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207-183
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: 09/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250919 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-35T 50283200970000 198161 8/10/2025 AK E-LINE PPROF T40899 BRU 223-34T 50283202060000 225059 8/17/2025 AK E-LINE CBL T40900 BRU 234-27 50283202070000 225065 9/12/2025 AK E-LINE CBL T40901 BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf T40902 KBU 11-08Z 50133206290000 214044 9/8/2025 AK E-LINE Perf T40903 MPU H-03 50029220630000 190088 9/9/2025 AK E-LINE SetPacker T40904 MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper T40905 MPU M-62 50029237440000 223006 8/31/2025 AK E-LINE LDL T40906 NCIU A-06 50883200260000 169050 8/25/2025 AK E-LINE TubingCut T40907 NCIU A-21A 50883201990100 225075 8/26/2025 AK E-LINE Perf T40908 ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey T40909 ODSN-01a 50703206480100 216008 9/8/2025 READ Caliper Survey T40910 ODSN-06 50703207150000 215098 9/9/2025 READ Jewelry Log T40911 PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM T40912 PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN T40913 TBU M-25 50733203910000 187086 8/31/2025 AK E-LINE Drift T40914 Please include current contact information if different from above. ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.22 13:22:50 -08'00' New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 � • . 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 b direct inspection of the file. ' 07 - O 3 Well History File Identifier Organizing (done) ❑ Two -sided III I111 I III ❑ Rescan Needed II I11111 I I RES N DIGITAL DATA OVERSIZED (Scannable) Col r Items: ❑ Diskettes, No. ❑ Map Grey Items: El Other, No/Type: ther Items Scannable by a Large Scanner LOSS oor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: yr p BY: Maria l 81 b 3 /s/ Project Proofing II Hill MI BY: Maria Date: 7/ i fi 3 - /s/ Scanning Preparation ! x 30 = c)... + 9' = TOTAL PAGES a rn � � (Count does not include cover sheet) BY: IIMat1 a) Date: 7/1 l Production Scanning III [1111 III I Stage 1 Page Count from Scanned File: a g5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: /s/ 7'/I8/J 1 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. I I III ReScanned II I IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc NNW DATA SUBMITTAL COMPLIANCE REPORT 7/9/2013 Permit to Drill 2071830 Well Name /No. 000GURUK KUP ODSK -33 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20562 -00 -00 MD 12055 TVD 6054 Completion Date 4/29/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR, DIR, Mudlogs, CTN, AND, PWD, RES, ADR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval 011 / Typ Med /Frmt Number Name Scale Media No Start Stop CH Received Comments pt Report: Final Well R Open 6/20/2008 End of Well Report, with PB1. Daily Summ, Daily Ops, Morning Report, Bit Record, Mud Report, Show Report, Survey Reports, Days vrs Dapth g Mud Log 2 Col 0 12055 Open 6/20/2008 Surface Data Combo Mud Log g Mud Log 2 Col 0 9730 Open 6/20/2008 PB1 Surface Data Combo Mud Log ;: Mud Log 2 Col 0 9730 Open 6/20/2008 PB1 Surface Data Engineering Log g Mud Log 2 Col 0 12055 Open 6/20/2008 Surface Data Engineering Log g Gas Analysis 2 Col 120 12055 Open 6/20/2008 Surface Data Pixlar Plot Gas Ratio ill Log Induction /Resistivity 2 Col 153 6053 Open 6/20/2008 TVD ROP, GR, PCG, DGR, GM, EWR, ADR, CTN, ALD Log / Induction /Resistivity 2 Col 153 12055 Open 6/20/2008 MD ROP, GR, PCG, DGR, GM, EWR, ADR, CTN, ALD Log Induction /Resistivity 2 Col 153 6072 Open 6/20/2008 PB1 TVD ROP, GR, PCG, DGR, GM, EWR, ADR, CTN, ALD Log•• Induction /Resistivity 2 Col 153 9730 Open 6/20/2008 PB1 MD ROP, GR, PCG, DGR, GM, EWR, ADR, CTN, ALD ED C Last" Induction /Resistivity 99 12055 Open 6/20/2008 TVD and MD logs in CGM, EMF and PDS graphics NNW DATA SUBMITTAL COMPLIANCE REPORT 7/9/2013 Permit to Drill 2071830 Well Name /No. 000GURUK KUP ODSK -33 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20562 -00 -00 MD 12055 TVD 6054 Completion Date 4/29/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N ED C Pdf C. 16485 Report: Final Well R 0 12055 Open 6/20/2008 End of Well Report, with PB1. Daily Summ, Daily Ops, Morning Report, Bit Record, Mud Report, Show Report, Survey Reports, Days vrs Dapth Well Cores /Samples Information: Sample Interval Set • Name Start Stop Sent Received Number Comments Cuttings 60 9705 1317 PB 1 Cuttings _. 6527 10398 1317 Final BoreHole ADDITIONAL INFORMATION Well Cored? Y / 1 v Daily History Received? N Formation Tops N Chips Received? 'f7' 1� P Analysis 4/1T Received? Comments: ---- Compliance Reviewed By: L O Date: ` ! lNJ'.-1'3 ill STATE OF ALASKA ALASKA IDAND GAS CONSERVATION COMMISSIO. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well El Plug Perforations ❑ Stimulate ❑ Other Replace ESP Performed: Alter Casing ❑ Pull Tubing Ei Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development El Exploratory ❑ ° 207 -183 3. Address: 700 G Street, Suite 600 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99501 50- 703 - 20562 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 355036 .4ODSK -33 9. Field /Pool(s): Oooguruk - Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 12,055 feet Plugs measured N/A feet true vertical 6054 feet Junk measured N/A feet Effective Depth measured 12,055 feet Packer measured See Below feet true vertical 6054 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A EEn Surface 3133' 9 -5/8" 3173' 3052' 5750 psi 3090 psi Intermediate 9756' 7" 9793' 6070' 7240 psi 5410 psi Production R Liner y r� Open Hole �Y Perforation depth Measured depth 9793' - 12,055' feet 6 ! Q 1 Open Hole True Vertical depth 6070' 6054' feet l Cos. ltit' arn Tubing (size, grade, measured and true vertical depth) 3 -1/2 ", L -80 9.2 #, TC II 4111 9010D 6018' TVD Packers and SSSV (type, measured and true vertical depth) MD / @ 2065' 2030'TVD 266665 2" x 7" Packer MD / 5' MD / 2559' TVD 11. Stimulation or cement squeeze summary: Tubing Punch, 48 holes at .42 ", 4 spf, 0 degrees phasing Intervals treated (measured): 4050' - 4062' Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1887 793 2541 1132 300 Subsequent to operation: 3056 3773 3237 1517 869 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil • Ei Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -397 Contact Tim Crumrine, 343 -2184 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Tim Crumrine Title Staff Completions Engineer Signature Phone 343 -2184 Date 5/4/2011 RBDMS MAY 0 9 1011 ' Form 10 -404 Revised 10/2010����� Submit Original Only P I O N E E R O,tions Summary Report - State Well Name: ODSK -33 NATURAL REStJRCES Well Name: ODSK -33 Contractor: NABORS DRILLING Rig Number: 19AC Job Category: WORKOVER Start Date: 3/20/2011 End Date: Start Depth Foot/Meters pens Last Start Date End Date MKS) (f) Mud (U) Summary 12/10/2010 12/11/2010 12,055.0 Bleed PW line to 0 psi. All gas. 5 hours later pressure had risen to 300 psi. Complete HES RU. MU and RIH with tubing punch gun #1 (6'). RIH and tie in using pipe tally and CCL. Position and shot qun #1 from 4,056' - 4,062' at 4 spf 0 degrees phasing oriented to the low side of the tubing using decentralizer and magnet. Good indication that gun fired. WHP rises to 1600 psi. POOH. All shots fired. MU and RIH with gun #2. Tie in and punch tubing from 4,050' - 4,056' at 4 spf. ^ Good indication that gun fired with minimal change in WHP. POOH and confirmed all shots fired. Note the total interval punched is 4,050' - 4,062'. Shot at 4 spf (total of 48 holes at 0.42 "). All shots are 0 degree phasing oriented to the low side of the tubing with magnet and decentralizer. RD HES and POP well at 1300. Final SIWHP - 1823. 3120/2011 3/21 /2011 12,055,0 8.40 Move rig pits up to subs and square same. RU same. RU slick line unit, and lubricator - pressure test to 1200 psi - Good test. Perform slick line runs as follows: Run 1 - RIH and set catcher sub in X nipple at 4,001' wim. Run 2 - Rift and pull QV from GLM at 3,516' w lm. Run 3 - RIH and pull catcher sub from X nipple at 4,001' wim. RU circulation manifold to IA and tubing while cleaning pits and taking on filtered sea water. Bull head filtered sea water down IA and down tubing to bring well to static condition, 500 bbls (1.5x annular volume) down IA at 6 bpm. Pump 200 bbls (2x tubing volume) down tubing at 6 bpm. h 11' 475 psi, and FCP 200 psi. Monitor wen 20 min - IA= 200 psi, TP= 200 psi. Bull head filtered sea water down IA and down tubing to bring well to static condition. 550 bbis (1.75x annular volume) down IA at 6 bpm. Pump 25 bbl hi-vis pill and chase wiith 200 bbls (2x tubing volume) down tubing at 8 bpm. FTP 650 psi, and FCP 50 psi. Monitor well for 20 min IA= 0 psi, TP= 0 psi, RIH and set catcher sub in X nipple at 4,001' win. Pump 10 bbls down IA every 1/2 hour while slick lining, FCP= 450 psi, FTP= 750 psi. Bull head filtered sea water down IA to ensure IA was fluid packed. 100 bbls at 2 bpm FCP 2100 psi, and FTP 2300 psi. Monitor pressures - falling. RIH and set dummy valve in upper GLM at 3,516' wim. ICP= 300 psi, ITP= 600 psi. Bleed down IA to 0 after seating dummy valve - bled back 2 bbis. Monitor well for 15 min, FCP= 0 psi, FTP= 550 psi. RIH and pull catcher sub from X nipple at 4,001' wim. Pump 10 bbis down tubing every 1t2 hour while slick lining. FCP= 0 psi, FTP= 550 psi. Bull head filtered sea water down tubing to bring well to static condition. Pump 25 bbl hi-vis pill and chase with 200 bbls (2x tubing volume) down tubing at 8 bpm. FCP 0 psi, and FTP 0 psi. Monitor pressures for 15 min - static, and close SSSV. 3/21/2011 3/22/2011 12,055.0 8.45 Shut in well with SSSV, PW, install BPV in tubing hanger. ND production tree. Terminate SSSV and PW control lines. Install test dart on BPV Nipple up ROPF Lest BOPF per AOGCC Permit n To Drill. Test with 2 -7/8" and 3-1/2" test joint to 250 psi low and 3500 psi high. Test annular w/ 2- J 7/8" test joint to 250 psi low and 2500 psi high. Test all floor valves to 250 psi low and 3500 psi J high. Test upper and lower IBOP valves to 250 psi low, 3500 psi high. Test 14 choke manifold valves to 250 psi low, 3500 high. Initial system pressure 3000; 2000 after closure, 200 psi= 25 sec. Full pressure 1 min 30 sec. All tests charted and all tests held for 5 min. Tests witnessed by AOGCC rep Chuck Scheve. Pull test dart from BPV. Attempt to pull BPV from tubing hanger - pressure trapped under BPV. Close blind rams and pump thru BPV. Pumped 15 bbls hi -vis pill followed by 75 bbls filtered sea water. ICP= 400 psi, and FCP= 50 psi. Pull BPV from tubing hanger and fill stack and tubing with 23 bbls. Rig up ESP Tec -wire, SSSV, and PW control line sheave and spool. RU 3 -1/2" tubing equipment. Perform in -depth step by step safety meeting with all personnel involved in completion procedure. MU 4" landing joint, verify 0 psi on IA, back out LDS on tubing hanger, unseat tubing hanger with 148k and work pipe until packer released at 150k. Reciprocate pipe in attempt to wear out packer element - unable to slack off once the hanger cleared the BOP stack. Reconnect to ESP Tec -wire, SSSV and PW control lines. LD landing joint and tubing hanger. 3122/2011 3/23/2011 12,055,0 8.45 Perform in -depth step by step safety meeting with all personnel involved in completion procedure. POOH with completion f19,516' t/5,053' pumping 14 bbls into IA every 30 min. Fill hole with 200 bbls down IA, Lay down WFT packer and change out ESP Tec -w re spat. P0011 with completion f/5,553 t/108' pumping 14 bbis into IA every 30 min. Lay down ESP pump and clear rig floor of all completion clamps, and change out ESP spool. Fill hole with 128 bbls once out the hole. Pump 10 bbis every 1/2 hour down IA, 3/23/2011 3/24/2011 12,055.0 8.50 Finish laying down ESP assembly. Slip and cut drill line. PU and make up ESP assembly f/ surface t/114'. Install motor lead and I -wire. Splice ESP cable to motor lead, test same, and secure motor lead. RIH with 3.5" L -80 9.2# TC -II completion string f/114' t14,183'. Test ESP cable at 4,183' - no reading on ESP discharge temperature and pressure. Trouble shoot surface equipment - problem downhole. Prep rig floor and t;pooling unit for pulling out the hole. POOH with completion f/4,183' t/3,814'. Page 1/2 Report Printed: 5/5/2011 P I O N E E R O.ations Summary Report - State • Well Name: ODSK -33 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Slate End Date (alka) (It) Mud tom) Summary 3/24/2011 3/25/2011 12,055.0 8.50 POOH with completion f/3,814' 1/114'. Lay down ADV and test ESP cable - still having same problem. Troubleshoot communication problem with ESP - found that Tec -wire was broken and 17' of it was left in hole as well as 1 SS band. Lay down ESP and motor f/97' t/ surface. RU slickline unit and PU tool string. Run 1- RIH w/ 5.8" wire grab 1/9,394' wlm - retrieve 1 band & 5' s✓ of wire. Run 2- RIH w/ 5.8" wire grab 1/9,400' wlm - dry run. Run 3 - RIH w/ 5.8" wire grab 1/9,450' wlm - dry run. Run 4 - RIH w/ 5.883 junk basket 1/9,394' wlm - retrieve 4" piece of wire. Run 5 - RIH w/ 5.883 junk basket 1/9,400' wlm - dry run. RD slickline unit and install wear bushing. 3/25/2011 3/26/2011 12,055,0 8.50 PU fishing BHA #1 and TIH ft surface 1/9,775'. Rotate spear on bottoms 6 revolutions. POOH V9,775` t/ surface. PU fishing BHA #2 and TIH f/ suface 1/9,885'. POOH 1/9,885' t/ surface and lay down BHA. Test choke manifold while pulling out the hole. AOGCC rep Bob Noble waived witness of test. 3/26/2011 3/27/2011 12,055.0 8.50 Remove wear bushing and install test plug. Test BOPE per AOGCC Permit to drill. Test with 3- 1 /2" test joint to 250 psi low and 3500 psi high. Test annular w/ 3 -1/2" test joint to 250 psi low and 2500 psi high. Test all floor valves to 250 psi low and 3500 psi high. Test upper and lower IBOP valves to 250 si low, 3500 psi high. Test 14 choke manifold valves to 250 psi low, 3500 P P 9 P high. Initial system pressure 3000; 2100 after closure, 200 psi= 24 sec. Full pressure 1 min.37 sec. All tests charted and all tests held for 5 min. Test witness waived by AOGCC rep Bob Noble. RU ESP wire spool, SSSV and PW control line spools. PU and MU ESP assembly f/ surface 1/97'. PU and MU ADV assembly 1/97' 1/114'. Install motor lead and 1 -wire. Splice ESP cable to motor lead, test same, and secure motor lead. RIH with 3.5" L -80 9.2# TC -II completion string f/114' 1/5,719'. 3/27/2011 3/28/2011 12,055.0 8.50 RIH with 3.5"1-80 9.2# TC-tl completion f/5,719'119,460'. PU and MU tufting hanger. Make ESP, PW, and SSSV control line penetrations thru hanger. Splice same to monitor while landing. Land hanger f/9,460' 1/9,495' - verify same and lock down hanger. Test upper and lower hanger seals to 5000 psi, chart 10 min - Good test. ND trip nipple. RU slick line unit and held prejob safety meeting, RIH and set ball and rod at 5,721' wlm. Fill tubing with 7 bbts, observed bubbling from tubing, no gas detected at wellhead, IA on vacuum. Close SSSV and install BPV in tubing hanger. 3/28/2011 3/29/2011 12,055.0 8.50 NU trip nipple. Open BPV poppet and monitor well - bubbled for 5 min. No gas detected. • Determined bubbling was air breaking out while pumping down tubing. Remove BPV and monitor well - static for 30 min. Install BPV back in tubing hanger. Nipple down BOPE and drilling riser. Make ESP wire, PW and SSSV control line penetrations thru well head and terminate same. Pull BPV valve from tubing hanger and install TWC. Install and NU production tree. Test tree and void to 5000 psi for 10 min on chart - Good test. Pull TWC and open SSSV= 0 psi observed. RU circulation manifold to tubing and test lines to 4000 psi - Good test. Pressure up to set WFT Packer and increase pressure to 3500 psi. Held tubing test to 3500 psi 30 min on chart - Good test. Apply 500 psi to tubing and pressure up on IA in 5 to 2500 psi held 30 min on chart - Good test. Standby and perform rig maintenance while waiting on slickline unit that is working on ODST -46i. 3/29/2011 3/30/2011 12,055.0 8.50 Standby and perform rig maintenance while waiting on slick line unit that is working on ODST- 46i. RU slick line unit, and lubricator test same to 1000 psi. Held PJSM. Retrieve ball and rod from 5,721' win. Run 2- Retrieve RHC-M plug body from 5,728' wim. POOH and RD slick lute unit. Standby and perform rig maintenance while waiting on coil tubing unit to finish working on ODST -45A, so that Nabors 19AC can get over ODSK-41 to perform ESP pump change. Page 2/2 Report Printed: 5/5/2011 PIONEER Current Schematic - State Well Name: ODSK -33 NATURAL RESOURCES HORIZONTAL - Sidetrack 1, 5/6/2011 8:27:12 AM Well Attributes Vertical schematic (actual) API /UWI Field Name Well Status Total Depth (ftKB) 50- 703 - 20562 -0000 000GURUK UNIT DRILLED 12,055.0 Casing Strings Conductor, 153.0ftKB Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) ® 0 .. Conductor 16 14.670 39.0 153.0 X -56 Welded 102.63 Casing Components Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 1 -1 Conductor Shoe 39.0 16 14.670 Surface, 3,172.7ftKB Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) Surface 9 5/8 8.835 39.6 3,172.7 L -80 40.00 I Casing Components ' t� Top (TVD) e Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com I 2 -7 9 5/8" Surface Casing Shoe 3,171.0 9 5/8 T Intermediate, 9,793.4ftKB Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) ® Intermediate 7 6.276 37.7 9,793.4 6,041.7 L -80 Buttress 26.00 Thread Casing Components Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 3 -8 Weatherford Reaming Shoe 9,790.4 6,041.4 7 Weatherford Reaming Shoe Tubing Strings 2 -8 Tubing Description String M... ID (in) Top (ftKB) Set Depth (f... Set Dept... Wt (lb/ft) Grade Top Thread Tubing- Recompletion 3 1/2 2.992 0.0 9,496.8 6,004.6 9.20 L -80 TC -II Tubing Components Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 2 -2 Vetco Grey tubing hanger 34.5 34.5 10 2.950 13/16 2 -8 HES WellStar TRSV w 2,064.9 2,043.2 4.65 2.313 2.313 "X" profile 2 7/8 IBT - M 12 -141 2 -14 2 7/8 X 1.5" 9Cr GLM 2,565.4 2,511.2 5 1/2 2.635 w /dummy w/ IBT -M BxP 2 -18 HES 2.313 "X" Nipple 2 7/8 2,614.8 2,555.1 3.24 2.313 IBT -M 2 -22 WFT 2 7/8 x 7" Hydrow -II 2,665.0 2,600.1 6.002 2.359 ESP feed thru Pkr w/ Gas 12-18 2 -29 2 7/8 X 1.5" 9Cr GLM 5,637.5 4,628.0 5 1/2 2.635 w /dummy w/ IBT -M BxP 2 -33 HES 2.313 "X" Nipple 2 7/8 5,718.3 4,660.1 3.34 2.313 IBT -M BxP w /RHC -M Plug 2 22 2 -38 Auto - Diverter Valve 9,392.0 5,986.6 4 1/2 2 -40 Welllift Discharge Gauge 9,397.1 5,987.4 4 1/2 2 -41 Centrilift ESP Assembly 9,399.5 5,987.8 5.38 I 1 EN 3 -8 Page 1/1 Report Printed: 5/6/2011 • • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) \ °\1‘ -P Z 7 I 6 0 Sent: Monday, April 11, 2011 11:32 AM 'Clark, James' Cc: DOA AOGCC Prudhoe Bay Subject: RE: SVS Testing on recent workovers Provide a detailed timeline of K -33 from startup (3/30/11) to present. Indicate when well was SI for "maintenance and adjustments ". Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Clark, James [mailto:James.Clark ©pxd.com] Sent: Sunday, April 10, 2011 7:33 PM To: DOA AOGCC Prudhoe Bay Subject: SVS Testing on recent workovers Gentlemen, We recently performed rig workovers to replace the ESP's in K -33 and K -41 at Pioneer ODS. K -33 was initially brought online on March 30 and there were a few instances where the well was shut in for maintenance and adjustments. An initial function test was performed on the SSV and the ScSSSV but we have not conducted the official performance test as of yet. I apologize for the oversight on not getting the performance test done in a timely manner. K -41 will be ready to POP later this evening and we would like to give it a few days to stabilize before testing the SVS. My question to you is would you like to witness the SVS testing on both wells two days from now or do you want us to do the performance test on K -33 sooner than waiting an additional two days. Please advise as to how you wish for us to proceed. Thanks Jimmy Clark Oooguruk Production Supervisor Pioneer Natural Resources Office: 907 - 670 -6530 Office 2 : 907 - 670 -6602 M B L: 850 - 865 -3538 Fax : 907-670-6610 james.clark4pxd.com Oooguruk. ProdSupervisorepxd.com 4/11/2011 • Page 2 of 2 II Jimmy Clark Oooguruk Production Supervisor Pioneer Natural Resources Office: 907 - 670 -6530 Office 2 : 907 - 670 -6602 M B L: 850 - 865 -3538 Fax : 907-670-6610 james.clark(cr�pxd.com Oooguruk.ProdSupervisor @pxd.com This email was sent on 4/10/11 at 7:32 PM by Clarkj. 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. 4/11/2011 • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 24, 2011 9:56 AM To: 'Delmonico, Joe' Cc: Tirpack, Robert; Johnson, Vern; Crumrine, Tim Subject: RE: ODSK -33 RWO Sundry #310 -397 , rD • 207-- / p-3 Joe, Thanks for the update... the change will be noted and put in our well file. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Delmonico, Joe [mailto:Joe.Delmonico @pxd.com] Sent Thursday, March 24, 2011 9:49 AM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert; Johnson, Vern; Crumrine, Tim Subject. ODSK -33 RWO Sundry #310 -397 Guy, As per our conversation Pioneer will not be doing a clean out run or running a liner into the open hole on ODSK- 33. This was a contingency option if we were forced to pick up drill pipe and fish the packer. Regards, Joe Delmonico Jr. Drilling Engineer Pioneer Natural Resources Alaska Office: 907 -343 -2182 Mobile: 907 -980 -7690 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. 