,147.80 2.48 8,235.41 MWD +IFR2 +MS +sag (4) I 11,472.44 92.74 324.01 6,145.54 6,089.34 2,944.50 - 7,724.29 6,034,046.60 462,129.37 2.90 8,262.25 MWD +IFR2 +MS +sag (4) 11,506.38 90.48 322.43 6,144.58 6,088.38 2,971.67 - 7,744.60 6,034,073.85 462,109.17 8.12 8,291.47 MWD +IFR2 +MS +sag (4) 11,538.93 89.83 323.81 6,144.49 6,088.29 2,997.70 - 7,764.13 6,034,099.96 462,089.75 4.69 8,319.54 MWD +IFR2 +MS +sag (4) I 11,570.08 90.54 322.31 6,144.39 6,088.19 3,022.60 - 7,782.85 6,034,124.93 462,071.13 5.33 8,346.42 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 6 COMPASS 2003.16 Build 42B I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) I Site: Well: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska 1 Survey Map Map Vertical I MD Inc Azl TVD TVDSS +14/-S +EI -W Northing Easting DLS Section (ft) (?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °H00') (ft) Survey Tool Name 11,602.99 90.88 324.84 6,143.99 6,087.79 3,049.08 - 7,802.39 6,034,151.49 462,051.70 7.76 8,374.66 MWD +IFR2 +MS +sag (4) 11,634.79 90.50 323.56 6,143.60 6,087.40 3,074.87 - 7,820.99 6,034,177.35 462,033.21 4.20 8,401.77 MWD +IFR2 +MS +sag (4) I 11,666.24 90.70 323.06 6,143.27 6,087.07 3,100.08 - 7,839.78 6,034,202.64 462,014.52 1.71 8,428.84 MWD +IFR2 +MS +sag (4) 11,699.18 89.89 321.58 6,143.10 6,086.90 3,126.15 - 7,859.91 6,034,228.79 461,994.50 5.12 8,457.47 MWD +IFR2 +MS +sag (4) 11,731.14 89.95 320.74 6,143.15 6,086.95 3,151.05 - 7,879.96 6,034,253.76 461,974.56 2.63 8,485.57 MVVD+IFR2+MS+sag (4) I 11,764.74 89.85 319.25 6,143.21 6,087.01 3,176.78 - 7,901.56 6,034,279.58 461,953.06 4.44 8,515.42 MWD +IFR2 +MS +sag (4) 11,796.76 89.88 320.92 6,143.28 6,087.08 3,201.34 - 7,922.10 6,034,304.22 461,932.62 5.22 8,543.86 MWD +IFR2 +MS +sag (4) 11,828.02 90.05 319.08 6,143.30 6,087.10 3,225.29 - 7,942.19 6,034,328.24 461,912.63 5.91 8,571.63 MWD +IFR2 +MS +sag (4) I 11,877.21 91.14 318.95 6,142.79 6,086.59 3,262.42 - 7,974.45 6,034,365.50 461,880.52 2.23 8,615.72 MWD +IFR2 +MS +sag (4) 11,923.73 92.03 320.54 6,141.50 6,085.30 3,297.90 - 8,004.50 6,034,401.11 461,850.62 3.92 8,657.14 MWD +IFR2 +MS +sag (4) 11,972.44 90.41 321.07 6,140.47 6,084.27 3,335.64 - 8,035.28 6,034,438.97 461,820.00 3.50 8,700.09 MWD +IFR2 +MS +sag (4) I 12,020.17 89.77 321.45 6,140.39 6,084.19 3,372.87 - 8,065.14 6,034,476.31 461,790.29 1.56 8,742.01 MWD +IFR2 +MS +sag (4) 12,063.52 90.58 323.16 6,140.26 6,084.06 3,407.17 - 8,091.65 6,034,510.72 461,763.93 4.36 8,779.70 MWD +IFR2 +MS +sag (4) 12,117.29 89.77 322.38 6,140.10 6,083.90 3,449.98 - 8,124.18 6,034,553.66 461,731.57 2.09 8,826.24 MWD +IFR2 +MS +sag (4) I 12,152.67 90.55 322.20 6,140.00 6,083.80 3,477.97 - 8,145.82 6,034,581.73 461,710.05 2.26 8,857.00 MWD +IFR2 +MS +sag (4) 12,212.57 89.38 321.03 6,140.03 6,083.83 3,524.93 - 8,183.01 6,034,628.83 461,673.05 2.76 8,909.43 MWD +IFR2 +MS +sag (4) 12,258.08 90.26 321.06 6,140.18 6,083.98 3,560.32 - 8,211.63 