3/24/2011 w • • b r 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 Tim Crumrine Staff Completion Engineer Pioneer Natural Resources Alaska, Inc. ei 0,7, i ro-3 700 G Street, Suite 600 �, Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSk -33 Sundry Number: 310 -397 Dear Mr. Crumrine: 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 this / day of December, 2010. Encl. IONEER • NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 RECEIVED December 01, 2010 DEC 0 2 ZOO State of Alaska /kiosks Qii & Gas Cons• Commission Alaska Oil and Gas Conservation Commission AnCherift 333 West 7 Ave, Suite #100 Anchorage, AK 99501 RE: Application for Sundry to Modify Completion, ODSK -33 Pioneer Natural Resources Alaska is requesting Sundry approval for the workover of • the ODSK -33 production well. Please see the attached Form 10 -403 and proposed rig workover plan. Two changes are proposed to the ODSK -33 well. First, the well is currently completed with an open hole lower completion; and Pioneer would like to run a 4 -1/2" liner in the well to a depth of 11,150 feet measured depth. The second proposed change is to the Electric Submersible Pump (ESP). The ESP currently installed is ' undersized. The proposed workover will install a larger ESP to allow much higher well rates. A new completion string will be run consisting of 3 -1/2" x 2 -7/8" tubing. Jewelry will remain the same size and in the same location. Sincerely, Tim Crumrine, P.E. Staff Completion Engineer Attachments: Form 10 -403 Supporting Sundry information cc: ODSK -33 Well File • c/ ,io RECEIVED I- �.t -oBEC 0 2 2010 STATE OF ALASKA ,1, ALASKA OIL AND GAS CONSERVATION COMMISSION Oil & Gas Cons. Commission APPLICATION FOR SUNDRY APPROVALS Andgrage 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ig " Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 ' Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Run Liner & Replace ESP 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development 0 . Exploratory ❑ 207 -183 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99501 50- 703 - 20562 -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: ODSK - 33 • Spacing Exception Required? Yes ❑ No El 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): 12,055' ' 6054' • 12,055' 6054' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3133' 9 -5/8" 3173' 3052' 5750 psi 3090 psi Intermediate 9756' 7" 9793' 6070' 7240 psi 5410 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 3 -1/2 ", 9.3# / Tubing Grade: Tubing MD (ft): Open Hole 9793' - 12,055' Open Hole 6070' - 6054' 2 -7/8 ", 6.5# L -80, IBT -M 3500' / 9566' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ScSSSV; 7" x 2 -7/8" Packer 762' MD / 762' TVD; 4021' MD / 3744' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 12/28/2010 Commencing Operations: Oil 0 • 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 Tim Crumrine, 343 -2184 Printed Name Tim Crumrine, 343 -2184 Title Staff Completion Engineer Signature > Phone Date Prepared By: Kathy Campoamor, 343 - 2183 i " / 12/1/2010 ________.- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .31.o - 3 Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 114 3Sbv es,.... BO / e S f- 4 s 4 •► n T s i` (*------- ''".-^`) Subsequent Form Required: //'� - L 0 L/ J a ,' APPROVED BY Approved by (,� / COMMISSIONER THE COMMISSION Date: i1 2. ) '/o d ( Submi in Duplicate Form 10-403 Rev S 1/2010 EC 10 7xe. , R 1G1 JAL • • ODSK -33 Proposed Rio Workover Summary Pre Rig: 1. SI ODSK -33 1 - 3 days prior to MIRU. 2. Tubing punch 2 -7/8" tubing using 4SPF (45 holes total) Tubing Punch from 4060' MDrkb to i / 4071' MDrkb. 3. Pump filtered (20 NTU) seawater down the IA. Pump an annulus volume down to the production packer —121 bbls through the upper GLM at 2 -3 bpm fluid packing the annulus. Record the pump pressure and WHP during bullhead. 4. Pump 10 bbls his vis seawater chased with —44 bbls of filtered (20 NTU) seawater at 2 -3 bpm to sweep gas from the tubing. Close the ScSSSV and bleed pressure off the tubing. a. Record pump pressure, IAP and WHP during the bullhead. Should the well go on a vacuum during pumping please note the bbls away at this point. 5. Monitor WHP and IAP via operators daily reading schedule until rig moves on location, Prep ✓ surface equipment for rig move. Bleed trapped gas off the IA as needed. MIRU Nabors 19AC: 1. Ensure that the ScSSSV is holding and there is no pressure on the tubing. 2. Install a BPV into the tubing hanger profile. a. Barriers are (a minimum of 2): ✓ i. Tubing side 1. Kill weight fluid to formation 2. ScSSV closed 3. BPV in the tubing hanger ii. Annulus 1. Kill weight fluid above the packer 2. Packer with closed gas vent valve 3. Wellhead 3. Test BOP's as per standard AOGCC requirements. With low (250 psi) and high (3500 psi) 5 minutes each. State will need to be notified to witness test. 4. Have FOSV available and drifted to 2.25" minimum to ensure e-line cutting tools can pass through I.D � KeJ ✓ti / 5. Pull to release packer a. Gas may be present below the packer, so be looking for a gas bubble once the packer is released. 6. Pull 2 7/8" 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. 7. Joint with FOSV should be in the mousehole as a contingency. 8. PU used 6 1/8" bit and 4" DP for clean -out run. 9. RIH with bit to 11150' MD. 10. Circulate bottoms up, if possible and POH slowly so as not to swab well. ■ Pagel of 2 PIONEER NATURAL RESOURCES ALASKA • 11. PU 4 '/" liner with guide shoe and pelf pups every 30'. MU rotating liner hanger assembly with running tool. RIH with lower completion, liner shoe is planned to be set at 11,150' MD. 12. Set liner hanger /packer. 13. PU & RIH 3.5 ", 9.3 ppf, L -80, TC -I1 tbg consisting of: a. ESP b. X nipple w/ RHCM plug body c. Vanoil 2 7/8" GLM d. X nipple one joint below packer e. Packer f. X nipple one joint above GW Packer g. Vanoil 2 7/8" GLM h. TRSSV 14. PU LJ w/ Production Tubing Hanger. 15. Land Tubing Hanger. RILDS for Tubing Hanger. Test both the upper and lower Tubing Hanger body seals to 5000psi. Set BPV. • 16. ND BOPE 17. NU Vetco Gray Production ESP X -mas Tree 18. Monitor SCSSSV control line pressure to ensure adequate hold open pressure during roller stem ball running. Set packer' annulus to 2500psi. Post Rig: 1. MIRU HES Slickline 2. Retrieve ball /rod assy from RHCM plug body 3. RIH with kick over tools and pull dummy from lowest GLM. Run SO with 0.625 orifice back in mandrel. 4. RIH w/ 2 -7/8" GS to X nipple, retrieve RHCM plug body 5. Rig down slickline 6. Function Test TRSSSV Page 2 of 2 PIONEER NATI IRAL RES(IURGES ALASKA ODSK -33 Produ Well Completion with i bing Punches Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal �� Vent Valves Control Line 16" Conductor ` 153' MDrkb / 153' NDrkb 3 -1/2 ", 9.3# L -80 IBT -M to 3500' MD \---------- 2 -7/8" ScSSSV, 2.313" ID @ 762' 2 -7/8" GLM, 1.5" FO -2, DV @ IF 3510' MDrkb / 3333' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID ' 3173' MDrkb / 3052' TVDrkb __.- -- X Nipple, 2.313" ID @ 4002' MD ■ •4 S 2 7" x 2 -7/8" Packer @ 4021' MDrkb / 3744' TVDrkb ■ IN._, f f ------\ X Nipple, 2.313" ID w RHC Tubing Punches to Allow Flow via ,/� f Profile @ 4038' MD Tubing / Annulus Combination 2 -7/8" GLM, 1.5" F0-2, DV © 8010' MDrkb / 5514' TVDrkb 2 -7/8 ", 6.5# L -80 IBT -M ESP Cable O ____________ 2 -7/8" Durasleeve Sliding Sleeve (open), 2 ID @9429' MDrkb XN Nipple 2.205" ID Nogo @ 9443' MDrkb Centrilift ESP © 9556' MDrkb Estimated Top of Cement @ 8793' MD 1 ... 6-1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID ` .i 9793' MDrkb / 6070' TVDrkb 12055' MDrkb / 6054' TVDrkb VDate: Revision By: Comments 04/24/08 JDF OH Completion , ODSK -33 Producer Well Schematic PIONEER ODSS 33 Proposed Workovit Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal r ze 1 Vent Valve Control Line 16" Conductor 158' MDrkb / 158' TVDrkb 3 -1/2 ", 9.3# L -80 IBT -M to 3500' MD 4, . 2- 7 0 ScSSSV, 2.313" ID @ 762' : •..4 i 2 -7/8" x 1.5" GLM @ 3510' MDrkb / 3333' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3173' MDrkb / 3052' TVDrkb X Nipple, 2.313" ID @ 4002' MD • S 7" x 2 -7/8" Packer @ 4021' MDrkb / 3744' TVDrkb ■ X Nipple, 2.313" ID Profile @ 4038' MD 3 -1/2 ", 9.2# L -80 IBT -M 2 -7/8" x 1.5" GLM @ 8010' MDrkb / 5514' TVDrkb ESP Cable ■ XN Nipple 2.205" ID Nogo @ 9443' MDrkb OOO Automatic Divert Valve Centrilift ESP © 9566' MDrkb Estimated Top of Cement @ 8793' MD rh .a c 7 ", 26# L -80 BTC -M, 6.276" ID 9793' MDrkb / 6070' TVDrkb inn zci- 0 0 0 0 0 0 0 0 0 Open ` O 0 0 0 0 0 0 0 Hole Y O 0 0 0 0 0 0 0 ci in LO 0 4- 12.6 #, L -80 Liner 11,150' MDrkb / 6,064' TVDrkb c\i PIONEER Date: Revision By: Comments 04/24/08 JDF OH Completion 11/29/10 KLC Proposed Completion Modification NATURAL RESOURCES ALASKA 11/30/10 TWC TWC Edits ODSK -33 Proposed Workover Page 1 off • Maunder, Thomas E (DOA) From: Williams, Theresa [Theresa.Williams @pxd.com] Sent: Monday, February 16, 2009 6:19 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: RE: K -33 IA Pressure Jim, Thanks for the comments. The operating guidelines I sent are a preliminary document to insure we don't exceed annular limits. We're in the process of refining them and will address your comments as they evolve. I believe we'll be getting 1400 psi gas from CPAI, but since gas lift is intended to be used only as a backup for a failed ESP or during initial well cleanup as needed it hasn't been our main area of focus. All of the items below will be addressed in our final document. Regards, M Theresa Williams Pioneer Natural Resources, Alaska Staff Operations Engineer (907) 343 -2104 Theresa. W i f l iams@pxd.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, February 09, 2009 9:47 AM To: Williams, Theresa Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: RE: K -33 IA Pressure Thank you for the explanations. Couple comments regarding the Pioneer well operating guidelines for Oooguruk Gas Lifted Producers What is gas lift pressure planned for Oooguruk? I would infer from guide that it is 1500psi (self imposed limit placed on IA by Pioneer). Why would you bleed IA (gas lift pressure) to 1000psi when there is an indication of communication (unless you are intentionally shutting in the well /gas lift gas to the well)? injection Wells AOGCC does not recognize allowable annuli pressures and no allowable bleed frequency for annuli pressures in in1ection wells. Instead, Rule 7 in AIO 33 and AIO 34 require you to notify the Commission of any indication of pressure communication or leakage in any annulus of an injection well, regardless of the pressure. Other items that should be addressed in the well operating guideline: - bleeding annuli pressures prior to restart of shut in wells; check Rule 10 (Annular Pressures) in CO 596 and CO 597; - upper operating pressure limit (45% of MIYP) for producers; triggers shut in of the well and Commission approval to restart; - maintaining imposed OA pressure (1000psi) in a well with open shoe (implication of depressed OA fluid level; fluid packing annuli); - managing annulus fluid levels and pressure changes due to significant temperature differentials to avoid \- 9/2/2009 �`-- • Page 2 of, collapse risk; e.g., converting from producer to injector Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 om: Williams, Theresa [mailto:Theresa.Williams @pxd.com] t: Wednesday, February 04, 2009 4:18 PM To: • egg, James B (DOA) Cc: under, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subje ,• RE: K -33 IA Pressure Jim, Thanks for you •atience and guidance on future notifications. It's my g. • 1 to not to have any more, but occasio Ily things do happen. My replies are in fuchsia bel • . Please call if you have any questions. M Theresa Williams Pioneer Natural Resources, A , ska Staff Operations Engineer (907) 343 -2104 Theresa. W i I Iiams@pxd.com From: Regg, James B (DOA) [mailto:jim.reg• ' alas -goy] Sent: Friday, January 16, 2009 2:32 PM To: Williams, Theresa Cc: Maunder, Thomas E (DOA); Gilroy, Jim; I, J. -y Subject: RE: K -33 IA Pressure Thank you for the notification. For fut - notifications, ple= e provide (1) current wellbore schematic, and (2) plot of the previous 90 days tubing, inner .nd outer annuli (TIO) , ressures - example TIO plot attached. Couple questions from the notif ation - 1) I'm a little confused with e well completion, which appears to be .et up for ESP artificial lift and a contingency gas lift capability (dumm alves installed ?). What is the packer vent ive referenced? What is it used for and why? A packer ven alve (PVV) is a fail -safe device in the pac :r that's a means of producing gas up the IA inste•• of the tubing. The reason for doing so is to pr: vent eventual gas -lock of the ESP. The PVV s a part of the well design for our producers and wa- included since WAG injection is one of o future options. We would be happy to meet with you an. •r Tom if you'd like to discuss rther. Valves and control line are shown on a proposed completion sc -matic in our well file but no descris e information has been provided 2 at is the status of the packer vent valve? The valve is dosed. We had an E5D • the well and when he 555V was opened back up the PVV was inadvertently opened, too. That was ' oticed fairly 9/2/2009 • • Page 1 of 3 Regg, James B (DOA) From: Williams, Theresa [Theresa. Williams @pxd.com] � �q Z,� Sent: Wednesday, February 04, 2009 4:18 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject RE: K -33 IA Pressure g\O 7- 1 3 Attachments: Pioneer Well Operating Guidelines.doc Jim, Thanks for your patience and guidance on future notifications. It's my goal to not to have any more, but occasionally things do happen. My replies are in fuchsia below. Please call if you have any questions. M Theresa Williams Pioneer Natural Resources, Alaska Staff Operations Engineer (907) 343 -2104 Theresa. W i l iamse pxd.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, January 16, 2009 2:32 PM To: Williams, Theresa Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: RE: K -33 IA Pressure Thank you for the notification. For future notifications, please provide (1) current wellbore schematic, and (2) plot of the previous 90 days tubing, inner and outer annuli (TIO) pressures - example TIO plot attached. Couple questions from the notification - 1) I'm a little confused with the well completion, which appears to be set up for ESP artificial lift and a contingency gas lift capability (dummy valves installed ?). What is the packer vent valve referenced? What is it used for and why? A packer vent valve (PVV) is a fail -safe device in the packer that's a means of producing gas up the IA instead of the tubing. The reason for doing so is to prevent eventual gas -lock of the ESP. The PVV is a part of the well design for our producers and was included since WAG injection is one of our future options. We would be happy to meet with you and /or Tom if you'd like to discuss further. Valves and control line are shown on a proposed completion schematic in our well file but no descriptive information has been provided 2) What is the status of the packer vent valve? The valve is closed. We had an E5D on the well and when the 555V was opened back up the PVV was inadvertently opened, too. That was noticed fairly quickly and it was closed, but the IA pressure wasn't bled down low enough because of the misconception that the upper limit on the IA was 2500 psi. This misconception has been correct. ✓ Email below indicates that it was not completely closed, and based on description, it could be interpreted that IA pressure is being maintained with active management (pressure bleeds); is that correct or have you confirmed 2/5/2009 • Page 2 of 3 the valve is now closed? The PPV is confirmed close and the IA pressure is not being maintained with active management, nor has it ever been. 3) What is Pioneer's policy ensuring compliance with the Commission's sustained annulus pressure requirements? (e.g., bleed frequency; bleed -to pressures; testing; diagnostic test triggers; pass /fail criteria for annulus pressure diagnostics) See attached preliminary version of Pioneer's Well Operating Guidelines. Additionally, we use the AOGCC pass /fail criteria for annulus pressure diagnostics as outlined in Area Injection Orders 33 and 34. 4) Why is the tubing - casing annulus gas filled? Is this imposed pressure from surface (imposed pressure is excluded from sustained annulus pressure rules by definition)? I misspoke in my original note. The IA is diesel- filled with a minimal gas cap. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Williams, Theresa [mailto:Theresa.Williams @pxd.com] Sent: Thursday, January 15, 2009 2:31 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: K -33 IA Pressure Jim, Per the Oooguruk- Kuparuk Oil Pool Rules, Conservation Order No. 596, this is notification that ODSK -33 had a sustained IA pressure in excess of 2000 psig limit beginning on December 28 through January 10 Investigation shows the packer vent valve on the well was mistakenly opened on Dec. 25 and immediately shut. It appears the valve did not close completely and the pressure increased on the IA exceeding the upper limit on the 28 During this reporting period the IA pressure increased to 2346 psi on January 6 at which time it was bled off, but not to a point below 2000 psi. Since January 10 the sustained IA pressure has not exceeded 2000 psi and is currently at 1029 psi. The IA is gas - filled. To prevent packer vent valves from being opened by mistake in the future we will disconnect the hydraulic lines until we need to vent gas up the IA. The IA pressure was allowed to remain at this level for this period of time because operations believed the upper limit to be 2500 psi. This would indicate were still not 100% familiar with our pools rules and we have already begun correcting this by reviewing them with all shifts. Our intent is to be in compliance at all times and the safety of our personnel and the environment is always at the forefront. If you require further details or have any questions please call. 2/5/2009 • • Page 3 of 3 Sincerely, M Theresa Williams Pioneer Natural Resources, Alaska Staff Operations Engineer (907) 343 -2104 Theresa. W i I Iiams @pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2/5/2009 • Pioneer Well Operating Guidelines All Wells 1. All annuli for all wells should always have a pressure greater than 0 psi (positive pressure). Pressure must always be greater than 0 and can be read on the gauge. 2. Annular pressure must be monitored and recorded twice daily. Pressures (tubing, inner annulus (IA), and outer annulus (OA)) will be monitored and recorded once per shift. Naturally Flowing Producers 1. Production casing (IA) limit: 2000 psi. The normal operating pressure for the IA is 1500 psi or below. It should be bled down to 1000 psi if it exceeds this limit. The following information should be recorded when bleeding the pressure: Initial and final pressures, type and volume of materials produced, and amount of time it takes to bleed down the pressure. 2. Surface casing (OA) annulus limit: 1000 psi. The normal operating pressure for the OA is 500 psi or below. The Production Supervisor should be notified if the pressure exceeds this limit. 3. Further diagnostics are required when: a. A tubing by IA leak requires bleeding more than twice in a 7 -day period b. The IA pressure rapidly tracks the tubing pressure even if the IA pressure is below 2000 psi c. A IA by OA leak requires bleeding more than twice in a 7 -day period d. The OA pressure rapidly tracks the IA pressure even if the OA pressure is below 1000 psi e. There are leaks present to the formation or atmosphere under normal operating pressures Gas -Lifted Producers 1. Production casing (IA) limit: 2000 psi. The normal operating pressure for the IA is 1500 psi or below. It should be bled down to 1000 psi if it exceeds this limit. The following information should be recorded when bleeding the pressure: Initial and final pressures, type and volume of materials produced, and amount of time it takes to bleed down the pressure. When kicking -off gas lift the upper limit on the IA can be 2500 psi with approval from the Production Operations Engineer. 2. Surface casing (OA) annulus limit: 1000 psi. The normal operating pressure for the OA is 500 psi or below. The Production Supervisor should be notified if the pressure exceeds this limit. 3. Further diagnostics are required when: a. A tubing by IA leak requires bleeding more than twice in a 7 -day period b. The IA pressure rapidly tracks the tubing pressure even if the IA pressure is below 2000 psi c. A IA by OA leak requires bleeding more than twice in a 7 -day period d. The OA pressure rapidly tracks the IA pressure even if the OA pressure is below 1000 psi • • e. There are leaks present to the formation or atmosphere under normal operating pressures Injection Wells 1. Production casing (IA) limit: 2000 psi. The normal operating pressure for the IA is 1500 psi or below. It should be bled down to 1000 psi if it exceeds this limit. The following information should be recorded when bleeding the pressure: Initial and final pressures, type and volume of materials produced, and amount of time it takes to bleed down the pressure. 2. Surface casing (OA) annulus limit: 1000 psi. The normal operating pressure for the OA is 500 psi or below. The Production Supervisor should be notified if the pressure exceeds this limit. 3. Further diagnostics are required when: a. A tubing by IA leak requires bleeding more than twice in a 7 -day period b. The IA pressure rapidly tracks the tubing pressure even if the IA pressure is below 2000 psi c. A IA by OA leak requires bleeding more than twice in a 7 -day period d. The OA pressure rapidly tracks the IA pressure even if the OA pressure is below 1000 psi e. There are leaks present to the formation or atmosphere under normal operating pressures NOTE: The AOGCC must be notified within 24 hours of confirmed communication between the tubing and IA and an action plan must be approved by the AOGCC. Notify the Production Operations Engineer if communication is suspected. Shut -In Wells 1. Same as naturally flowing producer 2. Set plug, kill pill, etc. as needed to ensure compliance with guidelines. Page 1 of 2 • cbs, 33 Regg, James B (DOA) P' 6 2C7 6 From: Regg, James B (DOA) l I I ( i/ Sent: Friday, January 16, 2009 2:32 PM \` To: 'Williams, Theresa' Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: RE: K -33 IA Pressure Attachments: TIO Plot example.xls Thank you for the notification. For future notifications, please provide (1) current wellbore schematic, and (2) plot of the previous 90 days tubing, inner and outer annuli (TIO) pressures - example TIO plot attached. Couple questions from the notification - 1) I'm a little confused with the well completion, which appears to be set up for ESP artificial lift and a contingency gas lift capability (dummy valves installed ?). What is the packer vent valve referenced? What is it used for and why? Valves and control line are shown on a proposed completion schematic in our well file but no descriptive information has been provided; 2) What is the status of the packer vent valve? Email below indicates that it was not completely closed, and based on description, it could be interpreted that IA pressure is being maintained with active management (pressure bleeds); is that correct or have you confirmed the valve is now closed? 