6,034,664.33 461,644.58 1.93 8,949.48 MWD +IFR2 +MS +sag (4) I 12,308.31 89.22 320.19 6,140.40 6,084.20 3,599.14 - 8,243.49 6,034,703.28 461,612.88 2.70 8,993.86 MWD +IFR2 +MS +sag (4) 12,359.63 89.70 319.74 6,140.89 6,084.69 3,638.43 - 8,276.50 6,034,742.70 461,580.03 1.28 9,039.48 MWO +IFR2 +MS +sag (4) 12,407.33 89.52 318.40 6,141.21 6,085.01 3,674.47 - 8,307.75 6,034,778.86 461,548.93 2.83 9,082.21 MWD +IFR2 +MS +sag (4) I 12,455.47 89.34 318.54 6,141.69 6,085.49 3,710.51 - 8,339.67 6,034,815.02 461,517.17 0.47 9,125.56 MWD +IFR2 +MS +sag (4) 12,501.85 90.69 318.84 6,141.68 6,085.48 3,745.34 - 8,370.28 6,034,849.98 461,486.70 2.98 9,167.25 MWD +IFR2 +MS +sag (4) 12,549.95 89.74 317.06 6,141.50 6,085.30 3,781.06 - 8,402.50 6,034,885.82 461,454.63 4.19 9,210.76 MWD +IFR2 +MS +sag (4) 12,600.39 92.49 317.48 6,140.52 6,084.32 3,818.10 - 8,436.71 6,034,923.00 461,420.57 5.52 9,256.61 MWD +IFR2 +MS +sag (4) I 12,631.70 91.92 317.57 6,139.31 6,083.11 3,841.17 - 8,457.84 6,034,946.16 461,399.54 1.84 9,285.01 MWD +IFR2 +MS +sag (4) 12,664.00 91.87 318.74 6,138.24 6,082.04 3,865.22 - 8,479.38 6,034,970.29 461,378.10 3.62 9,314.16 MWD +IFR2 +MS +sag (4) 12,695.76 91.37 318.58 6,137.35 6,081.15 3,889.06 - 8,500.35 6,034,994.21 461,357.23 1.65 9,342.70 MWD +IFR2 +MS +sag (4) I 12,727.69 90.01 318.97 6,136.96 6,080.76 3,913.07 - 8,521.39 6,035,018.30 461,336.29 4.43 9,371.38 MWD +IFR2 +MS +sag (4) 12,761.32 89.52 317.89 6,137.10 6,080.90 3,938.23 - 8,543.70 6,035,043.55 461,314.08 3.53 9,401.67 MWD +IFR2 +MS +sag (4) 12,792.94 89.33 319.80 6,137.42 6,081.22 3,962.04 - 8,564.51 6,035,067.44 461,293.37 6.07 9,430.06 MWD +IFR2 +MS +sag (4) I 12,823.21 88.34 319.17 6,138.03 6,081.83 3,985.04 - 8,584.17 6,035,090.52 461,273.81 3.88 9,457.07 MWD +IFR2 +MS +sag (4) 12,856.63 87.39 321.22 6,139.28 6,083.08 4,010.70 - 8,605.55 6,035,116.26 461,252.53 6.76 9,486.70 M1ND +IFR2 +MS +sag (4) 12,888.97 88.04 319.33 6,140.57 6,084.37 4,035.55 - 8,626.20 6,035,141.20 461,231.99 6.18 9,515.34 MWD +IFR2 +MS +sag (4) I 12,920.88 88.14 320.10 6,141.63 6,085.43 4,059.88 - 8,646.82 6,035,165.60 461,211.47 2.43 9,543.75 MWD +IFR2 +MS +sag (4) 12,953.27 88.71 320.61 6,142.52 6,086.32 4,084.81 - 8,667.48 6,035,190.62 461,190.91 2.36 9,572.43 MWD +IFR2 +MS +sag (4) 12,985.46 89.68 319.11 6,142.97 6,086.77 4,109.42 - 8,688.22 6,035,215.30 461,170.27 5.55 9,601.07 MWD +IFR2 +MS +sag (4) I 13,017.27 89.45 318.91 6,143.21 6,087.01 4,133.43 - 8,709.09 6,035,239.40 461,149.50 0.96 9,629.58 MWD +IFR2 +MS +sag (4) 13,049.30 89.28 319.13 6,143.57 6,087.37 4,157.60 - 8,730.09 6,035,263.66 461,128.60 0.87 9,658.29 MWD +IFR2 +MS +sag (4) 13,081.70 88.71 319.02 6,144.14 6,087.94 4,182.08 - 8,751.31 6,035,288.22 461,107.48 1.79 9,687.31 MWD +IFR2 +MS +sag (4) I 13,112.24 88.39 320.53 6,144.91 6,088.71 4,205.39 - 8,771.03 6,035,311.60 461,087.86 5.05 9,714.49 MWD +IFR2 +MS +sag (4) 3/4/2010 3:18:37PM Page 7 COMPASS 2003.16 Build 