3) What is Pioneer's policy ensuring compliance with the Commission's sustained annulus pressure requirements? (e.g., bleed frequency; bleed -to pressures; testing; diagnostic test triggers; pass /fail criteria for annulus pressure diagnostics) 4) Why is the tubing- casing annulus gas filled? Is this imposed pressure from surface (imposed pressure is excluded from sustained annulus pressure rules by definition)? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Williams, Theresa [mailto:Theresa.Williams @pxd.com] Sent: Thursday, January 15, 2009 2:31 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Gilroy, Jim; Hall, Joey Subject: K -33 IA Pressure Jim, Per the Oooguruk - Kuparuk Oil Pool Rules, Conservation Order No. 596, this is notification that ODSK -33 had a sustained IA pressure in excess of 2000 psig limit beginning on December 28 through January 10 Investigation shows the packer vent valve on the well was mistakenly opened on Dec. 25 and immediately shut. It appears the valve did not close completely and the pressure increased on the IA exceeding the upper limit on the 28 During this reporting period the IA pressure increased to 2346 psi on January 6 at which time it was bled off, but not to a point below 2000 psi. Since January 10 the sustained IA pressure has not exceeded 2000 psi and is currently at 1029 psi. The IA is gas - filled. 1/16/2009 • 411) Page 2 of 2 To prevent packer vent valves from being opened by mistake in the future we will disconnect the hydraulic lines until we need to vent gas up the IA. The IA pressure was allowed to remain at this level for this period of time because operations believed the upper limit to be 2500 psi. This would indicate we're still not 100% familiar with our pools rules and we have already begun correcting this by reviewing them with all shifts. Our intent is to be in compliance at all times and the safety of our personnel and the environment is always at the forefront. If you require further details or have any questions please call. Sincerely, M Theresa Williams Pioneer Natural Resources, Alaska Staff Operations Engineer (907) 343 -2104 Theresa.Wi Iliams@pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/16/2009 <Wellname> TIO Pressures 2,000 ... 1,800 —WHP IA OA 1,600 1,400 r 1,200 � y_ _ _t� .: 1 L 1,00 I 800 L j a 600 �.__ . 400 200 • 0 1 , I I I I I I O 0 O O O`b (C)Q' O `b O O 3 O O O O 3 O 0 O O O �O ��O �O ��O �O �O ��O �O ��O ��O ��O ��O ��O �O ��O ��O ��O ��O 0 & 3 \ \ ► \ 1 � co O O \ I \ D O r 1, O ` 1, � O \ � O t . � O k . � O ∎ v P\ P\ � � \O � , . � � Date Page 1 of 3 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 16, 2008 3:04 PM To: 'Vaughan, Alex' Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: RE: Current Oooguruk Well Status as of 10/16/2008 Alex, et al, Thanks much for the updated information. Looking at the information and cross checking our files, I only found one well that may need some paperwork filed; ODSN -39. If no activity is likely on this well until springtime, it is appropriate for Pioneer to file a 404 with attachments for the operational SD as was done with K -35, K -36 and N- 34. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Thursday, October 16, 2008 2:09 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: Current Oooguruk Well Status as of 10/16/2008 Tom, Well Name PTD Completion Date- Comment Status ODSDW 01-44 207 -140 1/27/2008 Active Disposal Well ODSK -35 207 -181 2/12/2008 Surface Casing Set ODSK -36i 207 -182 2/4/2008 Surface Casing Set —4 ODSK -33 207 -183 4/29/2008 Active Kuparuk Producer ODSN -34i 207 -184 2/17/2008 Surface Casing Set ODSN -31 208 -003 n/a Not Spudded ODSN -32 208 -004 n/a Not Spudded ODSN -40 208 -039 8/1/2008 Active Nuiqsut Producer ODSN -39i 208 -040 5/7/2008 Surface Casing Set ODSN -45i 208 -100 10/15/2008 Intermediate Casing Set, temporarily abandoned, likely to be side tracked ODSN -43 208 -139 n/a Not Spudded ODSK -41 208 -147 n/a Not Spudded, Spud 10/16/2008 ODSK -38 208 -148 n/a Not Spudded ODSN -37 n/a n/a Not Spudded The following is the current schedule as of 10/16/2008. We will be submitting the ODSN -37 Surface Casing Depth Change Sundry middle of next week. Drill Start Drill End Date Days Date 10/20/2008 Page 2of3 • �� OQSN-45i'|N13-S AOGCC approved k 74.0 Q[JSN~41 -KupF(Horiz)'S , ' 6.4 ODSK-38i -Kup D (Slant) - S 10/21 � 5.8 ~ l '' -- ��. ' C>K�SN-37-PN8 -S 1,~^..�� 5.7 ' 11/282008 ODSK-38i -Kup D (Slant) - P,C 11/2C3008 15.1 11/17/2088 ODSN'37'PN8 -| 11/17/2008 13.0 11/30/2008 ODSK-41 - Kup F (Horiz) - I,P,C 11/30/2008 32.9 1%62009 Alex Vaughan Operations Engineer PIONEER m�~� D�� �� �� �� 0 ~ N � � U�� �� �� �� NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Polya, Joe Sent: Wednesday, October 15, 2008 4:38 PM To: Vaughan, Alex Subject: FW: Current Oooguruk Well Status - Again Alex, Please review the attached and lets make ourselves a duplicate spreadsheet whereby we can track and ensure that we have all the applicable permits submitted and approved for our various wells in their array of stages toward completion °°.^ ^^, P" Pdvet Pioneer Natural Resources Alaska, Inc. Sc Staff Drilling Engineer joe.polyw,dpxd.corn Main Office: (907) 277 Direct: (907) 343 Fax: (907) 343 Mobile: (907) 244 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 14, 2008 10:01 AM To: Maunder, Thomas E (DOA); Polya, Joe Subject: RE: Current Oooguruk Well Status - Again Joe, I know you have been busy with ODSN-45, but I would appreciate if you or one of your staff could fill out the table below. Thanks in advance Tom Maunder, PE AOGCC . � Page 3 of 3 From: Maunder, Thomas E (DOA) Sent: Friday, October 03, 2008 12:00 PM To: Polya, Joe Subject: Current Oooguruk Well Status Joe, As you know, I am reviewing the permit applications for ODSK -41 and -38. In the course of that review, I have prepared a list of the permits issued to date for the Oooguruk project. I realize that Pioneer has encountered drilling difficulties that have resulted in halting operations on some of the wells. Also, halting operations was planned due to the seasonal drilling restriction for some of the Kuparuk wells. Would you or one of the engineers complete the following table for the ODS wells? I have included the information I have available. It is possible that I have not seen all the paperwork that has been filed. I am particularly interested in wells that have been spudded and then operations halted. I expect that we will exchange a few messages to get things all filled out. Call or message with any questions. Tom Maunder, PE AOGCC Well Name PTD Completion Date- Comment Status ODSDW 01 -44 207 -140 1/27/08 WDSP1 ODSK -35 207 -181 ODSK -36 207 -182 ODSK -33 207 -183 4/29/08 1 -oil Initial production well. ODSN -34 207 -184 ODSN -31 208 -003 ODSN -32 208 -004 ODSN -40 208 -039 8/1/08 1-oil ODSN -39 208 -040 ODSN -45 208 -100 ODSN -43 208 -139 ODSK -41 208 -147 Permit under review ODSK -38 208 -148 Permit under review Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 10/20/2008 Y 'Y • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (C�� DATE: July 30, 2008 P. I. Supervisor (( 2 - 0 7IS3o FROM: Lou Grimaldi SUBJECT: Well SVS Inspection Petroleum Inspector Oooguruk K -33 Pioneer Natural Resources Oooguruk Field Saturday, July 26, 2008: I visited Pioneer Natural Resources (PXD) Oooguruk Production Island just offshore of 3 -H pad in Kuparuk. I had been in contact with Merlene Conner (Production Supervisor) for a few days earlier, weather and scheduling conflicts had held up my inspection until today. This well had reportedly flowed for thirty days or greater without a Commission witnessed SVS test. I was requested by my supervisor, Jim Regg, to assess the worthiness of the SVS system and perform an SVS test if possible. arrived the island this morning at approximately 10:30 A.M. and after a brief meeting with Merlene Conner and Tom Treadway (PXD Production Operator) I was given a tour of the production module and well #K -33 SVS. CPF -3 is down for turnaround and production from this island had ceased previous to my visit. This system is controlled by a pressure transmitter signal located downstream of the production choke to the P.L.C. in the control room. Upon a low pressure signal falling below the programmed set -point air operated SSV's close on the flowline and gas -lift line. A SCSSV is also installed in the well, this is closed by the fire and gas logic system as well as a low pressure in the SCSSV hydraulic panel. I was informed that the SCSSV did not close on the activation of the modules emergency shutdown system (ESD). The wellhead was of the "Horizontal" configuration which I have encountered in other fields. This reduces the overall height of the wellhead and makes for a compact installation. I have not encountered any inherent drawbacks to this type wellhead. Due to this configuration the SSV is on the horizontal run and was installed outside of the manual valve and a 2" line that reportedly will be used for freeze protection if desired. In reading API 14H it seems they did not consider horizontal trees when writing that standard, a case could be made to place the SSV outside of the manual wing and consider that manual wing as actually a inside master valve (on the horizontal run). I do feel that the freeze protect line should go outside of the SSV. SCANNED APR 1 7 2013 SVS Oooguruk 07 -26 -08 LG Page 1 of 5 '' • • 4 ' s . ; , 1 ..::ilit t*Ir 44010114140: I r) I 4 i - , ., 416 44101411111110,, , ' tt. 44.,4 Ilt ' I • ''''' ' ' Illt. ' ''' . ii -,, fill I t i 1r ' ilt. " _. 7" * A ? Flow r/ �b Wing Valve ' ... A.L. Wing fi Valve (typ.) I a , MIN Flow Line it # Freeze • • protect lines 4 : - ' _ Artifi Lift Line cial Wellhead photo showing horizontal configuration SVS Oooguruk 07 -26 -08 LG Page 2 of 5 •` • • Ito* - — akv ' it ,t, . wa tilt 4 - .` fi t ` { i. ., .. `' 1 _`r1 � e t *fix L C .> „fir # (II I. N T t Y , Y � _ • , ►w Block cross "310 `}° for Freeze Tilik r , Protect line , -. .. ..101111.11111110 I , ,,, , it _ i _ t <.j, 4 . r R • f � •Yr Art f •■•••■.. f y4 ''''''' � a i r i 4 r 'i I Photo of I.A. valve configuration with block cross for "Freeze Protect” line between Master /Wing valve and SSV. SVS Oooguruk 07 -26 -08 LG Page 3 of 5 r • • fh ... _.��,r _ i ; _- P ressure i ' ' ,.... .: - gr-L-7•'•• 4 , ,I a a k t t k44. Transm 7 :\ i o N o Photo of pressure transmitter on flowline downstream of wellhead. The above transmitter has no LPS set point function other than to tell the PLC the pressure on the flowline assembly. The shutdown set points are input at the control room. I discussed this with Merlene Conner and Tom Treadway about our requirement of tagging the pilot with it's designated trip pressure. A possible solution might be to develop a screen on their PLC monitor that would show all wells LPS settings. There were no provisions for attaching a test manifold to the transmitter for testing purposes. I also discussed with them the criteria for LPS settings as reported to me they had been flowing at approximately 300 psi separator pressure but had the trip setpoint in the PLC at 100 psi. Tom Treadway and I discussed what the Commission expects from a SVS function /pressure test. I made it clear that upon resuming production a SVS test is required immediately. I gave our pager and phone numbers to both Merlene and Tom. I have also put them in contact with Bob Fleckenstein (AOGCC Stat Tech) to get them the proper forms for SVS test reporting. SVS Oooguruk 07 -26 -08 LG Page 4 of 5 f • • v St -*iv . 1 .4111111 l'' w IN ' s e 4. s ° t -0 x �� M �� .. rw.rw. . .i.,,,„, ,..„_...,.: . i i ... 3 , ki k* 'ff ., t� - - M 1 F 1 4 � l ti , Likely place fora t needle valve /quick �' " ' connect assy f a, z .' .'a t r r 1' .I () N1 I I I I I-' I 01 I Closeup of pressure transmitter. I was repeatedly told that PXD is striving for full compliance with pertinent AOGCC regulations. SVS Oooguruk 07 -26 -08 LG Page 5 of 5 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 23, 2008 10:41 AM To: 'Campoamor, Kathy' Cc: Hazzard, Vance Subject: RE: Operations Summary Detail — ODSK -33 (207 -183) Kathy, This detail is much better. I'd appreciate if this detail could be the norm for future operations reports. Call or message with any questions. Tom Maunder, PE AOGCC From: Campoamor, Kathy [ mailto:Kathy.Campoamor @pxd.com] Sent: Friday, June 13, 2008 4:25 PM To: Maunder, Thomas E (DOA) Subject: RE: Operations Summary Detail -- ODSK -33 (207 -183) Tom, Attached is a revision to the Operations Summary for ODSK -33. Let me know if the information on this report will satisfy the detail you're looking for. Thanks, %I GTlf11' t_ am,m)amor Engineering Tech II Pioneer Natural Resources Alaska Inc. phone 907 - 343 -2183 fax 907 - 343 -2192 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, May 30, 2008 2:55 PM To: Campoamor, Kathy Cc: Hazzard, Vance; Polya, Joe Subject: RE: Operations Summary Detail -- ODSK -33 (207 -183) Kathy, I am reviewing the 407 recently submitted for ODSK -33. Please send the detailed hour breakdown. The summary submitted does not have sufficient detail for me to do my review. Call or message with any questions. Tom Maunder, PE AOGCC 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. 6/23/2008 • • j „ • ' , , i ' Letter of Transmittal Date: June 20, 2008 From: Tavia Jackson To: Steve Davies Pioneer Natural Resources AOGCC 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage AK 99501 Anchorage, AK 99501 Information Transmitted: ODS K-33 and 33 PB1 WELL DATA (Logs, Reports, CDs) 1 CD - Final LWD Data (33 and 33 PB1) /2 Prints — 2" TVD/MD LWD Triple Combo Logs (ODSK-33) 1 Print — Engineering Log (OKSK-33) 1 Print — Combination Mudlog (OKSK-33) , f Print — Gas Ratio Log (OKSK-33) v2 Prints — 2" TVD/MD LWD Triple Combo Logs (ODSK-33PB1) — 1 Print — Engineering Log (OKSK-33PB1) 1 Print — Combination Mudlog (OKSK-33PB1) 0 .3„ercjr. ) 1 Copy — End of Well Report (ODSK33 and 33 PB1) Includes: 1 Mudlog Data CD Received by: Date: Please sign and return one copy to: Pioneer Natural Resources, Inc. Attn: Tavia Jackson/Shannon Kim 700 G Street, Sutie 600, Anchorage AK 99501 907-343-2190 fax ps--- / / M5165 c.0 ' VED 0 STATE OF ALASKA • MAY 2 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION Aiaska nil WELL COMPLETION OR RECOMPLETION REPORT ANfY ons, Commission 1 a. Well Status: Oil 0 , Gas ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb. Well Class: f Chorage 20AAC 25.105 20AAC 25.110 Development 0 - Exploratory ❑ GINJ❑ WINJ WDSPL WAG ❑ Other❑ No. of Completions: 1 �S ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp. or t9�r��T2. Permit to Drill Number: Pioneer Natural Resources Alaska Inc Aband.: 42008 207 -183 / 308 -088 / 308 -154 3. Address: 6. Date Spudde 41j 13. API Number: 700 G Street, Suite 600, Anchorage, AK 99501 2/1k2008 50- 703 - 20562 -00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached p0.4 1 14. Well Name and Number: Surface: 2965' FSL, 1102' FEL, Sec. 11, T13N, R7E, UM , 4P5008 �7j 5.2$ ODSK -33 . Top of Productive Horizon: 8. KB (ft above MSL): J 15. Field /Pool(s): 953' FSL, 4751' FEL, Sec. 11, T13N, R7E, UM Ground (ft MSL): 13.50' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk Kuparuk Undef • 4818' FSL, 3159' FEL, Sec. 14, 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- 469896.5 / y- 6031080.67 ' Zone -AsPa 12055' MD / 6054' TVD ADL 355036 TPI: x- 466240.9 y- 6029084.0 Zone -AsP4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 467827.85 • y- 6027463.49 + Zone- ASP4 762' MD / 762' TVD 417497 18. Directional Survey: Yes Ei No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) $2- ( g.280.CB 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR, DIR, Mudlogs, CTN, AND, PWD, RES, ADR - 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 65# H -40 Surface 153' Surface 153' 24" Welded 9 -5/8" 40# L -80 BTC Surface 3173' Surface 3052' 12 -1/4" 380 sx PF'L'; 215 sx Class 'G' 7" 26# L -80 Surface 9793' Surface 6070' 8 -3/4" 181 sx Class 'G' BTC -M 23. Open to production or injection? Yes Ei No❑ If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3 -1/2 ", 9.3#, L -80 IBT -M 3500' Open Hole Interval 2 -7/8 ", 6.4 #, L -80 IBT -M 9566' 4021' • MD TVD ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9793' - 12055' 6070' - 6054' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9429' Freeze Protect w/ 349 Bbls diesel 26. PRODUCTION TEST . Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period O Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. ' 24 -Hour Rate ■ 24.5 • 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 - 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 and laboratory analytical results per 20 AAC 25.071. None ' __ f t • Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE • • jai `�d8 4.'41.4'9' . . 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? F Yes No I If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Permafrost 850' 850' • Base Permafrost 1685' 1671' Top West Sak 2385' 2334' Top Torok 6642' 5022' Top HRZ 8750' 5799' • Top Kuparuk C 9780' 6068' • None 30. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joe Polya, 343 -2111 Printed Name: Vance Hazzard Title: Drilling Superintendent Signature: I Phone: 343 -2116 Date: 5/23/2008 Well No. ODSK -33 fe it No. 207 -183 Prepared By: Kathy Campoamor, 343 -2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 0 III Operations Summary Report Well Name: ODSK -33 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Spud Date: 2/18/2008 Rig Release Date: 4/28/2008 fastMed Decd 5,4 Data Depth Start (WS) FootlMAeters (ft) Obrt n _ 2/18/2008 44.0 0.00 Move rig from ODSN -34i to ODSK -33. Secure well, shim beams to level rig, disconnect and move supply lines to allow rig to move over well bay. I 42/19/2008 57.5 141.50 8.90 'Reconnect supply lines in Hutz, Move !lever ODSK-33, level pad and square to well bays. - Instal, i Vetco standing head, function test diverter and gas detectors, service rig, R/U:gyre. w ire`line Held � pre -spud safety meeting. Function test diverter system: Der AOGC9. John Crisp with " AOGCC waived I Witness of test. All systems passed without incidents- M/U 121!4' BHA. , reamed Oct conductor to 153 . Prig to 199', Cleared plugged CCU lines. 2/20/2008 199.0 1,547.00 9.30 Drill, slide /rotate and survey f/199 99' - 1,746' MD, 1,728' TVD. 2/21/2008 1,746.0. 1,437.20 9.50 Drill, (slide/rotate) and survey 91,746'-3,183' MD, 3, 165' TVD, CBU I-9-via sweep a_ f.5x.,PO011 3000`, trouble step . trip Tank»- 2/22/2008 3,183.2, 0.00 9.50 Short tripped to jars, worked thru tight spots, Circulate and condition, per Mud Man, and until shakers i clean, POOH worked thru tight spot at 2944', cont. out of hole, racked back 5 stds HWDP, LD directional assembly, RU 9-5/8' csg tools. Held PJSM. MU shoe joint & 1 intermediate joint & circ. thru float shoe. 2/23/2008 3,183.2 0,00 9.70 Run 9-5/8 Casing, work thrti "tight:spots ,F/2920' 172985'. Land casing with hah,fierarld Ciro & Condition, stage oumos up to 10 BPhil, 2650 psi with no losses. &. puo Reciprocate casing 20' durgy lead cennent job. Pumped 40 bbls,10.0 ppgdurd, spacer. mix & putt's' 260 bbks lead, (1571 cu/ft) Type L Permafrost, inked at 10.9 ppg well Peet sea water. with.4.i s;. >: yid, pumped at 45 BPM. 235 bbls cnmtnred land cas , Mix & pump ; 45 bbls Tat j25 3 " Pu ;: G +2% CaCl2 + .2% CFR -3,' 1.19,yld, mbted at 15.9 ppg with 5.2a t seawater - top'{ pwip bbis sea Water, displace with 9.5 WBM With rig pumps at:8"BPM , VI.P..P S lowed t014 :: ' BPM 650 psi, fit 214 obis" aw ay, plug with 500 psi over 1150 psl at 12:05 tars Bled off at 12;08 bra & checked floats, OK Cement inplace at 12:05 tire 40 bbls.of 10.9g cement.retumed'to " stn'fare, Flush diverteT;and rigor;. ND same. 2/24/2008 3,183.2, 0.00 9.70 Install Vetco Grey M -233 well head, test to 5000 psi, N/U BOP stack, test BOPE per AOGCC r . I. i. ns. Chuck Sheve with AOGCC waived witness to test. Test with 250 psi low & 3500 psi high on all Rams, Annular Preventer, Valves. Check Methane /H2S gas detection & LEL equipment, OK. Perform Accumulator test with 1:35 min recharge on system. RD test equipment. Slipped and cut drill line, M/U 8 -3/4" BHA and surface test same. P/U 4' drill pipe. 2/25/2.008 3,1832 0.00 8.90 Made up BHA #2, picked up &:singted.in 69 Its Drill pipe, service Fig=& tapctrive, drip out plugs collar and cement to 3161'3 CBU & attempt t test casing,,! nsuccess . P te- 2/26/2008 3,183.2 12.80 8.90 LD and rack back BHA #2, MU BHA #3 with RTTS to 3078' and TIH, Set and test Casing 35118 psi for 30 min. , POOH with RTTS and LD same, MU directional assembly BHA #4 and 1 IH, Drill cmt & float shoe from 3163' to 3173'. Clean out rat hole to 3183', drill 13' new formation at report time. I I 2/27/2004 3,196;0 1,625.10 9.20 Drill 8-3/4' hole section F/3196' T/3203'. Circulate priot to LOT. Perform L T :nth 8.8 pa It W " t psi break over point= 15.45 EMW. Drig ahead row{ Geo-P , tat 4, 821' MD. building angle to 54.56" t h r , - - 281.70 azi. Dig ahead wr/ Geo -Peat 4, 821' MD building; ante "to 54.58° With 28t.70 azi: :. . " ;:: 2/28/2008 4,821.1 1,678.90 9.60 Prig ahead w/ Geo-Pilot at 6,500.80' MD building angle to 68.60° with 253.30 azi. I � 2/29/2008 6,500.0 1 ,534.00 9.80 prig 8-3/4' hole, ahead w/ Geo -Pilot at 8,034 MD budding angle to 68.89* with 199.85° azf 3/1/2008 8,034.0 457.701 10.50 Drill to 8491', work stuck .i. -, .ipe free, circulate and condition mud, wiper trip to 7814' at report time. i www.peloton.com Page 1/8 Report Printed: 6/13/2008 0 Ili : Operations Summary Report Last Mud End Date Depth Stan (ftKB)1. Foot/Meters (!t) 9a1 ' Su , 3/2/2008 8,491.7 0.00 10.70 Finish short trip to 6640', worked thru tight spots at 7729', 7660', 7565'. TIH to 8313', safety wash and ream F/8313' To/ 8491'. Reamed out obstruction F/8474'- 8484'. Circulate and condition, pumped 30 Bbls hi -vis weighted sweep at 13.0 PPG WBM with 10 PPB walnut surface to surface. Trouble shoot !MWD failure, Pump 30 bbls fresh water pill, no success, POOH to 6478', touble shoot MWD while Icirc. and condition, no success, pump slug, POOH. Lay down BHA, un -load nukes and down load I MWD, clean balled up stabs and bit. Found small rocks in MWD pulser poppet. 