428 I Halliburton Company Definitive Survey Report I Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -14 - Slot ODS -14 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -14 North Reference: True Wellbore: ODSK -14 Survey Calculation Method: Minimum Curvature Design: ODSK -14 KupB Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Au TVD TVDSS +N/ -S +El -W Northing Easting DLS Section ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 13,146.15 87.86 319.67 6,146.02 6,089.82 4,231.39 - 8,792.77 6,035,337.69 461,066.23 2.98 9,744.58 MWD +IFR2 +MS +sag (4) 13,178.84 87.65 321.50 6,147.30 6,091.10 4,256.63 - 8,813.51 6,035,363.01 461,045.59 5.63 9,773.45 MWD +IFR2 +MS +sag (4) I 13,210.20 88.39 320.08 6,148.38 6,092.18 4,280.91 - 8,833.32 6,035,387.37 461,025.88 5.10 9,801.10 MWD +IFR2 +MS +sag (4) 13,242.64 89.83 320.08 6,148.89 6,092.69 4,305.79 - 8,854.13 6,035,412.33 461,005.17 4.44 9,829.90 MWD +IFR2 +MS +sag (4) 13,274.38 89.27 321.66 6,149.14 6,092.94 4,330.40 - 8,874.16 6,035,437.02 460,985.24 5.28 9,857.88 MWD +IFR2 +MS +sag (4) I 13,308.10 89.46 320.85 6,149.51 6,093.31 4,356.70 - 8,895.27 6,035,463.40 460,964.25 2.47 9,887.50 MWD +IFR2 +MS +sag (4) 13,340.47 89.41 321.04 6,149.83 6,093.63 4,381.84 - 8,915.66 6,035,488.62 460,943.96 0.61 9,916.01 MWD +IFR2 +MS +sag (4) 13,371.95 88.87 319.41 6,150.30 6,094.10 4,406.03 - 8,935.80 6,035,512.89 460,923.92 5.45 9,943.93 MWD +IFR2 +MS +sag (4) I 13,402.04 88.85 318.95 6,150.90 6,094.70 4,428.80 - 8,955.46 6,035,535.73 460,904.35 1.53 9,970.85 MWD +IFR2 +MS +sag (4) 13,435.95 88.96 320.36 6,151.55 6,095.35 4,454.63 - 8,977.41 6,035,561.66 460,882.51 4.17 10,001.07 MWD +IFR2 +MS +sag (4) 13,466.68 88.78 318.76 6,152.16 6,095.96 4,478.02 - 8,997.34 6,035,585.12 460,862.68 5.24 10,028.48 MWD +IFR2 +MS +sag (4) I 13,499.18 88.24 319.65 6,153.00 6,096.80 4,502.61 - 9,018.57 6,035,609.80 460,841.56 3.20 10,057.56 MWD +IFR2 +MS +sag (4) 13,531.82 88.76 320.22 6,153.86 6,097.66 4,527.58 - 9,039.57 6,035,634.85 460,820.66 2.36 10,086.57 MWD +IFR2 +MS +sag (4) 13,564.08 88.04 320.55 6,154.76 6,098.56 4,552.43 - 9,060.13 6,035,659.77 460,800.20 2.45 10,115.12 MWD +IFR2 +MS +sag (4) I 13,595.33 88.51 322.45 6,155.70 6,099.50 4,576.87 - 9,079.57 6,035,684.29 460,780.86 6.26 10,142.49 MWD +IFR2 +MS +sag (4) 13,627.87 88.32 322.81 6,156.60 6,100.40 4,602.72 - 9,099.32 6,035,710.22 460,761.22 1.25 10,170.68 MWD +IFR2 +MS +sag (4) 13,661.68 87.10 324.70 6,157.95 6,101.75 4,629.96 - 9,119.29 6,035,737.54 460,741.36 6.65 10,199.62 MWD +IFR2 +MS +sag (4) I 13,693.77 85.86 323.59 6,159.92 6,103.72 4,655.92 - 9,138.05 6,035,763.58 460,722.71 5.18 10,226.95 MWD +IFR2 +MS +sag (4) 13,725.27 86.24 323.78 6,162.09 6,105.89 4,681.25 - 9,156.66 6,035,788.97 460,704.20 1.35 10,253.89 MWD +IFR2 +MS +sag (4) 13,757.98 87.49 323.82 6,163.88 6,107.68 4,707.60 - 9,175.95 6,035,815.40 460,685.02 3.82 10,281.85 MWD +IFR2 +MS +sag (4) I 13,790.30 