1 3/3/2008 8,491.7 0.00 10.60 POOH, LD BHA #4. Test BOPE witnessed by Bob Nobles with AO.GCC Annular 250/2500 psi All Eother tests to 25013500 psi. MU BI A #5, T111.: 3/4/2008 8,491.0 538.00 10.70 Finish TIH to 8400', wash to 8491', No Fill, C & C, Drill 8 3/4' hole per program to 9029'. 3/5/2008 9,029,0 442.00 11.00 f Drill 8 314' hole with Geo Pilot F /:902W Tn/ 919W, C & C, attempt "check trip had esters drag up - 300k at 8990'. TIM wash and ream to bottom, Drill ahead to 94717 wffh Geo•Pllo while,bu rriud'wt to 11:0 ppg. . 3/6/2008 9,471.0 259.00 11.00, Drill 83/4' hole with Geo -Pilot F/ 9471' To/ 9682', Circulate B/U Drill 'F/ 9682' to 9705', Circulate B/U, ;Drill F/ 9705' to 9730'. Back ream out of hole F/ 9730' to 9374 ".Tight Hole, Hole packing off, work thru tight spots., I ' 3/712008 9,730.0 0.00 11.00 Back ream and Circulate Fl 9374' to 6960', Use Photometers as Hole. A problem exists:at 5538' possible key seat,. both Ghost reamers had problems coming thou this area, ' - 3/8/2008 9,730.0 0.00 11.00 Back Ream F/ 6960' to 5899'. Hit Tight spot and Jar pipe Free. Resume Back Reaming F/ 5839' to I 5250'. Hit second tight spot, Jar Pipe Free. Resume Back Reaming F/ 5190 to 4800'. �I 1i 3/9/2008 9,730.0 0:00 11.00 Back ream F/4800' to Shoe at 3173', Observe Well Circulate B/U at Shoe and observed a lot of cuttings upon Bottoms Up. POOH and Lay down BHA Service Top:Olive and conduct Post 'Jar**, Derrick' j '3/10/2008 9,730.0 0.00' 11.00 Finish with Post Jarring rig service, M/U BHA # 6 and RIH to 8424' on Elevators, Started experiencing hole problems and started Reaming to Bottom F/ 8424' to 8850' with no problems. at 8850' encountered High Torque and drag, worked thru spot at 8850' to 8884'. Resume Reamino to 8919' I. land pipe became stuck. Worked pipe Free and attempt to work thru this area. i 3/11 /2008 9,730.0 0.00 " 11.50 Pull pipe to safe zone at 8696', Build Mud weight to- 11.5pPg while wosjdng, pipe. Wash and ream to 8, 991'. Pipe became stuck again. work back up to 8805' and establiStigoo0 . hole -Raise GPM. 1460:l and rotary at 150 RPM and slowly wash down deank.g hole to 8836',_&M) an effort to clean, running shale. beds caused by HRZ Formation 3/12/2008 9,730.0; 0.00 12.00 Wash and ream to 8861',Beacame stuck, Jar free and work pipe to 8704'. Build and displace 11.5 1 mud with 12.0 ppg mud. Wash and Ream F/ 8704' to 9008'. Ream at 2' FPM for 32', Backream same ! 32' section and log any change in parameters, continue with next 32' section. 500 gpm, RPM 150, Mud weight 12.0 ppg. 3113/2008 9,730.0 0.00. 12.50 Wash and Ream F/ 9008' tri 9383'. Ream at 2' FPM for 32', Backream same 32'seotion and log any , ' in parameters, continue with next 32' section 500 gpm, RPM 150, ; Start Rafting Mud weight from 12.0 ppg to 12.5 ppg at 9242'. light spots - 9012', 9017`9029 9038`,, 92.91; 9348' ' www.peloton.com Page 2/8 Report Printed: 6/13/2008 40 Operations Summary Report Last Mud Dens End Date Depth Stan (ftK8) Foot/Meters (ft) (tai Sammy '3/14/2008 9,730.0 0.00 12.50 Wash and Ream F/ 9348" to 9,707'. Hit Refusal at 9707' Contact office before going any further, desision made to stop here due to the 12.5 ppg mud weight change and the problems we could encounter if we hit a zone not suited for the 12.5 ppg Mud. Ream at 2' FPM for 32', Backream same !32' section and log any change in parameters, continue with next 32' section. 500 gpm, RPM 150, Mud weight 12.5 ppg. Tight spots @ 9388', 9398', 9409', 9438'. Attempt survey @ 9375, Try increasing GPM, unable to communicate with MWD. No Accidents, No Incidents, No Spills 3/15/2008 9,730.0 0.00 12.50 Hit Refusal at 9707' attempt different combinations to work past spot, Contact office, Permission given to stop at 9707'. Circulate 3 Bottoms ups until shakers were clean, Pull a wiper trip to 8250' with no problems. RIH Ft 8,250' to 9,280'. Concerned about fluid displacement, Wash f t 9280 to 9707'.'" I Circulate and displace old 12.5 ppg mud for New and Circulate hole clean. POOH &" SLM F! 9707' to 5130% Test Choke .: • • Att. i - •, _ ._o, •r • 1," , .. * 3/16/2008 9,730.0 0.00 12.50! POOH w/ BHA # 6 F/ 5132' to Surface. U•on reachin. the last 'oint it was discovered that the bottom t.. , „' '...... , . " • t- .,:. n,I1T •3Ti'L �1ib1^f�L�111 h - i . -. Consult 'with office about Plan forward. Tested Choke Manifold while tripping out, per AOGCC requirements, • 1250 psi low /3500 psi high - 5 mins each test. RU and Test BOP to AOGCC regulations, Chuck Sheeve with AOGCC waived witness to test. Annular preventer @ 250 psi low /2500 psi high - with all tests @ 250 psi low /3500 psi high. Function test accumulator system with 3000 psi initial & 2000 psi draw down While testing dispatch a Baker fishing tool hand with overshot to location. After BOP Test serviced the rig and begin PU Fishing tools and 6 1/4" Drill collars to a depth of 320'. 3/17/2008 9,730.0 0.00 12.50 RIH urJ Fishing Assembly F/ 324' to 6,828'. Work tight spot Ft 6,826' to 6,890'. Jarred twice and work - pipe back to 6,788'. RIH F/ 6,788' to 7,000' where the fishing assembly became differentially stuck. Work pipe down with out jarring to 7,094', where weight broke over. RIH Ft 7,094' to 7,566'. Spot LCM pill across the BHA to the top of the Torok f=ormation 6,812. RIH F/ 7566'. to 8,435'. Start washing F/ 8.435' to the Top of fiSl) at 8.842' fBit W 9.438% Hook onto and establish circulation thru fish .,j:Ujl_ h fre th max overpull of 325K, no jarring, POOH WI fish F! 9,438' to 7,980' where the assembly became differentially stuck. . (Full circulation, Can't activate Jars To 1 fishi . BHA l LA• I i - 3/18/2008 9,730.0 0.00 12.50 Workin. stuck .i.e at 7,964'. Attem.t man combinations of workin. •i. - t in. to activate'- . Spot 3 Lub pills aroun.: ' an. continue wor mg pipe (40' 'own and 474K up) pot :lack Magic Pill and let soak in an effort to free up the upper collars and work pipe in a downward motion to clear the Torok sand. 3/19/2008 9,730.0 0.00 12.10 Let Black Magic soak, pumping 1 bbls! Hr. Line up Schfumberger to perforni free point, and Haltibuton to cement, and set kick off plug white working pipe. at 23:15 jars started working, continue to jar fish on Up and Down Stroke in an attempt to work pipe dawn. 3/20/2008 9,730.0 0.00 12.20 Work stuck pipe. Decision made by town ODE to run cement plugback, per agreement with AOGCC. Cement fish in hole, pump 2 -4 bbls 12.5 ppg spacer & test cement lines to 4500 psi - OK. Continue to pump spacer with HES pump for total of 25 bbls, followed by 39 bbls 12.5 ppg cement (Neat) and 5 bbls spacer. Chase with 65 bbls mud at average 4 -4.5 BPM= 960 psi (1250 psi when cement went thru tools). Inspect traveling block and derrick. RU SLB wire line and run free point, attempt to trap torque for back off, unable to trap required torque without breaking pipe. Wait on severing tool. 3/21/2008. 9,730.0 0.00 12.10 Wait on severing tool to arrive. tnstaf 1 7/8" severing tool on rope socket, Glli to 6620', sever pipe with 25k over. I, • ood indication of • - r .. CBU, POOH breaking, Inspecting each break with. • • personne , re-dope and re- torque to 22.41c per NabarS procedure,L/D "4 joints "with damaged faces: www.peloton.com Page 3/8 Report Printed: 6/13/2008 I II Operations Summary Report II -Last Mud Dens End Date Depth Start (ftKB) Foot/Meters (It) tiblgat) Summary 3/22/2008 9,730.01 0.00 12.20. Break and ispect threads, Re -dope & torque 2 times. MU cmt diverter sub, TIH to shoe, slip and cut ;drill line, repair iron rough neck, TIM to TOF, spot 17.9 ppg mud, pull 100', circ. and condition to 'balance fluid. 3/23/2008 9,730.0 0.00 12.10 CBU F +/- 6820', after spotting 17.0 ppg 11-vis pill 0 6920'.. Set cement kick off, pump 5 bbis . sea water. Continue to pump 20 bbls sea water, followed by 13.5 ppg spacer, 54 bbis of 17.0 ppg cement (fresh water based), followed by another 5 bbls 13.5 ppg spacer then 5 obis sea water. The sidetrack plug was then displaced with 55 bbis of 12.2 ppg mud, after dropping wiper plug. CIP 02:30. POOH to 6100' + - , CBU, POOH, Test BOPE per AOGCC requirements. Lou Grimaldi with AOGCC as witness to test. Test all rams 250 psi low /3500 psi high. ° Annular preventer, 250 psi low/2500 psi high and valves 250 psi low/3500 psi high - all tests passed. MU 8-3/4' 1 -1/2° bent housing motor side track assembly, PU I-IWDP & 4" 8 -135, TIM to 2570: 3/24/2008 6,527.0 475.00 12.20 TIN, wash & ream F/5380' T/6232'. Continue to wash & ream cement F/6232' T/6480', very hard , cement -ncount-r-.. Attempt to side track wellbore. Time drill F/6527' T/6575'. Sidetrack from cement •lu. without incidents. Drill, slide & survey to 7002'. Repair module on #1 pump. ■ 3/25/2008. 7,002.0 558.00 12.20 Repare #1 center fluid module and change seat gasket. Silde, drill and survey F/ 7002' Tot 7560'. 3/26/2008 7,560.0 373.00 12.20 Slide, drill and survey F/ 7560' To/ 7933'. ;3/27/2008 7,933.0 257.00 12.10 f Slide, drill and survey F/ 7933' To/ 8190'. CBU 2 times, pull on elevators to 6610`, pump and back ream F/ 6610' To/ 5844'. 3/28/2008 8,190.0 0.00 12.20 Work tight spot at 5844- 5837', jar free, Back -ream to 4111', pump out F/4111' To/ 3148', CBU x2 until shakers clean, pump slug, blow down TDS, POOH, LID BHA, Service rig, P/U Geo- pilot, bit and program MWD. TIH. ■ 3/29/2008. 8,190.0 427.00 12.60 TIN to shoe, CBU, TIN B/C ea. 30 stands, Tag obstruction at 7012'. Wash and ream F/ 7012 To/ 8190'., Drill Fl 8190' to/ 8617 with Geo -Pilot per SSDD and program. 3/30/2008 8,617.0 648.00 12.50 Drill F/ 8817 to 9265' MD, 5970' TVD with Geo -Pilot per SSDD and program. BOP test extension request to Tom Maunder with AOGCC via email - OK., 3/31/2008 9,265.0 45300 12.50 Drill F/9265' To/ 9718' , per SSDD and Program: Attempted different weights and rotary with no . signific change in ROP. 4/1/2008 9,718.0 90.00 12.50, Drill To/9808' MD, 6072' TVD per SSDD and program. Attempt to short trip, had tight hole and , I pressure loss, wash back to bottom and verify pressure loss. POOH, wash and ream as needed to pull out of hole with low pump rate. - 4/2/2008 , 9,808.0 0.00 12.30 Pump out of hole through multiple tigl'tt areas. Drill strip• failed with T' ' of f . h a 4199' and • • .• - As C on 4' drill.* • . Witness • test Waived b 6224.96. Pooh with Drill pipe. Test BORE per A Y John Crisp with AOGCC. Annular 25'0/2500 psi. Rams & Valves 250/35i r per. RD and set wear ring. Slip and cut drill, service rig. MU Baker Hughey fishing asseembly , I 4/3/2008 9,808.0! 0.00 12.50 Finish servicing Rig, M/U Fishing BHA and RN picking up new 4° DP to a depth of 4,187'. Start 1 washing and enoaae fish at 4216', with a positive pressure increase of 500 psi. Jar on fish when [grapples released at 4,163'. POOH to find the 4.875 grapples had slipped off and the Pack off was washed out. Change to a 4.75 grapple, install a mechanical jar above the overshot, change out pack -off. 4/4/2008 9,808.0 0.00 12.50 M/U Fishing assembly with 4.75' grapple. RIM start washing at 4,163' and chase fish down to 4266' where we engaged same. Jar fish Free and POOH. Lay. down fishing BHA and Fish. www.peloton.com Page 4/8 Report Printed: 6/13 /2008 I I Operations Summary Report , 1 is End Date • Depth Start (itKS) Foot/Meters (ft) MAO Spry 14/5/2008 i 9,808.0 0.001 12.50 Lay out 9 joints of 6.75' DC used in the fishing operations, RIH with old string of 4" drill pipe and UO same. Total Joints LD =293. 4/6/2008 9,808.0. 0.00 12.55 P/11 New 4' DP to a depth of 3090' and Rack back, P/U BHA and. Shallow Pulse test the MWD. RIH with rest of BHA to a depth of 598'. P/U 28 Joints of 4' DP and I./O. P/U 75 Joints of New 4 ". DP to 2,912'. Circulate a Drill Pipe Volume and RIH on Elevators filling every 20 stands to a depth of 8,505' where we hit refusal. Wash and ream from 8,505 to 8.600, 4/7/2008 9,808.0 0.00 12.50 RIH on elevators F/ 8,600 to 8,700, Pump with no rotation F/ 8,700 to 8, 800, RIH on Elevators F/R R()0 to 8,993' where we experienced hNjg problems. Had to wash and ream Fl 8,993 to 9,764'. Extremly hard time reamng from 8,993 to 9,275'. Prepare 500 bbls of new mud for dilution and build an !additional 500 bbls 200 bbls building at RFC and 300 bbls being built at Deadhorse plant. 4/8/2008 9,808.0 0.00 12.50 Wash and Ream to 9,808. Circulate and Condition, Dilute Old mud with 500 bbls of new mud prior to short trip. Stand back 1 stand every hour to prevent under cutting holey Pull short trip F/ 9,669 to 18,525' Hit tight spots at 9,390 and 8,868 work thru same. Rill to 9,808, had to wash tight spotat 9,115'. Circulate and Condition mud and add a. second dilution of 500 bbls o#:rteiv mud, Spot LCMpf on bottom and POOH Fl 9,808 to 6,004' Hit tight spots at 9570, 8,452, (where we had to pump at 213 gin) and 6,650. Pulled to 6,050 hit tight spot, try to work thrtt no success, Circulate and clean this section using 390 gpm w/ 120 rpm. (# 1 mud pump had swab-90011f- ' ' 4/9/2008 9,808.0 0.00 12.50 Rack ream F /6,004 T/4,553'. Pump out of hole F/4,553 T/4,264. Hole cleaned up, POOH on Elevators F/4,264 T/598'. Rack back 4 stands of HWDP, LO 2 joints of HWDP &Jars and LD rest of the BHA. Test Choke manifold on the way out of the hole to AOGCC specs. Pull wear bushing, Change rams i F /4" T/7 ". PU Test joint and test plug, RIH and set. Test Upper 7" Rams and upper floor safety valve. Test Annular and lower floor safety valve. All tests at 250 low /3500 high for 5 min, as per AOGCC. Waiver on complete BOP test given by Lou Grimaldi with AOGCC. Choke manifold tested on trip out of hole. All valves tested to 250 low /3500 high and held for 5 min. 4/10/2008 9,808.0 0.00 12.50 Finish testing 7' rams and Valves, R/U Casing Crew, M/U Float, Shoe Track and Float, Baker lock shoe track connections, Fill shoe track and verify free flow of mud. RIH W/ 237 Joints of 7" 26# L-80 Bull casin • to a de • 019 74 '. ; " ` ' 4/11/2008 9,808.0E 0.001 12.50 Land out 7" casing, shoe at 9,793' & float at 9,707'. Circulate at staged rate slowly increasing to 4 'born. CBU. Cement 7 ", pump 10 bbls sea water. Drop bottom plug, mix & pump 40 bbl dual spacer mixed at 13.0 ppg, followed by 38.0 bbls (181 saxs) Premium cement + 55% Halad -344 + .2% CFR -3 + .25 Ib /sk super CBL + .25% SCR -100, mixed at 15.8 ppg, yield 1.18 w/ 5.18 gal/sx requirement. Drop top plug & pump 10 bbls sea water. Line up rig pumps & displace with 363 bbls of mud. Did not bump plug, Float holding. CIP @ 06:30. Rig down casing and cement equipment. Test 7" wellhea d I packoff to 5000 psi & held for 10 min. PU test plug and test BOP's per AOGCC requirements. Test all rams, all surface valves including Koomey draw down. Chuck Scheve with AOGCC waived witness. Test 250 psi low /3500 psi high and hold for 5 min. MWD having trouble communicating with tools. Shift operation from PU BHA to PU Drill pipe needed for next hole section. 4/12/2008 9,808.0 0.00 12.50 P/U 4° Drill Pipe while working on MWD Tools.Circulate one Drill pipe volume and POOH and .stand pipe back in Derrick. P/U BHA and Test MWD tools at 285 gpm, Test good, Load Sources. ' I www.peloton.com Page 5/8 Report Printed: 6/13/2008 1 40 1 . ,,, ,x.... 7::,.... , Operations Summary Report Last Mud Dens ' End Date Depth Start MKS) Foot/Meters (ft) WNgat) Suavest) ` 4/13/2008 9,808.0 0.00 10.60 MU BHA # 13, load sources and test - OK. Finish PU remaining pieces and do final test. Wash pipe on Top Drive leaking - change out same. While changing out washpipe, proceed with Freeze Protection of 7" x 95/8" Annulus, pumped 10 bbls 12.5 of MW. Switch to diesel & pump total of 85 bbls with initial injection pressure @ 350 psi and final injection pressure © 850 psi. Final reading on _ I rasing annulus when shut in= 1150 psi. RIH on DP filling pipe every 25 stands. Encounter drag at 9,436' desision made to wash & rem F/9,436' tT /9,682' where plug rubber was encountered. RU to ' . . • • • .. , t - • f.' zx• unable to maintain satisfacto decline. T 3 m•r- time - -r ' checkina for anv and all possible leaks on surface equipment. Consult with Town ODE and were given instructions to drill Shoe Track equipment. Finished drilling the Float CP 9,709'and went to 9,793' w/ no . cement in shoe track. Perform LOT using 11.4 0D9 MW. achieve 675 psi final leak off pressure= 14.4 mpg EMW. Record casing annulus pressure, 1080 psi at start/end. RD tesing equipment. . 4/14/2008 i 9,808 -0 20.00 10.50 Finish drilling out float equipment & BBL shoe © 9,793'; no problems encountered: Clean out !Whole, . . F/9,793' T19,808' and drilled 20' new 6 -1/8" hole to 9,828'. CBU and pulled back into casing_ Rigged to ;& performed LOT w /10.5ppg MW=13.8ppg'EMW (.6# from LOT #'1)._ Break o verpoin t= IUSdpsi.. . Casing Annulus= 1000 psi start/end. Rig down testing equipment. and. Siip/Cut drilling line, Serviced Top Drive & rig. Continue to load pipe shed w14 -1/2" Slotted tker and mbc dry lob. Pump dry job, Bk v. clown Top drive & POOH for RTTS. Remove, Source and shut down MWD Tool anal Rack Back, 4/15/2008 9,828.0 0.00 10.50, Finished RIH to 9,650' & set RTTS © 9,650'. Perform 3500psi Casing test for 1/2 hr - ok. Unsg3# 'RTTS & POOH for BHA #15, (RTSS Type). PU & MU HES tools & RIH w /same filling pipe every 25 stands. I i 4/16/2008 ' 9,828.0 0.00 ,. 10.10 Finish RIM w/BHA #15 to 9,828', (no fill). Work on Sperry communication problems to Geo Pilot, C -O Geo-Span, work on software problems -from Sperry MWD. (Total= +8hrs loss). Drill to 9,845', tracture=120BPH losses s .. Ca Carbonate .111 continue to dry to 9 882' 2nd fracture= 12t: '. • . .• . r • • ain . s • • 2nd Ca Cabonat - • 71 continue driflin. 6-1/8' Hole to 9 967. RSC mixing mud, along w/Baroid Mud plant. ( 3rd fracturf at 9.9 18Q.P1 j„jases) Pull to shoe, spot another Ca Cabonate pill incasing and monitor loses, Build: Volume. Total losses at 24:00 Hs- 911 bbl s. 4/17/2008 9,828.0 139.00 9.90 Built volume due to losses, stage pumps up to loss circulation, spot 25 Bbls Baracarb 150 LCM pill, and note losses with pill in place, 7 -8 BPH with fill across top of annulus. Drill F/ 9967' To/ 10448. Lost • , - • spotted 30 Bbls, 75# /bbl Baracarb pill. Pull slowly to shoe. Monitor losses at shoe. Mir losses with fill across top of hole 4 BPH. At report time losses down to zero with no pump. Total losses for day= 1,267 BBL's/For Well= 2,179 BBL's 1 I I I 4/18/2008 9,967.0 481.00 10.50 Inspect pits per MI personnel. Pump Form -A -Plug from vac truck to pit. TIM-while nib( spacer. Pump . spacer, add accelerator to Plug pill, pump same, Displace with 109 BBIs 9.9 road, pull to9280', well.: swabbing, rotate each stand to alleviate swab. Attempt to B /Circ. pipe.plugged, hesitate squeeze down annulus at 35 GPM for 40 Bbls with 9.9 PPG mud. Back pressure steady at 175 when well . . pump shut down. Build mud weight to 10.5 ppg, pump 110 bbls down annulus, open annularar, mud fell below well head. Fill with. 11 bbls 105 PPG. Monitor for losses, varied from 16-8 BPH IOS5 rate with , pipe static Pull F/9280 to 7863'. Check loss rates each 5 stands or if disc reparicy in hole fill volume: • 4/19/2008 10,448.01 0.00 10.50; POOH, monitor losses each 5 stds, found drift al 4005'. Static losses 13 BPH, UD plugged Drill pipe !, Ito 1511'. I 14/20/2008 10,448.0 f 0:00 10.00 POOH, LD BHA plugged with Form-A-Plug, Bull head 30 bbls to balance fluid: Bull tread 40-135L5. . i I 10.0 PPG to , RU kill Irne to OA valve to monitor well during ROPE test: Test BOPEperAbGCC " re. uirements. Bob Noble with - AOG wain ,• At, - . .• z,y 1X Annular Preventer, 250 psi IOw12500 psi high. 3X Rams; 4X Safety Valves, 1 X Choke Line Valve, 2X HCR Valves & IX Kill Line' Vahre; alt ' 250 psi IoW/3500 psi high- Choke Manifold tested on the way out of hole Buil head 10 BBLS below test plug, well static, RD test equipment. TIH with 17 stands Drill Pipe, Circ, 10:bbls SAP/4dut Plug pill ' to clear residual Form-A-Plug, 3500 units gas, slight flow when pumps shut off:'Purnp 50 BBLS 10,5 . PPG mud to induce slight losses for trip out of hole. POOH, MU new BHA, surface test same: www.peloton.com Page 6/8 Report Printed: 6/13/2008 1 40 ,, ;. , Operations Summary Report 1 I Last tut, Dens 1 End Date Depth Start (ttKB) Foot/Meters (ft) Qom) Summary 4/21/2008 10,448.0; 594.00 10.00 Finish M/U BHA #16, RIH, B/C at 427 and surface test, all OK. TIH, B/C at 3320', break in bearings verify operation of down hole tools. Circ. out 2614 units gas and balance mud column with 15 BBLs mud down pipe. TIH to 7180', CBU, expericed 3 BBL loss during TIH, well static when pipe still. Q. out 1050 units, losses 13.8% pump rate. Observed traces of Form -A -Plug on surface. TIH to 9780', i B /C, attempt to CBU, @ 1 - 90 GPM, 100% mud losses, hole full and static. TIH with BHA to 10270', with 18 -24 BPH losses, wash and ream F/ 10207- 10448', 42 SPM, 900 PSI, 100% Losses at 192 BPH. Drill 6 1/8' hole to 10945' with mud, and changed to sea water down drill string and 10.0 PPG mud Icap on annulus, Drill to 11042' at mid night. 100% losses with mud in annulus staying full. 4/22/2008 11,042.0 1,013.00 10.00 Mud cap drill to TD CO 12055' with 10.0 PPG mud. Pulled back to 107$0'. to sttemot to low side well bore using time drillincjl /10th of foot each 3 min. Lost shore Dower, started rig generator, worked to tow side well, Lost MWD, Trouble shoot same in attempt to regain operation without success. 4/23/2008 12,055.0 0.00 10.00 Trouble shoot MWD failure, Time drill blind to attempt to low side hale No success, POOH, pumping @20 spm down pipe due to swabbing. Check flow each 1000' to insure hole static. 4/24/2008 12,055.0 0.00 10.50 Continue to have to Bull Head 50 BBL's of 10.5ppg MW 0 2,939'. ISIP= 23psi, & bled off pressure & open Annular Preventer. Very slight trickle & decision made to POOH'5 std. 2BBL gain), so Buff Head 33 BBL's more. Well static, so continue to POOH, 2,458' - 1,743', w/some slight swabbing again. ; Decision after consulting Town ODE is to pump out, 1,743' -1, 298', WhereTDS grabber dies had to be C-O, (shut in well as precaution). Once dies C -O & RS performed, FS1P was 0 30ps1, so decision q was made to Bull Head another 50 BBL's of 10.Oppg MW. Bled off pressure & open up well; w /slight `'t S r 1 -2 BPH kiss rate_ Initiated pumping out, w/100% Loss rate. Continued to pump out, 1,298 -579', R i s where some flat sided wear on last couple DP. These 2x DP were LD, along w/5x 4" HWDP, lx - Drilling Jar, & 3x Flex Monels, after flowing checking 15min's, (static). Some ,flog was seen occurring i e MWD tools, and welt shut in, w/10 psi 1SIP. Decision made to Bull Head 50 BBL's 10.5ppg MW, but Istill saw some slight flow when bled off. Consult Town ODE & mix 6O BBL's of 11.Oppg MW: Pump 65spm, and monitor pressure, (ok). Bled off & well now taking 80-90 BPH larss: Cont. to till hole & handle BHA #16 twit, (LD same). 4/25/2008 12,055.0 0.00' 10.50 M/U 6 1/8" bit & razor back scraper, TIH to 977'. Slip and cut drill line, Continue to TIH to 9658', close annular, bull head 575 BBLs 10.5 PPG mud down annulus at 277 GPM, 1300 PSI. Reciprocate pipe 'between tool joints to change flow paths during bull head operation. Check for pressure, open well and observe. Well static. POOH, pump down pipe to alleviate swab, well taking proper fill with 100 % loss down pipe and filling on back side with trip tank. Monitor well every 10 stands to verify well static. 4/26/2008 12,055.0 0.00 10.20 POOH, LD BHA, RU set test plug and lock down same. Change upper rams to 2-7/8" fixed and lower u . 1 " ' , ! . Test BOPE per AOGCC requirements_ Chuck Scheeve with AOGCC waived witness to test. Annular 250 /2500psi. Rams, Choke Valves, TDS upper & lower 1BOP, Safety Valve and IBOP Valve 250/3500psi. Performed Koomey test. RD test equipment, RU & run completion tubing. Bull head 375 bbis 10.5 Sodium Bromide at 1500 psi, RD hoses. RU ESP and control line . equipment. Losses increased to 175 BPH, pumped 77 BBLs sea water on annulus to slow losses. Build 10.2 ppg brine, clean tanks and transfer brine to rig tanks. Finish Mt) ESP motors and install - power cables and control lines to run completion. 4/27/2008 12,055.0 0.00 10.20 Run 2 -7/8" L -80, IBT -M, 6.5# completion assembly with down hole pumps, GLM, packer and safety valve F/66' T/6042'. Install Canon clamps every other connection, test ESP cable and control lines every 1000' to 5000 psi. Change out 2 -7/8" handling tools for 3 -1/2" equipment. Run 3 -1/2" L -80, IBT -M, 9.3# installing Canon clamps every other connection F/6042' T/6704'. Install GLM & pups. Test every 1000'. 4/28/2008 12,055.0 0.00 10.20`Cont run completion assembly with down hole pumps, installed Canon clamps every other connection, installed ScSSSV assembly, tested ESP every 1000'. Land hanger, test hanger 5000 psi, ND BODE, change rams, NU Tree, Test Tree 250/5000 psi for 5 min. Install high pressure hoses for Bull Heading diesel. . www.peloton.com Page 7/8 Report Printed: 6/13/2008 1 • Operations Summary Report • • Last Mud Dens End Date Depth Start MKS) Font/Meters (tt) ` 0104 Summary 14/29/2008 12,055.01 0.00 8.70! Bull headed diesel for freeze protection, pumped 285 bbls diesel on inner annulus & 64 bbls diesel 1 down tubing to tum over to production. Slick line to retrieve bar & ball assembly and X -RHCM plug, 1 RD slick line. Rig released @ 1600 hrs to move to ODSN -39i. 11 www.peloton.com Page 8/8 Report Printed: 6/13/2008 Operations Summary Report. Well Name: ODSK -33 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Spud Date: 2/18 /2008 Rig Release Date: 4/28/2008 Last Mud Dens End Date • tart (RKB) Foot/Meters lit) Pbigal) Summary 2/18/2008 44.0 0.00. Secure well, shim beams to level rig, disconnect and move supply lines to allow rig to move over well bay. 2/19/2008 44.' 141.50 8.90 Reconnect supply lines in Hutz, Move rig over ODSK -33, level pad and square to well bays. Install Vetco starding head, function test diverter and gas detectors, service rig, R/U gyro wire line, Heki pre -spud safety meeting, M/U BHA, reamed out conductor to 153'. Drlg to 199', cleared plugged CCU lines. 2/20/2008 199.0 1,547. , ' 9.30 Drill, slide /rotate and survey f/199' - 1,746' MD, 1,728' TVD. 2/21 /2008 1 ,746.0 1,437.20 ' 50 Drill, (slide/rotate) and survey f/1 ,746' -3, 183' MD, 3,165' TVD. CBU Hi -vis sweep & 1.5x. POOH to i 3000', trouble shoot trip tank. 2/22/2008 3,183.2 0.00 9.50 S •rt tripped to jars, worked thru tight spots, Circulate and condition, per Mud Man, and until shakers cle POOH worked thru tight spot at 2944', cont. out of hole, racked back 5 stds HWDP, UD direct al assembly, R/U csg tools, held PJSM made up shoe jt & 1 intermediate joint and circ. thru float sh• 2/2312008 3,183.2 0.00 9.70 Run 95/8" Ca ' g, work thru tight spots from 2920' to 2985'. Land casing with hanger and landing \ joint. Circ. & Co 'ition, mix and pump cmt. Displace with 9.5 WBM. Flush diverter and riser, N/D ` fit c�ic,� @e�•. "'"'"1 same. 2/24/2008 3,183.2 0.00 9.70 Install Vetco Grey M -23 ell head, test to 5000 psi, N/U BOP stack, test BOPE Der AOGCC Regs. Slipped and cut drill line, " BHA and surface test same. P/U 4" drill pipe. 2/25/2008 183. de up BHA #2, picked up & sled in 60 its Drill pipe, service rig & top drive, drill out plugs/float bejlar and cement to 3,161', CBU attempt to test casing, POOH. 3 g--1 2/26/2008 3,18 . .• • UD and rkck back BHA #2, M/U BHA # ith RTTS and TIH, Set and test Casing 3500 psi for 30 min. • RTTS and UD same, M/U d •ctional assembly BHA #4 and TIH, Drill cmt & float shoe from 3163' to 3173'. Clean out rat hole to 3 ', drill 13' new formation at report time. 2/27/2008 3,196.0 1,625.10 9.20 Dig ahead w/ Geo -Pilot at 4,821' MD building a • to 54.56° with 281.70 azi.Drig ahead w/ Geo -Pilot at 4,821' MD building angle to 54.56° with 281.70 2/28/2008 4,821.1 1,678.90 9.60 Dig ahead w/ Geo -Pilot at 6,500.80' MD building angle to :.60° with 253.30 azi. 2/29/2008 6,500.0 1,534.00 9.80 Dig ahead w/ Geo-Pilot at 8,034' MD building angle to 66.89° 199.86° azi. 3/1/2008 8,034.0 457.70 10.50 Drill to 8491', work stuck pipe, pipe free, circulate and condition mud, iper trip to 7814' at report time. 3/2/2008 8,491.7 0.00 10.70 Finish short trip to 6640', worked thru tight spots at 7729', 7660', 7565'. TI . 8313`, safety wash and ream F/8313' To/ 8491'. Reamed out obstruction F/8474'- 8484'. Circulate an •ndition, pumped 30 Bbls hi -vis weighted sweep at 13.0 PPG WBM with 10 PPB walnut surface to - ace. Trouble shoot MWD failure, Pump 30 b•ls fresh water pill, no success, POOH to 6478', touble sot MWD while circ. and condition, no success, pump slug, POOH. Lay down BHA, un -load nuke nd down load MWD, clean balled up stabs and bit. Found small rocks in MWD pulser poppet. 3/3/2008 8,491.7 0.00 10.60 POOH, UD BHA #4, Test BOPE, M/U BHA #5, TIH. 3/4/2008 8,491.0 538.00 10.70 Finish TIH to 8400', wash to 8491', No Fill, C & C, Drill 8 3/4" hole per program to 9029'. www.peloton.com Page 1/7 Report Printed: 5/22/2008 am • Operations Summary Repor• • Last Mud Dens End Date Depth Start (ft ' Foot/Meters (ft) (Ib /gal) Summary 3/5/2008 9,029.■ 442.00 11.00 Drill 8 3/4" hole with Geo -Pilot F/ 9029' To/ 9199', C & C, attempt check trip had exess drag up to 300k at 8990'. TIH wash and ream to bottom, Drill ahead to 9471' with Geo -Pilot while building mud wt to 11.0 ppg. 3/6i2008 9,471.0 •59.00 11.00 Drill 8314° hole with Geo -Pilot F/ 9471' To/ 9682'; Circulate B /U, Drill F/ 9682' t4 9705', Circulate B/U, Drill F/ 9705' to 9730'. Back ream out of hole F/ 9730' to 9374 '.Tight Hole, Hole packing off, work tru tight spots. 3/7/2008 9,730.0 0.06 11.00 Back ream and Circulate F/ 9374' to 6960', Use Pharameters as Hole dictates. A problem exists at 5538' possible key seat, both Ghost reamers had problems coming thru this area. 3/8/2008 9,730.0 0.00 11. '0 Back Ream F/ 6960' to 5899'. Hit Tight spot and Jar pipe Free. Resume Back Reaming (15839' to 5250'. Hit second tight spot, Jar Pipe Free. Resume Back Reaming F/ 5190 to 4800'. 3/9/2008 9,730.0 0.00 11.00 B. k ream F/ 4800' to Shoe at 3173', Observe Well, Circulate B/U at Shoe and observed a lot of cu' gs upon Bottoms Up. POOH and Lay down BHA. Service Top Drive and conduct Post Jarring Derr inspection 3/10/2008 9,730.0 0.00 11.00 Finish Post Jarring rig service, M/U BHA # 6 and RIH to 8424' on Elevators, Started experiencing hole probk s and started Reaming to Bottom F/ 8424' to 8850' with no problems. at 8850' wr4 encountere• igh Torque and drag, worked thru spot at 8850' to 8884', Resume Reaming to 8919; and pipe be e stuck. Worked pipe Free and attempt to work thru this area. 3/11/2008 0.00 11.50 Pull pipe to safe e at 8696', Build Mud weight to 11.5ppg while working pipe. Wash and ream to l - 8,991'. Pipe becam stuck again. work back up to 8805 and establish good hole. Raise GPM to 500 and rotary at 150 R • and slowly wash down cleaning hole to 8836' (K &M) in an effort to clean running shale beds ca, .ed by HRZ Formation. 3/12/2008 9,730.0 0.00 12.00 Wash and ream to 8861', : - came stuck, Jar free and work pipe to 8704'. Build and displace 11.5 mud with 12.0 ppg mud. Wa and Ream F/ 8704' to 9008'. Ream at 2' FPM for 32', Backream same 32' section and log any chap. in parameters, continue with next 32' section, 500 gpm, RPM 150, Mud weight 12.0 ppg. 3/13/2008 9,730.0 0.00 12.50 Wash and Ream F/ 9008' to 9383'. -am at 2' FPM for 32', Backream same 32' section and log any change in parameters, continue with -xt 32' section. 500 gpm, RPM 150, Start Raising Mud weight from 12.0 ppg to 12.5 ppg at 9242'. Ti. spots @ 9012', 9017', 9029', 9038', 9291', 9348'. 3/14/2008 9,730.0 0.00 12.50 Wash and Ream F/ 9348" to 9,707', Hit Re al at 9707' Contact office before going any further, desision made to stop here due to the 12.5 • • mud weight change and the problems we could encounter if we hit a zone not suited for the 1 ppg Mud. Ream at 2' FPM for 32', Backream same 32' section and log any change in parameters, • tinue with next 32' section. 500 gpm, RPM 150, Mud weight 12.5 ppg. Tight spots @ 9388', 93' : :409', 9438'. Attempt survey @ 9375, Try increasing GPM, unable to communicate with M No Accidents, No Incidents, No Spills 3/15/2008 9,730.0 0.00 12.50 Hit Refusal at 9707' attempt different combinations to work .st spot, Contact office, Permission given to stop at 9707'. Circulate 3 Bottoms ups until shakers were -an, Pull a wiper trip to 8250' with no problems. RIH F/ 8,250' to 9,280'. Conserned about fluid disp ement, Wash f/ 9280' to 9707'. Circulate and displace old 12.5 ppg mud for New and Circulate •Ie clean. POOH & SLM F/ 9707' to 5130'. Test Choke Manifold to 250psi Low and 3500psi high on t ' out. I I www.peloton.com Page 2/7 Report Printed: 5/22/2008 ff Operations Summary Repor Last Mud Dens End Date Depth Start (fiKB) •.• - ters (11) (te 9a) Summary 3/16/2008 9,730.0 0.00 12.50 POOH w/ BHA # 6 F/ 5132' to Surface. Upon reaching the last joint it was discovered that the bottom tool joint was missing_a_llonn with 15" of the tube and the rest of the BHA was left in the hole. Consult with office about Plan forward. R/U and Test BOP to AOGCC regulations. While testing dispatch a Baker fishing tool hand with overshot to location. After BOP Test serviced the rig and begin P/U Fishing toots and 6 1/4" Drill collars to a depth of 320'. 3/17/2008 9,730.0 0. a 12.50 RIH w/ Fishing Assembl F/ 324' to 6,826'. Work tight spot F/ 6,826' to 6,890'. Jarred twice and work pipe back to 6,788'. RI / 6,788' to 7,000' where the fishing assembly became differentially stuck. Work pipe down with out jarring to 7,094' where weight broke over. RIH F/ 7,094' to 7,566'. Spot LCM pill across the BHA to the top of the Torok Formation @ 6,812'. RIH F/ 7,566' to 8,435'. Start washing F/ 8,435' to the Top of fish at 8,842' (Bit 0 9,438'). Hook onto and establish circulation thru tish. Pull tish tree with max overpull of 325K, no jarring. POOH w/ fish F/ 9,438' to 7,980' where the assembly became differentially stuck. ulI circulation, Can't activate Jars, Total fishing BHA length- -915') 3/18/2008 9,730.0 0.00 12.50 Wor q stuck pipe at 7.964'. Attempt many combinations of working pipe trying to activate jars. Spot 3 Lub 'Its around BHA and continue working pipe (40K down and 474K up) Spot Black Magic Pill and let soa •n an effort to free up the upper collars and work pipe in a downward motion to clear the Torok I� s sand. C( � 3/19120 f C7 > —ft . . a 0.00 12.10 Let Black M. soak, pumping 1 bbls/ Hr. Line up Schlumberger to perform free point, and Hallibuton 04-2107e, • to cement, a .et kick off plug while working pipe, at 23:15 jars started working, continue to jar fish on Up and L. Stroke in an attempt to work pipe down. 3/20/2008 9,730.0 0.00 12.20 Work stuck pipe, ce ent fish in hole, inspect traveling block and derrick. R/U SLB wire line and run free point, attempt to •p torque for back off, un -able to trap required torque without breaking pipe. Wait on severing tool. 3/21/2008 9,730.0 0.00 12.10 Wait on severing tool to a Install 1 718' severing tool on rope socket, GIH to 6620' sever pipe , ! with 25k overpull, good ind' . ion of pipe parting, CBU, POOH breaking, inspecting each break with Tuboscope personnel, re -dop: -nd re- torque to 22.4k per Nabors proceedure. t/D 4 joints with damaged faces. 3/22/2008 9,730.0 0.00 12.20 Break and ispect threads, M/U cmt • erter sub, TIH to shoe, slip and cut drill line, repair iron rough neck, TIH to TOF, spot 17.9 ppq mu. 'pull 100', circ. and condition to balance fluid. tr 3/23/2008 9,730.0 0.00 12.10 CBU, set cement kick off plAi.,100H to . 00' + - , CBU, POOH, Test BOPE, MWU 8 3/4" 1 1/2° bent housing motor side track assmbly, P/U ' ' & 4" 8-135, TIH to 2570. I j 3/24/2008 6,527.0 475.00 12.20 TIH, wash & ream F/ 5380' To/ 6527'. Had firm ement, side track well. Drill, slide & survey to 7002'. Repair module on #1 pump. 3/25/2008 7,002.0 558.00 12.20 Repare #1 center fluid module and change seal gas t, Slide, drill and survey F/ 7002' To/ 7560'. I I 3/26/2008 7,560.0 373.00 12.20 Slide, drill and survey F/ 7560' To/ 7933'. 3/27/2008 7,933.0 257.00 12.10 Slide, drill and survey F/ 7933' To/ 8190'. CBU 2 times, pull . ' elevators to 6610', pump and back ream F/ 6610' To/ 5844'. 3/28/2008 8,190.0 0.00 12.20 Work tight spot at 5844 - 5837', jar free, Back -ream to 4111', pum'p •ut F/4111' To/ 3148', CBU x2 until shakers clean, pump slug, blow down TDS, POOH, UD BHA, Sery - rig, P/U Geo- pilot, bit and program MWD. TIH. I I www.peloton.com Page 3/7 Report Printed: 5/22/2008 `� Operations Summary Repor010 Last Mud Dens End Date Depth Start (ttKB) F.. - ters (ft) (ib /gal) Summary 3/29/2008 8,190.0 427.00 12.60 TIH to shoe, CBU, TIH B/C ea. 30 stands, Tag obstruction at 7012'. Wash and ream F/ 7012 To/ 8190'., Drill F/ 8190' to/ 8617' with Geo -Pilot per SSDD and program. 3/30/2008 8,617,0 648. ,s 12.50 Drill F/ 8817' to 9265' MD, 5970' TVD with Geo -Pilot per SSDD and program. 1 3/31/2008 9,265.0 453.00 2.50 Drill F/9265' To/ 9718' , per SSDD and Program. Attempted different weights and rotary with no significant change in ROP. 4/1/2008 9,718.0 90.00 12. f rill To/9808' MD, 6072' TVD per SSDD and program. Attempt to short trip, had tight hole and essure loss, wash back to bottom and verify pressure Toss, POOH, wash and ream as needed to • out of hole with low pump rate. 4/2/2008 9,808.0 0.00 12.30 Pump 'ut of hole through multiple tight areas. Drill string failed with Top of fish at 4199' and bottom at 6224.9. Pooh with Drill pipe. R /U, test BOPE on 4" drill pipe. R/D and set wear ring. Slip and cut drill, service r M/U Baker Hughes fishing asssembly. 4/3/2008 9,808.0 0.00 12.50 Finish servici Rig, M!U Fishing BHA and RIH picking up new 4" DP to a depth of 4,187'. Start washing and e ge fish at 4216' with a positive pressure increase of 500 psi. Jar on fish when grapples releas- . t 4,163'. POOH to find the 4.875 grapples had slipped off and the Pack off was washed out. Chan - to a 4.75 grapple, install a mechanical jar above the overshot, change out pack -off. 4/4/2008 9,808.0 0.00 12.50 M/U Fishing assembly w 4.75" grapple. RIH start washing at 4,163' and chase fish down to 4266' where we engaged same. , r fish Free and POOH. Lay down fishing BHA and Fish. 4/5/2008 9,808.0 0.00 12.50 Lay out 9 jts of 6.75" DC used the fishing operations, RIH with old string of 4" drill pipe and UO same. Total Joints 'JD (293) There was an HSE incident (being - • ck). The Derrick hand when coming out of the upper Dog house 1UPERSEDED closed the door behind him only to h. - the refrigerator style door handle break off and fall to the rig �°� floor 85'. No one was on the floor at th= ime Object weight was .5 Lbs. `?' . � a� Also 6 sacks of Barite slipped off a pallet -ing loaded onto elevator. Barite was in containment and v .��... _. cleaned up. Report to follow. 4/6/2008 9,808.0 0.00 12.55 P/U New 4" DP to a depth od 3090' and Rack ba P/U BHA and Shallow Pulse test the MWD. RIH with rest of BHA to a depth of 598'. P/U 28 Joints o , " DP and 1/0. P/U 75 Joints of New 4" DP to 2,912'. Circulate a Drill Pipe Volume and RIH on Be 'tors filling every 20 stands to a depth of 8,505' where we hit refusal. Wash and ream from 8,505 to 8,. /0. 4/7/2008 9,808.0 0.00 12.50 RIM on elevators F/ 8,600 to 8,700, Pump with no rotation 8,700 to 8,800, RIH on Elevators F18,800 to 8,993' where we experienced hole problems. Had to wash •• ream F/ 8,993 to 9,764'. Extremly hard time reamng from 8,993 to 9,275'. Prepare 500 bbls of n: mud for dilution and build an additional 500 bbls 200 bbls building at RFC and 300 bbls bein • • Wit at Deadhorse plant. 4/8/2008 9,808.0 0.00 12.50 Wash and Ream to 9,808. Circulate and Condition, Dilute Old mud 500 bbls of new mud prior to short trip. Stand back 1 stand every hour to prevent under cutting hole • ull short trip F/ 9,669 to 8,525' Hit tight spots at 9,390 and 8,868 work thru same. RIH to 9,808, Id to wash tight spot at 19,115'. Circulate and Condition mud and add a second dilution of 500 bb of new mud. Spot LCM pill on bottom and POOH F/ 9,808 to 6,004' Hit tight spots at 9570, 8,452, 7,9' ' (where we had to pump at 213 gpm) and 6,650. Pulled to 6,050 hit tight spot, try to work thru no suc. -ss, Circulate and clean this section using 390 gpm w/ 120 rpm. (# 1 mud pump had swab go out ) www.peloton.com Page 4/7 Report Printed: 5/22/2008 • Operations Summary Repor• Last Mud Dens End Date Depth Start (ftKB) .n; (#t) (tb /gal) Su y 4/9/2008 9,808.0 0.00 12.50 Rack ream F/ 6,004 to 4,553', Pump out of hole F/ 4,553 to 4,264, Hole cleaned up POOH on Elevators F/ 4,264 to 598'. Rack Back 4 stands of HWDP UO 2 joints of HWDP and Jars and UD rest of the BHA. Test Choke manifold on the way out of the hole to AOGCC specs. Pull wear bushing, Change upper 4" pipe rams to 7 ". P/U Test joint and test plug, RIH and set. Test upper 7" rams and annular to AOGCC specs. 250 low 3500 high and hold for 5 min. 4/10/2008 9,808.0 0... 12.50 Finish testing 7" rams and Valves, R/U Casing Crew, M/U Float, Shoe Track and Float, Baker lock shoe track connections, Fill shoe track and verify free flow of mud. RIH W/ 237 Joints of 7" 26# L -80 Butt casing to a depth of 9,741'. 4/11/2008 9,808.0 0.00 12. • Land out 7" casing, Shoe at 9,793', Float at 9,707'. Circulate at staged rate slowly increasing to 4 bpm. Circulate B /U. Cement 7 ", Did not bump plug, Float holding. Rig down casing and cement quipment. P/U test plug and test BOP's. MWD having trouble communicating with there tools, Shift • - ration from P/U BHA to P/U Drill pipe needed for next hole section. 4/12/2008 9,808.0 0.00 12.50 P/U ' • rill Pipe while working on MWD Tools.Circulate one Drill pipe volume and POOH and stand pipe b. in Derrick. P/U BHA and Test MWD tools at 285 gpm, Test good, Load Sources. 4/13/2008 9,808.0 0.00 10.60 M/U BHA • 3 Load sources and test, Tested OK. Finish P/U remaining pieces and do final test, wash pipe leaking, hange out same. While changing out washpipe Proceed with Freeze protection of 7" x 9 5/8" Annulu RIH on DP filling pipe every 25 stands. Encounter drag at 9,436' desision made to � ' t� wash F/9,436' 9,682' where top plug was encountered. R/U to test casing to 3,500 psi , (Attempt � �� r' failed, try 3 mor- •mes after checking for any and all possible leaks on surface equipment). Perform a leak off test using 1.4 mud, w/a 14.4 EMW, (FSIP= 675 psi). Consult with Town ODE and were given instructions to drill foe Track equipment. Finished drilling the Float @ 9,709'and went to 9,793' w/ no - • in shoe trac 4/14/2008 9,808.0 20.00 10.50 Finish drilling out float eq ent & BBL shoe @ 9,793', (no problems encountered). Clean out rathoie, 9,793' to 9,808', a trilled 20' new 6 -1/8" Hole to 9,828'. CBU, and pulled back into casing. Rigged to & performed LOT 10.5ppg MW= 13.8ppg EMW, (1050psi break over point). Rig down testing equipment, and Slip/C .. rilling fine, Serviced Top Drive & rig. Continue to load pipe shed w/4 -1/2" Slotted liner and mix d 'ob. Pump dry job, Blow down Top drive & POOH for RTTS. Remove Source and shut down D Tool and Rack Back. 4/15/2008 9,828.0 0.00 10.50 Finished RIH to 9,650' & set RTTS. P= orm 3,500psi Casing test for 1 /2hr, (ok). Unseat RTTS & POOH for BHA #15, (RTSS Type). PU • U HES tools & RIH w /same filling pipe every 25 std's. 4/16/2008 9,828,0 0.00 10.10 Finish RIH w/BHA #1S to 9,828', (no fill). W • on Sperry communication problems to'Geo Pilot, C -O Geo -Span, work on software problems from ' erry MWD, (Total= +8hrs loss). Drill to 9,845', (fracture= 120BPH losses), spot Ca Carbonat 'ill, continue to drill to 9,882', (2nd fracture= 12OBPH losses again), spot 2nd Ca Cabonate pill, contin - drilling 6-1/8" Hole to 9,967'. RSC mixing mud, along w/Baroid Mud plant. ( 3rd fracture al 9,958— :0 BPH loses ) Pull to shoe, spot another Ca Cabonate pill in casing and monitor loses, Build V. e. Total losses at 24 :00 Hrs - -- 911 bbl's. 4/17/2008 9,828.0 139.00 9.90 Built volume due to losses, stage pumps up to loss circ :tion, spot 25 Bbls Baracarb 150 LCM pill, and note losses with pill in place, 7 -8 BPH with fill across •p of annulus. Drill F/ 9967' To/ 10448. Lost total returns, spotted 30 Bbls, 75# /bbl Baracarb pill. Pull sl• ly to shoe. Monitor losses at shoe. Initial I losses with fill across top of hole 4 BPH. At report time loss= down to zero with no pump. Total losses for day= 1,267 BBL's /For Well= 2,179 BBL's www.peloton.com Page 5/7 Report Printed: 5/22/2008 Operations Summary Report* Last Mud Dens End Date Depth Start (ftK8) oot/Meters (ft) WO St+mma+y 4/18/2008 9,967.0 481.00 10.50 Inspect pits per MI personnel. Pump Form -A -Plug from vac truck to pit. TIH while mix spacer. Pump spacer, add accelerator to Plug pill, pump same. Displace with 109 BBIs 9.9 mud, pull to 9280', well swabbing, rotate each stand to alleviate swab. Attempt to B /Circ. pipe plugged, hesitate squeeze down annulus at 35 GPM for 40 Bbls with 9.9 PPG mud. Back pressure steady at 175 when well pump shut down. Build mud weight to 10.5 ppg, pump 110 bbls down annulus, open annular, mud fell below well head. Fill with 11 bbls 10.5 PPG. Monitor for losses, varied from 16 -8 BPH loss rate with pipe static. Pull F/9280' to 7863'. Check loss rates each 5 stands or if discrepancy in hole fill volume. 