87.95 325.42 6,165.16 6,108.96 4,733.93 - 9,194.65 6,035,841.81 460,666.43 5.15 10,309.26 MWD +IFR2 +MS +sag (4) 13,820.93 89.70 324.82 6,165.79 6,109.59 4,759.05 - 9,212.16 6,035,866.99 460,649.02 6.04 10,335.11 MWD +IFR2 +MS +sag (4) 13,852.00 89.70 324.82 6,165.95 6,109.75 4,784.45 - 9,230.06 6,035,892.46 460,631.23 0.00 10,361.43 PROJECTED to TD I I I I I I 3/4/2010 3:18:37PM Page 8 COMPASS 2003.16 Build 42B I I I HALLIBURTON ODSK - 5nerry Drilling Days vs. Depth I Rig Days 8500 11 1 1� 1 I (1 V 1 1 - 11 -1 -11 1 I 1111111111.111 11.11 �� 1111111111. halm. PIONEER 1111111111111111. 11.1111111 1111111111111111. 11.11111111 9000 I�IIIIIIIIIIII11., - 111011011111111u17'.111 - a � i , _ . ui.i.uiiii 1 Prognoses 11���� . , 11 5/ 8' Ca s n to .11111111.111111 ill; lL 8 654. , 11 00' MD 59ru.2 ND 11 011111111■11111110111<l i — Actual 1 111 111111.1111 II■11111111.11111111■111�1 _ _ - - - -___ -� 1 9500 ------ 11.Iuuuu.II 11.11111111.1111117.IIIt11111 11 - 11 - 11.111111.1 11■111111110l1111110111L11111 I in i _11_111111■ "� " .' 111111.111■ 11111 I I I . Start 3 1 /8 " "i Production Feb t1t , 2010 1oao�' MD, 51 rvD III11-10111�1111111011 110011111 10000 _ S)er SOL Arrives :' On-B.4,11„-14 ..1.6 Feb -2�' . 111117.111■ IIIIIII.III , - } ::::::m::. Lss P-' POsH 1. € - ' washout. Change BHA tc I 1 1 11. 111111 II Motcr Assy . MI I I , II 1 10500 Iri1111111•1 ■11111 - - - - -- I - - _ - -_ -__ I _________ .I - 1 ' HIIHIIUIIuIIIIHI _ ` - 111.11111111.10IIIIIN111 II j , I 11000 IIIIIIIIIIIIIIIHHIIIIII - - -- _ -_ -- ❑ 1 111111101111111111111111111 1 "CS 1, Pull Back ,o side track 11500 - ------ - - - - -- — -- - - -- 111 , Erd of OI SK -1• PB2 III . ! 1 I 11 III. •1111.a.11. 12000 - . -- --- - - - - ----- ---- - - - - -- I 1 1111111 U I 111I MINIM III1. I 1111111111111111111 II 's 12500 III I ; 111.11. 111111 = ' ___ 13000 __ -_ I I 111 i1111. 1i.111..1III. �. II 1 Run 4 1/2" Liner 13500 IHI _ lit HP 1 -111 14000 0 sll • .. ' t,, l i, 11 "I 1 1 ,11 H 11 1 1 114. 19 1 I 1 HALLI B U RTO N Sperry Drilling Surface Data Logging After Action Review 1 Employee Name: Tom Mansfield Date: 3/2/2010 Well: ODSK - 14 Hole Section: Production What went as, or better than, planned: ' Sample program went very well and samples were expedited in a timely manner. All equipment functioned well during this section. Difficulties experienced: Some problems with gas trap float system. Much improved since replacement of pulley 1 system and even with MPD pump running. Gas trap float has a small leak allowing moisture to enter the cavity. Recommendations: 1 The gas trap float should be inspected, drained, and if a hole is found, patched with tack weld or an adhesive coating. 1 Innovations and/or cost savings: None noted during this hole section. 1 1 1 1 1 1 1 1 HALLIBU TO I S perry Dr Uh,g ODSK -14 API 50- 703 - 20610 -00 Digital Data EMF & PDF Logs ADI End of Well Report Halliburton Log Viewer EMF Viewer I i. I ' 1