4/19/2008 9,967.0 - 2,104.00 10.50 POOH, monitor losses each 5 stds, found drift at 4005'. Static losses 13 BPH, L/D plugged Drill pipe to 1511'. 4/20/2008 7,863.0 10. • POOH, L/D BHA plugged with Form -A -Plug. Bull head 30 bbls to balance fluid. Bull head 40 BBLS 0.0 PPG to , R/U kill line to OA valve to monitor well during BOPE test. Test BOPE per AOGCC, 'oneer & Nabors policies. Bull head 10 BBLS below test plug, well static, R/D test equipment. TIH 17 stands Drill Pipe, Circ. 10 bbls SAP /Nut Plug pill to clear residual Form -A -Plug, 3500 units ga slight flow when pumps shut off. Pump 50 BBLS 10.5 PPG mud to induce slight losses for trip out hole. POOH, M/U new BHA, surface test same. 4/21/2008 10,448.0 594.00 10.00 Finish BHA #16, RIH, B/C at 427' and surface test, all OK. TIH, B/C at 3320', break in bearings verify ope ion of down hole tools. Circ. out 2614 units gas and balance mud column with 15 BBLs mud down • • e. TIH to 7180', CBU, expericed 3 BBL loss during TIN, well static when pipe still. Circ. out 1050 un' losses 13.8% pump rate. Observed traces of Form-A-Plug on surface. TIH to 9780', B/C, attempt t. BU, @ 190 GPM, 100% mud losses, hole full and static. TIH with BHA to 10270', with 18 -24 BP • ses, wash and ream F/ 10207' - 10448', 42 SPM, 900 PSI, 100% Losses at 192 BPH. Drill 6 1I8" hole to 1945' with mud, and changed to sea water down drill string and 10.0 PPG mud cap on annulus. Dri <0 11042' at mid night. 100% losses with mud in annulus staying full. 4/22/2008 11,042.0 1,013.00 10.00 Mud cap drill to 12055' 10.0 PPG mud. Pulled back to 10780' to attempt to low side well bore ./ using time drilling 1 /10th o oot each 3 min. Lost shore power, started rig generator, worked to low side well, lost MWD, Troub hoot same in attempt to regain operation without success. 4/23/2008 12,055.0 0.00 10.00 Trouble shoot MWD failure, Tim drill blind to attempt to low side hole. No success, POOH, pumping @20 spm down pipe due t0 swat. ' •. Check flow each 1000' to insure hole static. 4/24/2008 10,805.0 a t 10.50 Continue to have to Bull Head 50 BB . of 10.5ppg MW @ 2,939'. ISIP= 23psi, & bled off pressure & ,�' a$,, open Annular Preventer. Very slight tr • le & decision made to POOH 5 std.'s, 2BBL gain), so Bull a tir ltead 33 BBL's more. Well static, so co ue to POOH, 2,458'- 1,743', w /some slight swabbing again. . Decision after consulting Town ODE is to ump out, 1,743'- 1,298', where TDS grabber dies had to be C -O, (shut in well as precaution). Once die C -O & RS performed, FSIP was @ 30psi, so decision was made to Bull Head another 50 BBL's of r.Oppg MW. Bled off pressure & open up well, w /slight 1 -2 BPH loss rate. Initiated pumping out, w/1. '% Loss rate. Continued to pump out, 1,298 -579', where some flat sided wear on last couple DP. hese 2x DP were LD, along w /5x 4" HWDP, lx Drilling Jar, & 3x Flex Monels, after flowing chec ' g 15min's, (static). Some flow was seen occurring @ MWD tools, and well shut in, w /10 psi ISIP. D- sion made to Bull Head 50 BBL's 10.5ppg MW, but still saw some slight flow when bled off. Consult T• n ODE & mix 60 BBL's of 11.0ppg MW. Pump @ 65spm, and monitor pressure, (ok). Bled off & well taking 80 -90 BPH loss rate. Cont. to fill hole & handle BHA #16 tools, (LD same). 4/25/2008 0.0 10.50 M/U 6 1/8" bit & razor back scraper, TIH to 977'. Slip and c • rill line, Continue to TIH to 9658', close annular, bull head 575 BBLs 10.5 PPG mud down annulus at '77 GPM, 1300 PSI. Reciprocate pipe between tool joints to change flow paths during bull head oper. '.n. Check for pressure, open well and observe. Well static. POOH, pump down pipe to alleviate swab, ell taking proper fill with 100 % loss down pipe and filling on back side with trip tank. Monitor well eve 10 stands to verify well static. www.peloton.com Page 6/7 Report Printed: 5/22/2008 I f 1 Operations Summary Repore Last Mud Dens End Date Depth Start (ttKB) Foot/Meters (Ib /ga1) Summary 4/26/2008 0.0 ! 10.20 POOH, UD BHA, R/U set test plug and lock down same. Change upper rams to 2 7/8" and lower to 3 1/2 ", tested BOPE per AOGCC, PNR & NAD guidelines. R/D test equipment. Bull head 375 BBLS 10.5 Sodium Bromide. R/U ESP and control line equipment. Losses increased to 175 BPH, pumped 77 BBLs sea water on annulus to slow losses. Build 10.2 ppg brine, clean tanks and transfer brine to rig tanks. Finish M/U ESP motors and install power cables and control lines. Run completion. 4/27/2008 0.0 10.20 Ru ompletion assembly with down hole pumps, GLM, packer and safety valve. Install Canon clam every other connection, test ESP cable and control lines every 1000'. 4/28/2008 0.0 10.20 Run comp ion assembly with down hole pumps, installed Canon clamps every other connection, installed Sc SV assembly, tested ESP every 1000'. Land hanger, test hanger 5000 psi, N/D BOPE, chnage rams, U Tree, Test Tree 5000 psi, Install high pressure hoses for Bull Heading diesel. 4/29/2008 0.0 8.70 Bull headed diesel freeze protection & turn over to production. Slick line to retrieve bar & ball assembly and X -RH plug, R/D slick line. Wr \ CP '" / � J 1 www.peloton.com Page 7/7 Report Printed: 5/22/2008 1 ' ",,. • Halliburton CompanA Survey Report Company: Pioneer Date: 5/19/2008 Time: 10:32 :42 Page: 1 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSK -33, True North Site: - Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 f Well: ODSK -33 Section (VS) Reference: Well (0.00N,0.00E,209.53Azi) Wellpath: ODSK -33 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSK -33 Slot Name: Well Position: +N / -S -69.47 ft Northing: 6031080.67 ft Latitude: 70 29 45.546 N +E / -W -24.12 ft Easting : 469896.50 ft Longitude: 150 14 46.161 W Position Uncertainty: 0.00 ft Wellpath: ODSK -33 Drilled From: ODSK -33PB1 507032056200 Tie -on Depth: 6446.33 ft Current Datum: ODSK -33: Height 57.50 ft Above System Datum: Mean Sea Level Magnetic Data: 5/19/2008 Declination: 22.53 deg Field Strength: 57625 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg 44.00 0.00 0.00 209.53 Survey Program for Definitive Wellpath Date: 5/19/2008 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 100.00 1003.00 ODSK -33PB1 SRG (100.00- 1003.00 SRG- Gyro -SS Conventional SRG single shots 1044.41 6446.33 ODSK -33PB1 Sag +CA +IIFR +MS (104 MWD +Sag +CA +IIFR +MBWD + Sag + CA + IIFR + MS 6527.00 11971.30 ODSK -33 Sag +CA +IIFR +MS (6527.0 MWD +Sag +CA +IIFR +M'BWD + Sag + CA + IIFR + MS Survey MD Ind Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 44.00 0.00 0.00 44.00 -13.50 0.00 0.00 6031080.67 ' 469896.50 - TIE LINE 100.00 0.23 201.27 100.00 42.50 -0.10 -0.04 6031080.57 469896.46 SRG- Gyro -SS 169.00 0.40 223.51 169.00 111.50 -0.41 -0.26 6031080.26 469896.24 SRG- Gyro -SS 263.00 0.36 329.39 263.00 205.50 -0.39 -0.63 6031080.28 469895.87 SRG- Gyro -SS 356.00 0.23 179.30 356.00 298.50 -0.33 -0.78 6031080.35 469895.72 SRG- Gyro -SS 447.00 0.50 335.84 447.00 389.50 -0.15 -0.94 6031080.53 469895.56 SRG- Gyro -SS 539.00 0.78 269.96 538.99 481.49 0.22 -1.73 6031080.89 469894.77 SRG- Gyro -SS 631.00 2.23 282.39 630.96 573.46 0.60 -4.10 6031081.29 469892.40 SRG- Gyro -SS 723.00 3.96 280.67 722.82 665.32 1.57 -8.98 6031082.28 469887.53 SRG- Gyro -SS 815.00 5.28 272.22 814.52 757.02 2.33 -16.33 6031083.06 469880.18 SRG- Gyro -SS 905.00 5.36 274.56 904.13 846.63 2.82 -24.66 6031083.59 469871.86 SRG- Gyro -SS 1003.00 4.85 271.03 1001.74 944.24 3.26 -33.36 6031084.06 469863.16 SRG- Gyro -SS 1044.41 5.09 269.67 1043.00 985.50 3.28 -36.95 6031084.10 469859.57 MWD +Sag +CA +IIFR +MS 1140.79 6.36 280.00 1138.90 1081.40 4.18 -46.48 6031085.04 469850.04 MWD +Sag +CA +IIFR +MS 1236.05 7.23 285.41 1233.49 1175.99 6.69 -57.46 6031087.59 469839.08 MWD +Sag +CA +IIFR +MS 1333.71 8.05 285.96 1330.28 1272.78 10.20 -69.96 6031091.16 469826.59 MWD +Sag +CA +IIFR +MS 1429.22 10.60 281.60 1424.52 1367.02 13.81 -84.99 6031094.82 469811.57 MWD +Sag +CA +IIFR +MS 1526.00 14.13 279.28 1519.04 1461.54 17.51 - 105.38 6031098.60 469791.20 MWD +Sag +CA +IIFR +MS 1622.24 17.14 281.26 1611.71 1554.21 22.17 - 130.89 6031103.37 469765.72 MWD +Sag +CA +IIFR +MS 1719.50 19.77 283.59 1703.96 1646.46 28.84 - 160.94 6031110.15 469735.70 MWD +Sag +CA +IIFR +MS 1816.14 19.52 285.35 1794.98 1737.48 36.95 - 192.39 6031118.40 469704.28 MWD +Sag +CA +1IFR +MS 1913.06 19.97 284.01 1886.20 1828.70 45.24 - 224.06 6031126.82 469672.64 MWD +Sag +CA +IIFR +MS 2009.74 19.20 279.16 1977.29 1919.79 51.77 - 255.78 6031133.47 469640.96 MWD +Sag +CA +IIFR +MS 2106.45 18.21 277.49 2068.89 2011.39 56.27 - 286.46 6031138.10 469610.30 MWD +Sag +CA +IIFR +MS 2202.12 17.93 277.68 2159.85 2102.35 60.19 - 315.88 6031142.13 469580.90 MWD +Sag +CA +11FR +M$ 2298.77 18.21 277.12 2251.73 2194.23 64.05 - 345.61 6031146.11 469551.19 MWD +Sag +CA +IIFR +MS 2394.74 18.27 277.16 2342.88 2285.38 67.78 - 375.41 6031149.97 469521.40 MWD +Sag +CA +IIFR +M' 2491.96 18.79 281.69 2435.06 2377.56 72.86 - 405.87 6031155.16 469490.97 MWD +Sag +CA +IIFR +M' Halliburton Companle Survey Report Company: Pioneer Date: 5/19/2008 Time: 10:32:42 Page: 2 Field; Pioneer ASP Zone 4 Co-ordinate(NE) Reference: Well: ODSK -33, True North Site: Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 Well: ODSK -33 Section (VS) Reference: Well (0-OON,0.0QE,209.53Azi) Weilpath: ODSK -33 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S FJW MYiapN MapE Tool ft deg deg ft ft ft ft ft ft 2586.99 18.73 282.57 2525.04 2467.54 79.28 - 435.75 6031161.70 469461.12 MWD +Sag +CA +1IFR +M' 2683.95 20.23 282.65 2616.45 2558.95 86.34 - 467.30 6031168.89 469429.60 MW D+Sag+CA+ I I F R+M ' 2780.25 22.79 281.22 2706.04 2648.54 93.61 - 501.85 6031176.31 469395.09 MWD +Sag +CA +IIFR +M' 2877.02 25.44 280.16 2794.35 2736.85 100.93 - 540.69 6031183.78 469356.27 MWD +Sag +CA +11FR +M' 2973.87 27.96 278.88 2880.87 2823.37 108.10 - 583.61 6031191.12 469313.39 MWD +Sag +CA +I1FR +M' 3069.17 30.84 278.49 2963.89 2906.39 115.16 - 629.85 6031198.37 469267.18 MWD +Sag +CA +IIFR +M' 3118.50 31.62 278.71 3006.07 2948.57 118.98 - 655.14 6031202.29 469241.91 MWD +Sag +CA +IIFR +M'• 3216.14 33.44 280.52 3088.39 3030.89 127.77 - 706.90 6031211.29 469190.20 MWD +Sag +CA +IIFR +M' 3260.08 33.11 280.40 3125.12 3067.62 132.15 - 730.60 6031215.76 469166.51 MWD +Sag +CA +IIFR +M' • 3356.84 33.01 281.34 3206.22 3148.72 142.10 - 782.44 6031225.93 469114.72 MWD +Sag +CA +IIFR +M' 3453.54 33.96 280.56 3286.87 3229.37 152.23 - 834.82 6031236.27 469062.39 MWD +Sag +CA +IIFR +M' 3549.51 35.50 281.37 3365.74 3308.24 162.64 - 888.49 6031246.89 469008.76 MWD +Sag +CA +IIFR +M' 3646.09 35.84 283.07 3444.20 3386.70 174.56 - 943.53 6031259.03 468953.78 MWD +Sag +CA +IIFR +M' 3743.12 35.54 283.02 3523.01 3465.51 187.34 - 998.67 6031272.03 468898.69 MW D+ Sag+CA+ I IFR +M ' 3839.50 36.70 282.21 3600.86 3543.36 199.74 - 1054.12 6031284.66 468843.31 MWD +Sag +CA +IIFR +M' 3936.26 38.23 281.79 3677.66 3620.16 211.97 - 1111.69 6031297.12 468785.79 MWD +Sag +CA +IIFR +M' 4029.91 38.59 282.95 3751.04 3693.54 224.44 - 1168.52 6031309.82 468729.02 MWD+Sag+CA+ I I FR + M ' 4129.17 41.82 282.48 3826.84 3769.34 238.53 - 1231.01 6031324.16 468666.59 MWD +Sag +CA +IIFR +M' 4222.30 42.25 282.36 3896.01 3838.51 251.94 - 1291.91 6031337.82 468605.75 MWD +Sag +CA +IIFR +M' 4322.96 43.36 280.08 3969.87 3912.37 265.24 - 1359.00 6031351.38 468538.72 MW D+Sag+CA+ I I F R+M ' 4418.57 47.23 279.30 4037.11 3979.61 276.66 - 1425.97 6031363.07 468471.80 MWD +Sag +CA +IIFR +M' 4514.44 50.18 280.70 4100.38 4042.88 289.18 - 1496.89 6031375.88 468400.94 MWD +Sag +CA +IIFR +M' 4612.33 51.19 280.66 4162.40 4104.90 303.22 - 1571.31 6031390.22 468326.59 MWD +Sag +CA +IIFR+ • 4709.56 54.56 281.69 4221.07 4163.57 318.26 - 1647.35 6031405.56 468250.62 MWD +Sag +CA +IIFR +M' 4803.27 58.08 282.56 4273.03 4215.53 334.64 - 1723.57 6031422.26 468174.47 MWD +Sag +CA +11FR +M' 4903.51 60.73 282.96 4324.05 4266.55 353.70 - 1807.72 6031441.66 468090.41 MWD +Sag +CA +IIFR +M' 4998.70 61.54 282.86 4370.00 4312.50 372.33 - 1888.98 6031460.61 468009.23 MWD + Sag +CA +IIFR +M' 5095.36 61.12 282.37 4416.37 4358.87 390.85 - 1971.74 6031479.46 467926.56 MWD +Sag +CA +IIFR +M'. 5191.96 61.08 282.19 4463.06 4405.56 408.84 - 2054.37 6031497.78 467844.00 MWD +Sag +CA +IIFR +M' 5287.35 62.20 280.59 4508.37 4450.87 425.41 - 2136.66 6031514.68 467761.80 MW D+Sag+CA+I I F R +M ' 5384.70 64.46 279.00 4552.07 4494.57 440.19 - 2222.37 6031529.82 467676.15 MWD +Sag +CA +11 FR +M' 5481.31 65.47 279.34 4592.95 4535.45 454.14 - 2308.79 6031544.12 467589.80 MWD +Sag +CA +IIFR +M' 5578.11 66.24 277.31 4632.55 4575.05 466.93 - 2396.18 6031557.25 467502.47 MWD + Sag +CA +IIFR +M' 5672.39 66.61 276.09 4670.26 4612.76 477.01 - 2482.00 6031567.68 467416.70 MWD +Sag +CA +IIFR +M' 5771.61 67.01 273.24 4709.34 4651.84 484.42 - 2572.89 6031575.46 467325.85 MWD +Sag +CA +IIFR +M' 5868.46 67.68 270.93 4746.64 4689.14 487.67 - 2662.20 6031579.07 467236.56 MWD +Sag +CA +11FR +M' 5963.54 68.13 268.61 4782.41 4724.91 487.31 - 2750.29 6031579.07 467148.48 MWD +Sag +CA +11FR +M' 6059.41 68.63 265.06 4817.74 4760.24 482.39 - 2839.26 6031574.50 467059.50 MWD +Sag +CA +IIFR +M' 6158.03 68.94 261.97 4853.44 4795.94 472.00 - 2930.59 6031564.49 466968.13 MWD +Sag +CA +IIFR +M' 6254.69 69.29 257.88 4887.91 4830.41 456.21 - 3019.48 6031549.05 466879.19 MWD +Sag +CA +IIFR +M' 6351.35 69.47 255.47 4921.96 4864.46 435.36 - 3107.51 6031528.56 466791.09 MWD +Sag +CA +IIFR +M' 6446.33 68.60 253.30 4955.94 4898.44 411.49 - 3192.92 6031505.04 466705.59 MWD +Sag +CA +11FR +M' 6527.00 70.14 250.12 4984.37 4926.87 387.79 - 3264.59 6031481.64 466633.83 MW D+Sag+CA+ IIF R+M ' 6559.05 70.76 248.87 4995.10 4937.60 377.21 - 3292.87 6031471.17 466605.51 MWD +Sag +CA +IIFR +M' 6652.96 71.12 245.88 5025.77 4968.27 343.07 - 3374.79 6031437.37 466523.46 MWD +Sag +CA +IIFR +M' 6746.88 70.80 245.40 5056.41 4998.91 306.45 - 3455.67 6031401.08 466442.44 MWD +Sag +CA +IIFR +M' 6847.03 70.51 241.07 5089.60 5032.10 263.91 - 3540.02 6031358.88 466357.93 MWD +Sag +CA +1IFR +M' 6944.63 69.96 238.64 5122.61 5065.11 217.79 - 3619.44 6031313.09 466278.33 MWD +Sag +CA +IIFR +M' 7041.68 69.47 236.72 5156.26 5098.76 169.12 - 3696.36 6031264.74 466201.22 MWD +Sag +CA +IIFR +M' 7137.55 69.27 232.47 5190.05 5132.55 117.16 - 3769.48 6031213.08 466127.90 MWD +Sag +CA +IIFR +M' 7233.36 68.27 229.47 5224.75 5167.25 60.94 - 3838.85 6031157.14 466058.31 MWD +Sag +CA +11 FR +M 7330.95 68.30 224.49 5260.88 5203.38 -0.90 - 3905.10 6031095.59 465991.81 MWD +Sag +CA +11FR +M' 1 • Halliburton Company. Survey Report Company: Pioneer Date: 5/19/2008 Time: 10 :32 :42 Page: 3 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSK -33, True North Site: Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 Well: ODSK -33 Section (VS) Reference: Well (0.00N,0.00E,209.53Azi) Wellpath: ODSK -33 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft it 7427.75 68.05 220.89 5296.87 5239.37 -66.93 - 3966.02 6031029.81 465930.63 MWD +Sag +CA +IIFR +M' 7524.34 66.74 217.82 5334.01 5276.51 - 135.86 - 4022.57 6030961.11 465873.81 MW D +Sag+CA+ I I F R+ M ' 7620.87 68.23 215.05 5370.98 5313.48 - 207.60 - 4075.51 6030889.60 465820.59 MWD +Sag +CA +IIFR +M' 7716.66 69.87 210.23 5405.24 5347.74 - 282.91 - 4123.72 6030814.49 465772.07 MW D+ Sag+CA+ I I F R+M ' 7813.96 68.91 204.10 5439.52 5382.02 - 363.88 - 4165.29 6030733.70 465730.18 MW D+ Sag +CA+ I IF R+M ' 7909.52 68.04 199.99 5474.59 5417.09 - 446.25 - 4198.66 6030651.47 465696.49 MWD +Sag +CA +IIFR +M'. 8005.52 66.14 195.74 5511.98 5454.48 - 530.38 - 4225.80 6030567.46 465669.01 MW D+Sag+CA+ I IF R+M ' 8101.66 66.51 189.89 5550.61 5493.11 - 616.18 - 4245.31 6030481.74 465649.15 MWD +Sag +CA +IIFR +M' 8191.91 67.18 186.25 5586.11 5528.61 - 698.32 - 4256.95 6030399.66 465637.18 MWD +Sag +CA +IIFR +M' 8236.29 67.02 185.25 5603.38 5545.88 - 739.00 - 4261.04 6030359.00 465632.92 MWD +Sag +CA +11 FR +M' 8333.30 67.27 180.81 5641.07 5583.57 - 828.24 - 4265.76 6030269.79 465627.84 MWD +Sag +CA +11FR +M' 8429.27 67.33 176.21 5678.13 5620.63 - 916.72 - 4263.46 6030181.32 465629.78 MWD +Sag +CA +IIFR +M' 8526.51 67.47 172.06 5715.51 5658.01 - 1005.99 - 4254.29 6030092.01 465638.59 MWD +Sag +CA +IIFR +M 8623.82 68.00 167.45 5752.40 5694.90 - 1094.58 - 4238.27 6030003.37 465654.25 MW D+Sag+CA+ I IF R +M ' 8719.01 68.26 164.50 5787.86 5730.36 - 1180.27 - 4216.86 6029917.60 465675.31 MWD +Sag +CA +IIFR +M' 8815.69 68.06 159.12 5823.85 5766.35 - 1265.49 - 4188.86 6029832.28 465702.96 MW D+Sag+CA+ I I F R+ M ' 8912.66 67.80 154.62 5860.30 5802.80 - 1348.10 - 4153.58 6029749.53 465737.91 MWD +Sag +CA +11FR +M' 9007.89 69.32 150.89 5895.12 5837.62 - 1426.88 - 4113.00 6029670.59 465778.17 MWD +Sag +CA +11FR +M' 9105.70 72.49 147.94 5927.12 5869.62 - 1506.42 - 4065.96 6029590.87 465824.88 MWD +Sag +CA +IIFR +M' 9202.41 75.05 144.99 5954.15 5896.65 - 1583.80 - 4014.66 6029513.30 465875.86 MW D+Sag+CA+ I IF R+M ' 9299.01 76.57 141.89 5977.84 5920.34 - 1659.00 - 3958.88 6029437.88 465931.33 MWD +Sag +CA +IIFR +M' 9395.25 78.80 138.68 5998.37 5940.87 - 1731.31 - 3898.80 6029365.33 465991.11 MWD +Sag +CA +IIFR +M' 9491.55 78.47 138.32 6017.35 5959.85 - 1802.02 - 3836.24 6029294.38 466053.37 MWD +Sag +CA +IIFR +M'. 9588.08 78.97 138.50 6036.23 5978.73 - 1872.82 - 3773.40 6029223.33 466115.92 MWD +Sag +CA +11FR +M' 9685.23 80.05 137.59 6053.91 5996.41 - 1943.86 - 3709.54 6029152.04 466179.48 MWD +Sag +CA +IIFR +M' 9779.84 82.37 136.17 6068.37 6010.87 - 2012.10 - 3645.64 6029083.55 466243.11 MWD +Sag +CA +IIFR +M' 9834.63 84.61 137.70 6074.58 6017.08 - 2051.86 - 3608.47 6029043.64 466280.11 MWD +Sag +CA +IIFR +M' 9930.64 88.84 139.42 6080.07 6022.57 - 2123.70 - 3545.05 6028971.55 466343.23 MWD +Sag +CA +11FR +M' 10026.87 87.59 137.11 6083.07 6025.57 - 2195.47 - 3481.03 6028899.53 466406.95 MWD +Sag +CA +11FR +M' 10123.19 88.27 135.23 6086.55 6029.05 - 2264.91 - 3414.37 6028829.83 466473.32 MWD +Sag +CA +1IFR +M' 10219.86 88.21 135.04 6089.51 6032.01 - 2333.39 - 3346.21 6028761.08 466541.20 MWD +Sag +CA +IIFR +M'. 10316.26 90.19 136.64 6090.86 6033.36 - 2402.54 - 3279.06 6028691.67 466608.06 MWD +Sag +CA +IIFR +M' 10427.92 87.16 132.25 6093.44 6035.94 - 2480.68 - 3199.40 6028613.21 466687.40 MWD +Sag +CA +11FR +M' 10524.37 87.59 129.98 6097.86 6040.36 - 2544.03 - 3126.81 6028549.58 466759.72 MWD +Sag +CA +11FR +M' 10620.26 89.76 131.22 6100.08 6042.58 - 2606.41 - 3054.03 6028486.91 466832.24 MW D+Sag+CA+ I I F R+M ' 10717.59 89.81 132.93 6100.44 6042.94 - 2671.63 - 2981.79 6028421.40 466904.21 MWD +Sag +CA +IIFR +M' 10813.81 92.05 136.19 6098.88 6041.38 - 2739.12 - 2913.26 6028353.64 466972.47 MWD +Sag +CA +IIFR +M' 10910.20 98.52 141.70 6090.00 6032.50 - 2811.41 - 2850.26 6028281.10 467035.16 MWD +Sag +CA +IIFR +M' 11007.96 96.41 138.62 6077.30 6019.80 - 2885.82 - 2788.16 6028206.45 467096.95 MWD +Sag +CA +IIFR +M' 11102.59 94.87 138.07 6068.00 6010.50 - 2956.18 - 2725.58 6028135.84 467159.25 MW D+Sag+CA+ I IF R+M ' 11199.97 92.64 132.68 6061.62 6004.12 - 3025.31 - 2657.34 6028066.45 467227.19 MWD+Sag+CA+I IFR+M • 11296.06 89.67 127.74 6059.68 6002.18 - 3087.30 - 2584.00 6028004.16 467300.27 MWD +Sag +CA +1IFR +M' 11391.00 90.31 128.94 6059.69 6002.19 - 3146.19 - 2509.54 6027944.98 467374.49 MWD +Sag +CA +IIFR +M' 11489.43 90.55 129.03 6058.96 6001.46 - 3208.11 - 2433.03 6027882.75 467450.74 MWD +Sag +CA +I1FR +M' 11585.92 90.80 132.24 6057.82 6000.32 - 3270.94 - 2359.82 6027819.64 467523.69 MW D+Sag+CA+ I IF R+M ' 11682.47 90.61 136.54 6056.63 5999.13 - 3338.46 - 2290.85 6027751.84 467592.38 MWD +Sag +CA +IIFR +M' 11779.02 91.30 139.11 6055.02 5997.52 - 3410.00 - 2226.04 6027680.05 467656.89 MWD +Sag +CA +1IFR +M' 11874.76 89.99 141.73 6053.94 5996.44 - 3483.77 - 2165.05 6027606.04 467717.57 MWD +Sag +CA +I1FR +M' 11971.30 90.00 142.16 6053.95 5996.45 - 3559.79 - 2105.54 6027529.79 467776.77 MWD +Sag +CA +IIFR +M' 12055.00 90.00 142.16 6053.95 , 5996.45 - 3625.89 - 2054.20 6027463.49 • 467827.84 PROJECTED to TD 1 f - • Halliburton Compan4 Survey Report Company: Pioneer Date: 5/19/2008 Time: 10:27:32 Page: 1 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSK -33, True North Site: Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 Well: ODSK -33 Section (VS) Reference: Well (0.00N,0.00E,241.83Azi) Wellpath: ODSK -33P81 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSK -33 Slot Name: Well Position: +N / -S -69.47 ft Northing: 6031080.67 ft Latitude: 70 29 45.546 N +E / -W -24.12 ft Easting : 469896.50 ft Longitude: 150 14 46.161 W Position Uncertainty: 0.00 ft Wellpath: ODSK -33PB1 Drilled From: Well Ref. Point 507032056201 Tie -on Depth: 44.00 ft Current Datum: ODSK -33: Height 57.50 ft Above System Datum: Mean Sea Level Magnetic Data: 2/18/2008 Declination: 22.67 deg Field Strength: 57618 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +NI -S +E/ -W Direction ft ft ft deg 44.00 0.00 0.00 241.83 Survey Program for Definitive Wellpath Date: 5/19/2008 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.00 1003.00 ODSK -33PB1 SRG (100.00- 1003.00 SRG- Gyro -SS Conventional SRG single shots 1044.41 9697.58 ODSK -33PB1 Sag +CA +IIFR +MS (104 MWD +Sag +CA +IIFR +MWD + Sag + CA + IIFR + MS Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Taal ft deg deg ft ft ft ft ft ft 44.00 0.00 0.00 44.00 -13.50 0.00 0.00 6031080.67 469896.50 TIE LINE 100.00 0.23 201.27 100.00 42.50 -0.10 -0.04 6031080.57 469896.46 SRG- Gyro -SS 169.00 0.40 223.51 169.00 111.50 -0.41 -0.26 6031080.26 469896.24 SRG - Gyro -SS 263.00 0.36 329.39 263.00 205.50 -0.39 -0.63 6031080.28 469895.87 SRG- Gyro -SS 356.00 0.23 179.30 356.00 298.50 -0.33 -0.78 6031080.35 469895.72 SRG- Gyro -SS 447.00 0.50 335.84 447.00 389.50 -0.15 -0.94 6031080.53 469895.56 SRG - Gyro -SS 539.00 0.78 269.96 538.99 481.49 0.22 -1.73 6031080.89 469894.77 SRG- Gyro -SS 631.00 2.23 282.39 630.96 573.46 0.60 -4.10 6031081.29 469892.40 SRG- Gyro -SS 723.00 3.96 280.67 722.82 665.32 1.57 -8.98 6031082.28 469887.53 SRG- Gyro -SS 815.00 5.28 272.22 814.52 757.02 2.33 -16.33 6031083.06 469880.18 SRG- Gyro -SS 905.00 5.36 274.56 904.13 846.63 2.82 -24.66 6031083.59 469871.86 SRG - Gyro -SS 1003.00 4.85 271.03 1001.74 944.24 3.26 - 33.36 6031084.06 469863.16 SRG- Gyro -SS 1044.41 5.09 269.67 1043.00 985.50 3.28 -36.95 6031084.10 469859.57 MWD +Sag +CA +IIFR +M' 1140.79 6.36 280.00 1138.90 1081.40 4.18 -46.48 6031085.04 469850.04 MWD +Sag +CA +1IFR +M' 1236.05 7.23 285.41 1233.49 1175.99 6.69 -57.46 6031087.59 469839.08 MWD +Sag +CA +1IFR +M' 1333.71 8.05 285.96 1330.28 1272.78 10.20 -69.96 6031091.16 469826.59 MWD +Sag +CA +IIFR +M • 1429.22 10.60 281.60 1424.52 1367.02 13.81 -84.99 6031094.82 469811.57 MWD +Sag +CA +11FR +M' 1526.00 14.13 279.28 1519.04 1461.54 17.51 - 105.38 6031098.60 469791.20 MWD +Sag +CA +1IFR +M 1622.24 17.14 281.26 1611.71 1554.21 22.17 - 130.89 6031103.37 469765.72 MWD +Sag +CA +IIFR +M' 1719.50 19.77 283.59 1703.96 1646.46 28.84 - 160.94 6031110.15 469735.70 MWD +Sag +CA +IIFR +M' 1816.14 19.52 285.35 1794.98 1737.48 36.95 - 192.39 6031118.40 469704.28 MWD+Sag+CA+ I I F R+M ' 1913.06 19.97 284.01 1886.20 1828.70 45.24 - 224.06 6031126.82 469672.64 MWD +Sag +CA +IIFR +M' 2009.74 19.20 279.16 1977.29 1919.79 51.77 - 255.78 6031133.47 469640.96 MWD +Sag +CA +1IFR+ • 2106.45 18.21 277.49 2068.89 2011.39 56.27 - 286.46 6031138.10 469610.30 MWD +Sag +CA +IIFR +M' 2202.12 17.93 277.68 2159.85 2102.35 60.19 - 315.88 6031142.13 469580.90 MWD +Sag +CA +11FR +M' 2298.77 18.21 277.12 2251.73 2194.23 64.05 - 345.61 6031146.11 469551.19 MWD +Sag +CA +IIFR +M' 2394.74 18.27 277.16 2342.88 2285.38 67.78 - 375.41 6031149.97 469521.40 MWD +Sag +CA +IIFR +M • 2491.96 18.79 281.69 2435.06 2377.56 72.86 - 405.87 6031155.16 469490.97 MWD +Sag +CA +IIFR +M 2586.99 18.73 282.57 2525.04 2467.54 79.28 - 435.75 6031161.70 469461.12 MWD +Sag +CA +IIFR +MS J • Halliburton CompanA Survey Report Company: Pioneer Date: 5/19/2008 Time: 10:27 :32 Page: 2 Field: Pioneer ASP Zone 4 Co-ordinate(NE) Reference: Well: ODSK -33, True North Site: Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 Well: ODSK -33 Section (VS) Reference: Well (0.00N,0.00E,241.83Azi) Wellpath: ODSK -33P81 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S FJW MapN MapE Tool ft deg deg ft ft ft ft ft ft 2683.95 20.23 282.65 2616.45 2558.95 86.34 - 467.30 6031168.89 469429.60 MWD +Sag +CA +IIFR +M 2780.25 22.79 281.22 2706.04 2648.54 93.61 - 501.85 6031176.31 469395.09 MWD +Sag +CA +I1FR +M' 2877.02 25.44 280.16 2794.35 2736.85 100.93 - 540.69 6031183.78 469356.27 MWD +Sag +CA +IIFR +M' 2973.87 27.96 278.88 2880.87 2823.37 108.10 - 583.61 6031191.12 469313.39 MWD +Sag +CA +IIFR +M'• 3069.17 30.84 278.49 2963.89 2906.39 115.16 - 629.85 6031198.37 469267.18 MWD +Sag +CA +11FR +M' 3118.50 31.62 278.71 3006.07 2948.57 118.98 - 655.14 6031202.29 469241.91 MW D+Sag+CA+I I F R+M ' 3216.14 33.44 280.52 3088.39 3030.89 127.77 - 706.90 6031211.29 469190.20 MWD +Sag +CA +IIFR +M' 3260.08 33.11 280.40 3125.12 3067.62 132.15 - 730.60 6031215.76 469166.51 MWD +Sag +CA +IIFR +M' 3356.84 33.01 281.34 3206.22 3148.72 142.10 - 782.44 6031225.93 469114.72 MWD +Sag +CA +IIFR +M'• 3453.54 33.96 280.56 3286.87 3229.37 152.23 - 834.82 6031236.27 469062.39 MWD+Sag+CA+IIFR+M 3549.51 35.50 281.37 3365.74 3308.24 162.64 - 888.49 6031246.89 469008.76 MWD +Sag +CA +1IFR +M' 3646.09 35.84 283.07 3444.20 3386.70 174.56 - 943.53 6031259.03 468953.78 MWD +Sag +CA +IIFR +M' 3743.12 35.54 283.02 3523.01 3465.51 187.34 - 998.67 6031272.03 468898.69 MWD +Sag +CA +IIFR +M' 3839.50 36.70 282.21 3600.86 3543.36 199.74 - 1054.12 6031284.66 468843.31 MWD +Sag +CA +IIFR +M' 3936.26 38.23 281.79 3677.66 3620.16 211.97 - 1111.69 6031297.12 468785.79 MWD +Sag +CA +IIFR +M' 4029.91 38.59 282.95 3751.04 3693.54 224.44 - 1168.52 6031309.82 468729.02 MWD +Sag +CA +11FR +M'• 4129.17 41.82 282.48 3826.84 3769.34 238.53 - 1231.01 6031324.16 468666.59 MWD +Sag +CA +IIFR +M' 4222.30 42.25 282.36 3896.01 3838.51 251.94 - 1291.91 6031337.82 468605.75 MWD +Sag +CA +11FR +M' 4322.96 43.36 280.08 3969.87 3912.37 265.24 - 1359.00 6031351.38 468538.72 MWD +Sag +CA +IIFR +M' 4418.57 47.23 279.30 4037.11 3979.61 276.66 - 1425.97 6031363.07 468471.80 MWD +Sag +CA +IIFR +M' 4514.44 50.18 280.70 4100.38 4042.88 289.18 - 1496.89 6031375.88 468400.94 MWD +Sag +CA +11 FR +M' 4612.33 51.19 280.66 4162.40 4104.90 303.22 - 1571.31 6031390.22 468326.59 MWD +Sag +CA +I1 FR +M' 4709.56 54.56 281.69 4221.07 4163.57 318.26 - 1647.35 6031405.56 468250.62 MWD +Sag +CA +I1FR +M' 4803.27 58.08 282.56 4273.03 4215.53 334.64 - 1723.57 6031422.26 468174.47 MWD +Sag +CA +IIFR +M'• 4903.51 60.73 282.96 4324.05 4266.55 353.70 - 1807.72 6031441.66 468090.41 MWD +Sag +CA +IIFR +M'• 4998.70 61.54 282.86 4370.00 4312.50 372.33 - 1888.98 6031460.61 468009.23 MW D +Sag+CA+ I I FR+ M ' 5095.36 61.12 282.37 4416.37 4358.87 390.85 - 1971.74 6031479.46 467926.56 MWD +Sag +CA +IIFR +M' 5191.96 61.08 282.19 4463.06 4405.56 408.84 - 2054.37 6031497.78 467844.00 MWD +Sag +CA +IIFR +M'• 5287.35 62.20 280.59 4508.37 4450.87 425.41 - 2136.66 6031514.68 467761.80 MWD +Sag +CA +11 FR +M' 5384.70 64.46 279.00 4552.07 4494.57 440.19 - 2222.37 6031529.82 467676.15 MWD +Sag +CA +IIFR +M' 5481.31 65.47 279.34 4592.95 4535.45 454.14 - 2308.79 6031544.12 467589.80 MWD +Sag +CA +11FR +M' 5578.11 66.24 277.31 4632.55 4575.05 466.93 - 2396.18 6031557.25 467502.47 MWD +Sag +CA +IIFR +M' 5672.39 66.61 276.09 4670.26 4612.76 477.01 - 2482.00 6031567.68 467416.70 MWD +Sag +CA +11 FR +M' 5771.61 67.01 273.24 4709.34 4651.84 484.42 - 2572.89 6031575.46 467325.85 MWD +Sag +CA +IIFR +M' 5868.46 67.68 270.93 4746.64 4689.14 487.67 - 2662.20 6031579.07 467236.56 MWD +Sag +CA +IIFR +M' 5963.54 68.13 268.61 4782.41 4724.91 487.31 - 2750.29 6031579.07 467148.48 MWD +Sag +CA +I1FR +M' 6059.41 68.63 265.06 4817.74 4760.24 482.39 - 2839.26 6031574.50 467059.50 MWD +Sag +CA +11FR +M' 6158.03 68.94 261.97 4853.44 4795.94 472.00 - 2930.59 6031564.49 466968.13 MWD +Sag +CA +IIFR +M' 6254.69 69.29 257.88 4887.91 4830.41 456.21 - 3019.48 6031549.05 466879.19 MW D+Sag+CA+ I I FR+M ' 6351.35 69.47 255.47 4921.96 4864.46 435.36 - 3107.51 6031528.56 466791.09 MWD +Sag +CA +11 FR +M'• 6446.33 68.60 253.30 4955.94 4898.44 411.49 - 3192.92 6031505.04 466705.59 MW D+Sag+CA+ I I F R+M ' 6542.75 67.44 250.70 4992.04 4934.54 383.87 - 3277.95 6031477.77 466620.46 MWD +Sag +CA +IIFR +M' 6639.92 67.36 247.94 5029.38 4971.88 352.19 - 3361.87 6031446.44 466536.42 MWD +Sag +CA +11FR +M'• 6735.97 67.67 246.05 5066.12 5008.62 317.51 - 3443.55 6031412.09 466454.60 MWD +Sag +CA +IIFR +M' 6831.27 66.95 243.29 5102.89 5045.39 279.90 - 3523.01 6031374.81 466375.00 MWD +Sag +CA +IIFR +M' 6929.34 66.54 239.56 5141.62 5084.12 236.82 - 3602.12 6031332.05 466295.72 MW D+Sag+CA+ I IFR+M ' 7025.73 66.75 234.89 5179.85 5122.35 188.93 - 3676.50 6031284.47 466221.16 MWD +Sag +CA +IIFR +M' 7122.87 67.03 230.70 5217.99 5160.49 134.92 - 3747.64 6031230.75 466149.81 MWD +Sag +CA +IIFR +M' 7219.81 66.75 225.53 5256.06 5198.56 75.42 - 3813.99 6031171.53 466083.22 MWD +Sag +CA +11FR +M'• 7313.48 66.35 223.35 5293.34 5235.84 14.08 - 3874.15 6031110.43 466022.82 MWD +Sag +CA +IIFR +M$ , 7410.60 66.09 221.18 5332.51 5275.01 -51.69 - 3933.92 6031044.92 465962.79 MWD +Sag +CA +IIFR +M 7508.63 66.77 218.27 5371.71 5314.21 - 120.79 - 3991.34 6030976.06 465905.10 MWD +Sag +CA +I1FR +M Halliburton Compan0 Survey Report Company: Pioneer Date: 5/19/2008 Time: 10:27 :32 Page: 3 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSK -33, True North Site: Oooguruk ODS Vertical (TVD) Reference: ODSK -33: 57.5 Well: ODSK -33 Section (VS) Reference: Well (0.00N,0.00E,241.83Azi) Wellpath: ODSK -33PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Tncl Azim TVD Sys TVD NIS ENV MapN MapE Tool ft deg deg ft ft ft it It ft 7605.08 66.31 213.98 5410.12 5352.62 - 192.23 - 4043.49 6030904.83 465852.67 MWD +Sag +CA +IIFR +MS 7700.80 65.72 210.88 5449.04 5391.54 - 266.03 - 4090.38 6030831.23 465805.48 MWD +Sag +CA +IIFR +MS 7795.77 66.19 207.27 5487.75 5430.25 - 341.82 - 4132.52 6030755.63 465763.04 MWD +Sag +CA +I1FR +MS 7892.05 66.67 203.23 5526.26 5468.76 - 421.61 - 4170.14 6030675.99 465725.10 MWD +Sag +CA +I1FR +MS 7992.03 66.89 199.20 5565.69 5508.19 - 507.24 - 4203.38 6030590.50 465691.52 MWD +Sag +CA +IIFR +MS 8087.82 67.09 194.48 5603.15 5545.65 - 591.60 - 4228.91 6030506.26 465665.65 MWD +Sag +CA +IIFR +MS 8184.95 67.24 190.12 5640.86 5583.36 - 679.04 - 4247.97 6030418.91 465646.23 MWD +Sag +CA +IIFR +MS 8281.39 67.53 186.19 5677.96 5620.46 - 767.14 - 4260.60 6030330.87 465633.26 MWD +Sag +CA +IIFR +MS 8377.45 67.96 181.90 5714.36 5656.86 - 855.80 - 4266.86 6030242.24 465626.63 MWD +Sag +CA +IIFR +MS 8472.71 68.25 176.64 5749.90 5692.40 - 944.14 - 4265.73 6030153.91 465627.40 MWD +Sag +CA +IIFR +MS 8569.61 68.04 174.09 5785.98 5728.48 - 1033.77 - 4258.46 6030064.25 465634.31 MWD +Sag +CA +IIFR +MS 8665.61 68.03 170.85 5821.89 5764.39 - 1122.02 - 4246.80 6029975.97 465645.61 MWD +Sag +CA +I1FR +MS 8762.35 68.75 165.60 5857.54 5800.04 - 1210.02 - 4228.44 6029887.90 465663.61 MWD +Sag +CA +IIFR +MS 8859.64 69.73 161.09 5892.04 5834.54 - 1297.15 - 4202.37 6029800.68 465689.33 MWD +Sag +CA +IIFR +MS 8956.12 72.38 156.83 5923.38 5865.88 - 1382.28 - 4169.59 6029715.42 465721.76 MWD +Sag +CA +IIFR +MS 9053.48 75.26 154.64 5950.51 5893.01 - 1467.50 - 4131.16 6029630.06 465759.84 MWD +Sag +CA +11 FR +MS 9149.87 77.85 150.74 5972.93 5915.43 - 1550.77 - 4088.15 6029546.62 465802.51 MWD +Sag +CA +IIFR +MS 9245.34 80.12 148.77 5991.17 5933.67 - 1631.71 - 4040.94 6029465.50 465849.38 MWD +Sag +CA +IIFR +MS 9341.99 81.19 146.27 6006.86 5949.36 - 1712.15 - 3989.73 6029384.86 465900.26 MWD +Sag +CA +IIFR +MS 9439.18 79.67 143.71 6023.02 5965.52 - 1790.64 - 3934.76 6029306.16 465954.91 MWD +Sag +CA +1IFR +MS 9535.88 81.32 140.01 6039.00 5981.50 - 1865.63 - 3875.87 6029230.94 466013.49 MWD +Sag +CA +IIFR +MS 9632.05 79.57 136.69 6054.96 5997.46 - 1936.48 - 3812.86 6029159.83 466076.21 MWD +Sag +CA +IIFR +MS 9697.58 80.19 134.95 6066.48 6008.98 - 1982.74 - 3767.90 6029113.40 466120.97 MWD +Sag +CA +IIFR +MS 9730.00 80.19 134.95 6072.00 6014.50 - 2005.31 - 3745.29 6029090.74 466143.49 PROJECTED to TD ODSK -33 oduction Well Propo Completion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 153' MDrkb / 153' TVDrkb t 3 -1/2 ", 9.3# L -80 IBT -M to 3500' MD 2 -7/8" ScSSSV, 2.313" ID @ 762' 2 -7/8" GLM, 1.5" FO -2, DV @ 3510' MDrkb / 3333' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3173' MDrkb / 3052' TVDrkb X Nipple, 2.313" ID @ 4002' MD 7" x 2 -7/8" Packer @ 4021' MDrkb / 3744' TVDrkb X Nipple, 2.313" ID w RHC -M Profile @ 4038' MD 2 -7/8 ", 6.5# L -80 IBT -M 2 -7/8" GLM, 1.5" FO -2, DV @ 8010' MDrkb / 5514' TVDrkb lo ESP Cable 2 -7/8" Durasleeve Sliding Sleeve (open), 2.313" ID @ 9429' MDrkb XN Nipple w /CAT SV, 2.205" ID Nogo @ 9443' MDrkb Centrilift ESP @ 9556' MDrkb Estimated Top of Cement @ 8793' MD 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 9793' MDrkb / 6070' TVDrkb 12055' MDrkb / 6054' TVDrkb ' Date: Revision By: Comments `74 04/24/08 JDF OH Completion `Y 4 ODSK -33 Producer Well Schematic PIONEER NATURAL RESOURCES . S iti\ ' 1 ii,A i',,, [ iii\ I if C ) I I ,,, f l I [ 0 I - i U 12 SARAH PALIN, 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 Vance Hazzard Drilling Superintendent Pioneer Natural Resources Alaska Inc. 700 G Street Ste 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk- Kuparuk Oil Pool, ODSK -33 Sundry Number: 308 -154 Dear Mr. Hazzard: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, *1. . *4, • : oner DATED this 4day of April, 2008 End. �� KL IzIVtu U STATE OF ALASKA APR 2 3 2008 ALASKA OIL AND GAS CONSERVATION COMMIS ION 6-3 APPLICATION FOR SUNDRY APPROVA Oil & Gas Cons. Commission 20 AAC 25.280 A c Grave 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver Other U Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program El . Pull Tubing Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development 151 Exploratory ❑ 207 -183 / 308 -088 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 700 G Street, Suite 600, Anchorage, AK 99501 50- 703 - 20562 -00 • 7. KB Elevation (ft): 9. Well Name and Number: 57.5' ODSK -33 8. Property Designation: 10. Field/Pools(s): ADL 355036 . Oooguruk / Kuparuk • 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): 12055 6054 12055 6054 N/A N/A Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 101' 16" 157' 157' 1640 psi 670 psi Surface 3117' 9 -5/8" 3173' 3096' 5750 psi 3090 psi Intermediate 9544' 7" 9793' 6083' 7240 psi 5410 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft): N/A 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ISI Service p 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/22/2008 Oil 0 Gas ❑ Plugged ❑ Abandoned ❑ 16. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya, 343 -2111 Printed Name V ce Hazzard Title Drilling Superintendent Signature 6th Phone 343 -2116 Date 4/22/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 '— 51../ Plug Integrity p BOP Test p Mechanical Integrity Test ❑ Location Clearance p Other: Subsequent Form Required: ‘ ...k rA , C(., / al W(A. APPROVED BY Approved by: 'I � fj ISSIONER THE COMMISSION Date: ¢• . ...Og . A f E��ooa l / /�� /®.S Form 10 -403 Revised 07/200C RIG ' Submi in uplicate • Pioneer Natural Resources Alaska (PNRA) ODSK -33 Deviation from the Approved Permit to Drill (207 -183) Current Operations: Nabors 19AC is currently pumping out of the hole to the intermediate casing shoe at 9,793' MD. We have drilled to a depth of 12,055' MD. Geologically we hit a hard streak that kicked us up to the high side of the reservoir and has put our wellbore in a non - optimum placement. An attempt was made to perform an open -hole sidetrack from 10,780' to optimize the placement of the wellbore — this attempt was unsuccessful. With the end of PNRA's unrestricted drilling season at midnight tonight, we have decided to end the well at this total depth. Plan Forward: We currently plan to leave the well as an openhole, "barefoot ", completion in the lateral, V which is a deviation from the approved permit to drill. With a "barefoot" lateral, PNRA would still complete the well as an ESP producer, as is currently planned and permitted. PNRA justification: Logs suggest that the lower portion of the Oooguruk - Kuparuk reservoir is a more optimum location than the current placement of the lateral and had we not run out of time during this drilling season, we would have sidetracked this well. As such, PNRA plans to re -enter the ODSK -33 well during the unrestricted drilling season, which starts after Oct 31, 2008. Placing a liner in the well at this time would limit PNRA's ability to re -drill the lateral economically and efficiently, thus providing a non - optimum resource recovery. Prior to the time that PNRA is able to re -enter the ODSK -33 well for re -drill, PNRA would like to place the well on production to recover some resource and data from the wellbore. • • 'F k ` RECEI APR Z 3 2008 Alaska al & Gas eon C o PIONEER image mmiss►on NATURAL RESOURCES ALASKA, INC April 22, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry Notice to open hole complete the ODSK -33 horizontal lateral, PTD (207 -183) Surface Location: 2,965' FSL, 1102' FEL, T13N, R7E, UM X = 469,896.5 Y = 6,031,080.67, ASP 4 NAD27 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to leave the lateral section of the ODSK -33 as an open hole completion. The remainder of the completion v will be in accordance to the approved Permit to Drill (207 -183). Please find attached information for your review: 1) Form 10 -403 Application for Sundry. 2) Documentation on the current well conditions and justification for leaving the lateral "barefoot ". The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vance Hazzard, Drilling Superintendent (20 MC 25.070) (907) 343 -2116 vance.hazzard@pxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) (907) 343 -2133 tavia.jackson@pxd.com Sincerely, eti,tot i nce Hazzard Drilling Superintendent Attachments: Form 10 -403 Supporting information cc: ODSK -33 Well File 700 G STREET, STE. 600 • ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Franks, James [James. Franks @pxd.com] Sent: Wednesday, April 23, 2008 10:33 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance; Davies, Stephen F (DOA) Subject: RE: PTD (207 -183) ODSK -33 update Tom, I dropped off the hard copies of the 10-403 for the ODSK -33 well this morning. I look forward to hearing a reply. Should you require more information, please let me know. We are currently tripping our drilling BHA out of the hole and will be running a scraper next and then be ready to run our ESP completion. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, April 22, 2008 11:04 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance; Davies, Stephen F (DOA) Subject: RE: PTD (207 -183) ODSK -33 update James, Thanks for the information. This well has surely been trying. As discussed, a sundry should be submitted for the change to open hole. Please also include some discussion supporting Pioneer's decision. A 407 should be submitted completing the well with the current BHL. Since this action will complete the well, when you return to the well later this year a new 401 will be needed. By our convention, we consider the remaining drilling to be a redrill. That will make for a name change, possibly to ODSK -33A. Call or message with any questions. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Tuesday, April 22, 2008 10:56 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: PTD (207 -183) ODSK -33 update Tom, Thanks for your time. I know you are busy. Current operations: 4/23/2008 Page 2 of 2 • • We have drilled to 12,055' in the Oooguruk - Kuparuk reservoir and attempted to OH Sidetrack the well at 10,780' and were unsuccessful. We are going to end the well here — for now. Plan Forward: Leave the well as an open hole completion and run our completion as planned. We intend on coming back to this well at our earliest opportunity (after Oct 31) and drilling to our planned TD — our reason for not running the liner. I will get you a 10 -403, Sundry of Operations today. Let me know if you have any questions or comments. Thanks! James James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 -343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 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. 4/23/2008 • S Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 23, 2008 4:26 PM To: 'Polya, Joe' Cc: OoogurukDrillingSupervisor, Franks, James; Hazzard, Vance; AOGCC North Slope Office Subject: RE: ODSK -33 (207 -183) — Two Items —1. Notification of Closing Annular Preventer while POOH and 2. Request to RIH without retesting Annular Preventer. Joe, et al, It is acceptable to defer testing the annular preventer until the test of the tubing rams. Also, we show the last BOP test occurred on April 19 making the next one due not later than April 26. Call or message with any questions. Tom Maunder, PE AOGCC Original Message From: Polya, Joe [mailto:Joe.Polya @pxd.coml Sent: Wednesday, April 23, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Franks, James; Hazzard, Vance Subject: ODSK -33 -- Two Items -- 1. Notification of CLosing Annular Preventer while POOH and 2. Request to RIH without retesting Annular Preventer. Mr. Maunder, As per our phone conversation I would like to address to items: 1. The Drill Site Leader (Jim Brown) notified your AOGCC field representative (Mr. Noble) that we closed our annular while Pooh with the bha at -2900 feet due to slight flow and measured 75 psi. We have gone through three cycles of bullheading 10.5 ppg drilling fluid which effective gains static conditions on the well after which the next 5 stands are pulled -- the well is currently static and we are continuing to pooh. the rig bullheadeds 50 bbls of 10.5 ppg viscosified drill -n fluid (polymer based drilling fluid with CaCO3) to kill the well. * The well bore history -- we experienced total losses while trying to drill ahead after encountering a fault at -10,400'. Since then the well was extended to -12,000 feet while mud cap drilling -- maintaining the back side full with the 10.0 ppg dril -n fluid and pumping sea water down the drill string. * The rig is circulating with the hole fill pump on the back side while pulling out of the hole from the 7" casing shoe @ 9793' and -- fill volumes are recorded to ensure correct fill for pipe displacement. * after every five stands the hole fill pump is shut down monitor to monitor for flow. * if the well shows any signs of flow it is shut in on the annular and 10.5 ppg dril -n fluid is bullhead into the back side to kill the well. This technique has proven successful on the prior trip to change bha and is proving effective on this trip. * The formation pressure is 9.8 ppg equivalent mud weight and the fluids ranging between 10.0 ppg to minimize losses while drilling to 10.5 ppg to maintain overbalance while tripping. * Static Losses have flucuated between 4 to 16 barrels per hour at the 1 S various stages of the well over the last the recent days. 2. I am requesting that AOGCC allows Pioneer to make the scraper run without requiring a retest of the annular preventer -- the next BOPE test is scheduled for April 29th on the 7 DAY TEST CYCLE. The BOP rams will be changed to tubing size and retested prior to running completion directly after the scraper run. * The forward plan is to RIH with casing scraper run immediately after Laying Down the current bha -- the casing scrapers will be run on the same 4" drill pipe that this hole section has been drilled with. Thank you for your consideration of this matter, Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources 907 -244 -0668 *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2 Page 1 of 1 I Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 22, 2008 1:50 PM To: John Hellen (john.hellen ©pxd.com) Cc: Regg, James B (DOA) Subject: Drill Notification Contacts: John Hellen Eia John, I confirm receipt of your notice that a spill drill is in progress involving the ODSK -33 well. You reported that the "incident" began at 12:30 pm. Please advise if there is anything further you need. Tom Maunder, PE AOGCC 6/5/2008 Page 1 of 2 41 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 22, 2008 11:04 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance; Davies, Stephen F (DOA) Subject: RE: PTD (207 -183) ODSK -33 update James, Thanks for the information. This well has surely been trying. As discussed, a sundry should be submitted for the change to open hole. Please also include some discussion supporting Pioneer's decision. A 407 should be submitted completing the well with the current BHL. Since this action will complete the well, when you return to the well later this year a new 401 will be needed. By our convention, we consider the remaining drilling to be a redrill. That will make for a name change, possibly to ODSK -33A. Call or message with any questions. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Tuesday, April 22, 2008 10:56 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: PTD (207 -183) ODSK -33 update Tom, Thanks for your time. I know you are busy. Current operations: We have drilled to 12,055' in the Oooguruk - Kuparuk reservoir and attempted to OH Sidetrack the well at 10,780' and were unsuccessful. We are going to end the well here — for now. Plan Forward: Leave the well as an open hole completion and run our completion as planned. We intend on coming back to this well at our earliest opportunity (after Oct 31) and drilling to our planned TD — our reason for not running the liner. I will get you a 10 -403, Sundry of Operations today. Let me know if you have any questions or comments. Thanks! fames James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 -343 -2179 Statement of Confidentiality: 6/23/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 2:16 PM To: ' Polya, Joe' &"1 Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Franks, James; AOGCC North Slope Office Subject: RE: Request for Possible BOPE Test Extension beyond 7 Day Test Cycle for Nabors 19AC Rig on ODSK -33 Well. Joe, Jim and I have spoken. It is acceptable to proceed as you plan and perform the next BOP test (hopefully) prior to running the slotted liner. Keep the Inspectors informed as usual. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Monday, April 14, 2008 2:14 PM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Franks, James Subject: Request for Possible BOPE Test Extension beyond 7 Day Test Cycle for Nabors 19AC Rig on ODSK -33 Well. Mr. Maunder, As per our phone conversation, Pioneer is requesting approval to RIH with the Rotary Stowable to drill our 6 -1/8" lateral hole section (approximately 5400 feet of hole to drill) prior to our next BOP Test (approximate test would be now be April 18th, 2008)? • Date of Last BOPE Test: April 10, 2008. • Date of Next BOPE Test Requirement: April 17, 2008. Current Operation: • POOH after successfully 30 minute 3500 psi test on 7" casing with RTTS set above float collar. Forward Plan: • Pooh and LD the RTTS. MU and RIH with 6 -1/8" rotary steerable assembly and drill -5400 feet of lateral hole section. o Should complete this and be back on surface with bit on April 18th. • Test BOPE prior to RIH with 4 -1/2" liner. Note: The rig has established an excellent record with regard to BOP Equipment Test Performance and Procedure - a reasonable portion of the Nabors 19AC BOP Tests have been witnessed by the North Slope AOGCC representatives. 7'44, poe Poe q a Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer 4/14/2008 • • Maunder, Thomas E (DOA) — From: Polya, Joe [Joe.Polya©pxd.com] Sent: Sunday, April 13, 2008 12:34 PM To: Maunder, Thomas E (DOA); thomas.maunder©alaska.gov Cc: Hazzard, Vance; Foerster, Catherine P (DOA) Subject: RE: Request to Drill Kuparuk Interval on ODSK 33 based on data to support casing intergrity from Top of Cement Mr. Maunder, Thank you for your careful consideration and prompt attention to this matter. The rig has been instructed to POOH and will PU an RTTS -- then RIH to set above the float collar and test the casing to 3500 psi. Joe Polya From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Sun 4/13/2008 12:19 PM To: Polya, Joe; thomas.maunder @alaska.gov Cc: Hazzard, Vance; Foerster, Catherine P (DOA) Subject: RE: Request to Drill Kuparuk Interval on ODSK -33 based on data to support casing intergrity from Top of Cement Joe and Vance, I have spoken with Commissioner Foerster regarding the situation on ODSK -33. Casing integrity is a primary well construction requirement. It is normally demonstrated as you planned, prior to drilling out of the casing. Absent any other constraints, the standard practice when a casing test fails is to trip and employ a retrievable packer set above the shoe to clearly demonstrate the integrity of the casing. We believe that it is prudent to demonstrate the casing integrity before drilling ahead. Your plan to drill ahead prior to testing the casing is not accepted. Tom Maunder, PE AOGCC - - -- Original Message Fro • Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: •- 4/13/2008 11:47 AM To: Maunder, homas E (DOA); thomas.maunder @alaska.gov Cc: Hazzard, Va Subject: Request to : '11 Kuparuk Interval on ODSK -33 based on data to support cas' intergrity from Top of -nt Mr. Maunder, Pursuant to our phone conversation, I am : oviding the foil. ng information to support Pioneer's request to drill the 6.125" horizo later. .rior to achieving a 3500 psi casing test. We have indications as noted below pressure was leaking though the shoe track into the Kuparuk formation during the c., ng te- As a result the 7" casing and cement job will provide isolation of all - - ssures and f .'.s while confining these to the 7" casing and Kuparuk formation -- f ermore, the 7" casing :.ove the Top of Cement is Isolated from the 7" x 9 -5/8" as-. us demonstrating good casing i -rgrity as observed in the attempted casing test two Leak Off Tests (attached). Therefo - Pioneer is confident that the 6.1 : hole section can be drilled without compromising .fety to individuals or ha.- o the environment -- and all formations and pressures enc...tered will be conf'. : to Kupaurk formation. Confidence in the cement isolation above the Kuparuk Zone based on the cement job 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, April 13, 2008 12:20 PM To: Polya, Joe; thomas.maunder @alaska.gov Cc: Hazzard, Vance; Foerster, Catherine P (DOA) Subject: RE: Request to Drill Kuparuk Interval on ODSK -33 based on data to support casing intergrity from Top of Cement o ' — kSs3 Joe and Vance, I have spoken with Commissioner Foerster regarding the situation on ODSK -33. Casing integrity is a primary well construction requirement. It is normally demonstrated as you planned, prior to drilling out of the casing. Absent any other constraints, the standard practice when a casing test fails is to trip and employ a retrievable packer set above the shoe to clearly demonstrate the integrity of the casing. We believe that it is prudent to demonstrate the casing integrity before drilling ahead. Your plan to drill ahead prior to testing the casing is not accepted. Tom Maunder, PE AOGCC Original Message From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Sun 4/13/2008 11:47 AM To: Maunder, Thomas E (DOA); thomas.maunder @alaska.gov Cc: Hazzard, Vance Subject: Request to Drill Kuparuk Interval on ODSK -33 based on data to support casing intergrity from Top of Cement Mr. Maunder, Pursuant to our phone conversation, I am providing the following information to support Pioneer's request to drill the 6.125" horizontal lateral prior to achieving a 3500 psi casing test. We have indications as noted below that pressure was leaking though the shoe track into the Kuparuk formation during the casing test. As a result the 7" casing and cement job will provide isolation of all pressures and fluids while confining these to the 7" casing and Kuparuk formation -- furthermore, the 7" casing above the Top of Cement is Isolated from the 7" x 9 -5/8" annulus demonstrating good casing intergrity as observed in the attempted casing test and two Leak Off Tests (attached). Therefore, Pioneer is confident that the 6.125" hole section can be drilled without compromising safety to individuals or harm to the environment -- and all formations and pressures encountered will be confined to Kupaurk formation. 1. Confidence in the cement isolation above the Kuparuk Zone based on the cement job indictations: * The 7" casing was set and cemented @ 9793' and (3' tvd and 13' md) below the top of the Kuparuk Zone. * Rigid Blade centralizers were employed at one per joint across the entire 1000 ' and of cemented interval. * The cement was displaced at 4 bpm ( -175 fpm annular velocity) with full returns and pressure increase observed to indicate hydraulic lift of the cement exiting the shoe and displacing drilling fluid in the 7" x 8.5" annulus. * The plug was not bumped; however, the floats held and while running into the hole with the drilling assembly the top of cement was found just 22' above the float collar @ 9682' md. 2. The 7" x 9 -5/8" annulus pressure remains constant with no evidence of pressure communication during the casing test or either of two leak off tests. * Casing tested to 3500 psi with 3.81 bbls and bled back to 1800 psi in 5 minutes and 1300 psi in 10 minutes. 7" x 9 -5/8" annulus remained at 1050 psi through out test. 1 * Followed s with a simulated L.O.T. proc ,, with bit above the shoe track which equated to a 14.3 ppg EMW with 11.4 ppg drilling fluid. 7" x 9 -5/8" annulus remained at 1050 psi through out test. * Drilled the plug and 22' of ratty cement above the plug, drilled float collarat 9705' and and encounted wet shoe track while washing and reaming to the Reamer Shoe at 9791' md. Displaced to production interval drilling fluid and drilled Reamer Shoe and 20' of new formation to 9828'. * Performed an official L.O.T. @ 13.8 ppg with 10.5 ppg drilling fluid. 7" x 9 -5/8" annulus remained at 1050 psi through out test. 3. A fracture gradient for the offset Ivik #1 well was measured at 13.8 ppg EMW during a stimulation job. This is consistent with the L.O.T. above and the simulated L.O.T. through what Pioneer believes was a leaking shoe track. Pioneer proposes that the 7" casing can be tested prior to running completion. After RIH with slotted liner and prior to releasing running tool, the 7" casing can be tested against the liner top packer to 3500 psi to fully comply with the casing test requirements. Thank you for you time and prompt consideration of this matter. The rig has just completed slipping and cutting drill line and is servicign the top drive at this time. Please call with any questions, Joe Polya 907 - 244 -0668 *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 2 PION•ER • -- - c - t'J� L;�. -�! RESOURCES DATE: 4/12/2008 LEASE: Oooguruk WELL #: ODSK -33 FIELD: Oooguruk Unit CASING SIZE, WEIGHT, GRADE: 7.0" 26 ppf L -80, IBT -M WINDOW CASING SHOE MEASURED DEP 9,682 FT. WINDOW CASING SHOE T.V.D. 6,073 FT. MUD WEIGHT: 11.4 PPG 80 % CASING BURST: 5,792 PSI VISCOSITY: 45 SEC. CASING TEST PRESSURE: 3500 PSI HYDROSTATIC PRESSURE: 3600 PSI FORMATION TEST PRESSURE: 950 PSI EQUIVALENT MUD WEIGHT: I 14.41 PPG I EMW CASING TEST BARRELS Pressure 4000 - -- _ 0 0 3500 0.25 250 0.5 525 3250 0.75 710 1 975 3500 1.25 1125 3000 1.5 1400 1.75 1650 2 1910 2750 2.25 2150 3000 - - 2.5 2150 2500 2.75 2395 3 2700 3.25 2910 2250 3.5 3150 2500 3.75 3350 2000 3.81 3500 2000 1 1750 I \ V s. 1500 1500 1250 1000 1000 750 TIME Pressure 0 3500 500 5 1800 500 10 1300 250 15 20 25 0 30 0 0 10 20 30 40 50 0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 Minrdas Bartels OPEN HOLE LOT I BARRELS Pressure 0.25 0 0.5 0 0.75 225 1200 - -- 1 350 1loo 1.25 450 1000 1.5 650 1.75 900 so0 2 1000 eoo 2.25 m 700 ISIP 1000 v so0 1 min 925 0. 500 2 min 850 400 3 min 800 Sao 7 /... 4 min 750 T T T 1 200 8 min 675 100 0 • i 0.25 0.5 0.75 1 1.25 1.5 1.75 2 2.25 ISIP 1 min 2 min 3 min 4 min 5 min Barrels Company Man Jim Brown / Herb Hupperich p PIONRER 0 NA RFeaOURCFS DATE: 4/13/2008 LEASE: Oooguruk WELL #: ODSK -33 FIELD: Oooguruk Unit CASING SIZE, WEIGHT, GRADE: 7.0" 26 ppf L -80, IBT -M WINDOW CASING SHOE MEASURED DEP 9,808 FT. WINDOW CASING SHOE T.V.D. 6,075 FT. MUD WEIGHT: 10.5 PPG 80 % CASING BURST: 5,792 PSI VISCOSITY: 42 SEC. CASING TEST PRESSURE: 3500 PSI HYDROSTATIC PRESSURE: 3317 PSI FORMATION TEST PRESSURE: 1050 PSI EQUIVALENT MUD WEIGHT: I 13.82 PPG EMW CASING TEST BARRELS Pressure 0 0 4000 - 0.25 250 0.5 525 3260 0.75 710 1 975 3500 1.25 1125 3000 1.5 1400 1.75 1650 2750 2 1910 2.25 2150 3000 2.5 2150 2500 2.75 2395 3 2700 3.25 2910 2250 3.5 3150 2500 3.75 3350 2000 3.81 3500 E Z � z 1750 m 2000 E. a 1500 1500 1250 1000 1000 - 750 TIME Pressure 500 0 3500 5 1800 500 10 1300 250 15 20 0 25 30 ' 0 0 10 20 30 40 50 0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 Minutes OPEN HOLE LOT BARRELS Pressure 0.25 50 0.5 200 0.75 300 1200 - -- 1 375 1100 1.25 450 1000 1.5 500 1.75 575 900 2 650 800 2.25 700 d 700 2.5 825 5 2.75 925 d 600 3.25 1050 a 500 400 - ISIP 1050 300 1 min 980 _ 2 min 970 200 3 min 950 100 4 min 900 0 5 min 880 0.25 0.5 0.75 1 1.25 1.5 1.75 2 2.25 2.5 2.75 3.25 !SIP 1 min 2 min 6 min 860 Barrels 7 min 850 Company Man Jim Brown / Herb Hupperich Page 1 of 1 • Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Thursday, April 03, 2008 10:44 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Campoamor, Kathy Subject: Oooguruk Update MS i . - Tom, !wanted to give you an update as to what is happening on the Oooguruk Development for Pioneer Natural Resources. Following the drilling to TD of the second try, we developed a washout in the drillstring and subsequently lost the BHA. We are now in the process of retrieving the BHA and as I type this note, we are -1500' from the surface shoe with the bit. With all the difficulties on this well, we are not going to get back over the ODSK -36i well prior to the end of the unrestricted drilling season and as such will also need to tum in a 10-407 for that well. The permits for ODSN -40 and ODSN -39i were tumed in around the middle of March. Would you happen to know their status? I have requested diverter waivers for both of those wells and am trying to do a bit of planning for the rig. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 -343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 4/5/2008 • • Page 1 of 1 Regg, James B (DOA) From: Crisp, John H (DOA) Sent: Saturday, March 29, 2008 7:30 AM To: OoogurukDrillingSupervisor; DOA AOGCC Prudhoe Bay Cc: Polya, Joe; Franks, James; Jackson Jr., Robert; Klepzig, Rod Subject: RE: BOPE Test Rodney, sorry I missed your page yesterday. Thanks for calling this morning. I am 100% sure I will not be out there to witness your BOP test when you next POOH. The choke test can be performed when Pioneer & Nabors feel it is safe to do so. When we are going to witness your BOP test we will ask to see the choke test. In the past it has not been AOGCC policy to request Operator to POOH for weekly BOP test. Please test BOP's when you POOH or contact AOGCC Senior Petroleum Engineers Tom Maunder or Jim Regg. Looks like from the e mail Mr. Brown sent that the assembly that is presently in the hole was RIH 03- 27 -08. Could BOP's have been tested 03 -27 -08 to make sure Operation is in compliance with AOGCC regulations for weekly test? Thank you & good luck with your Operations. From: OoogurukDrillingSupervisor [mailto:OoogurukDrlgCm @pxd.com] Sent: Thursday, March 27, 2008 12:38 PM To: DOA AOGCC Prudhoe Bay Cc: Polya, Joe; Franks, James; Jackson Jr., Robert; Klepzig, Rod Subject: Re: BOPE Test Gentlemen, we are going in the hole today w/a Rotary steerable assembly to "TD" the well bore @ approx. 9,710', (@ 8,200'), w /in 72 hrs & then run 7" casing. We had a State Witness test by Mr. Lou Grimaldi on the last test, (Mar. 22, 2008), which he was satisfied. I would like to ask for the possibility of a BOPE test extension at this time, as it will appear might be ready to run the 7" casing, but would have to test BOPE on trip out w /BHA, (exceed past 24:00hrs, Mar. 29th dead line). Have been experiencing a lot of reaming w /past BHA out of hole, in older section of well bore, and would be glad to converse daily to update on well status, as do not want to be out hole very long prior to having to run casing, (Thoughts /or questions). Please advise of decision for request, & thanks for attention to this matter JB Jim Brown Rig Supervisor: Gravel, Snow, & Shallow Water Pioneer Natural Resources (Alaska), Inc. Anchorage Office # 1- 907 - 277 -2700 Home # 1- 403 - 547 -0825 E mail: jim.hroW*pxd.com Pioneer Camp On Ooogurak Island, AK Office # 1- 907 - 670 - 6606/6609 Fax # 1- 907 - 670 -6673 Pioneer /Cruz Camp @ Hansen - Anchor Pt., AK Office # 1- 907 - 226 -2180 *New Contact Numbers* This email was sent on 3/27/08 at 1:37 PM by brownji. D — % / t 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. 4/1/2008 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request Abandon„ I Suspend U Operational shutdown LJ Perforate U Waiver Li Merl/ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ V\ , L) lc Change approved program a Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ '-O 'fZS ‘d1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Pioneer Natural Resources Alaska Inc. Development o Exploratory ❑ 207 -183 3. Address: Stratigraphic ❑ Service ❑ 6. API Number 700 G Street, Suite 600 50- 703 - 20562 -00 7. KB Elevation (ft): 9. Well Name and Number. 57.5 ODSK -33 8. Property Designation: 10. Field/Pools(s): ADL 355036 Oooguruk/Kuparuk 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): 9707' 6072' 7058' 5193' n/a 7058 -7974' and (916') Casing Length Size MD TVD Burst Collapse Structural n/a n/a n/a n/a n/a n/a Conductor 101' 16" 157' ' 157 ' 1640 psi 670 psi Surface 3117 9-5/8" 3173' 3096' 5750 psi 3090 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (10: n/a n/a n/a n/a n/a Packers and SSSV Type: n/a Packers and SSSV MD (ft): n/a 12. Attachments: Description Summary . of Proposal Li 13. Well Class after proposed work: Detailed Operations Program p BOP Sketch ❑ Exploratory ❑ Development D service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: W8/2008 Oil El Gas ❑ Plugged ❑ Abandoned ❑ 16. Verbal Approval: Date: 3 tck oc.,0 WAG ❑ GINJ ❑ WINJ 0 WDSPL ❑ Commission Representative: Cr w.e.,S<c t -.0c1 t� ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact / Printed Name A. 1 h _ e 1D adw, ,l4r 7v Pleiti NTUND'6`e' ' Signature one Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 03 O 88 • Plug Integrity J. BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ �1 - \C - -� ti` Vti©r kU % q t S' C� ���l a C- o- `v � e e� "her: Subsequent Form Required: ��L CA - loll s k'vw..0 4d \ G- Esc) © �� APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: 3 /2o ( (? Form 10-403 Revised 07/2005 DUPLI CATE t 128Subm • t RECEIVED PIONEER MAR 1 9 2008 NATURAL RESOURCES ALASKA, INC March 19, 2008 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 Sundry Notice to P&A ODSK -33PB1 and Sidetrack ODSK -33 Surface Location: ODSK -33PB1 and ODSK -33 2,965' FSL, 1102' FEL, T13N, R7E, UM X = 469,896.5 Y = 6,031,080.67, ASP 4 NAD27 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to P&A the lower interval in the ODSK -33PB1 and sidetrack the well as ODSK -33 and re -drill the lower interval to a Kuparuk intercept close to the original target. A drilling and fishing bha is currently stuck in the well and exhaustive attempts to free it have been unsuccessful. The bha does not have any nuclear sources. The bha is currently stuck in the well 1756' and above TD at 9730' md/6072' tvd. The top of the bha is at 7067' md/5199' tvd and extends to 7974' md/5559' tvd. The Torok Shale, HRZ Shale and the Kalubik Shales are exposed in the open hole between the bha and the Kuparuk reservoir top at 9696' md/6066' tvd. It was discovered that the clean out bha was left in the well when POOH on Friday March 14 A fishing bha run was successful in latching onto the clean out bha at 8842'. While pulling out of the hole with the fish the jars went off in a tight spot with the bit at 7974' and on the evening of March 16` Full circulating capabilities have been possible during the entire time the pipe has been stuck; however, approximately 230 feet of spiral collars are sitting across the Torok Sands and it is believed that this portion of the bha became differentially stuck before the pipe could be freed from the tight spot that was pulled into — attempts to stoke the bumper sub or activate the jars have been unsuccessful. Exhaustive efforts have been employed to free the pipe without success to include pulling maximum allowable tension on the drilling string, torque and slump and spotting an 80 bbl Black Magic Pill across the BHA on Monday March 17 Pioneer proposes circulating a 12.5 ppg density cement abandonment plug around the entire fishing and drilling bha -- displacement will be calculated to leave cement inside the bha as well. This cement blend has a 1200 psi compressive strength and is the same density as the drilling fluid to prevent it from swapping out and migrating down hole in the 67 degree angle well. A dual spacer will be employed to promote good cement bond with the bha and formation to create an effective seal. The shales below the bha and above the Kuparuk reservoir should collapse over time further sealing off the Kuparuk reservoir. DUPLICATE 700 G STREET, STE. 600 • ANCHORAGE, ALASKA 99501 • MAIN: 4907) 277 -2700 • • Alaska Oil & Gas Conservation Commission May 21, 2007 Page 2 of 2 A strain gauge will be run on wireline to verify a free point above the bha followed by a string shot to back off the drill string. Then a second cement plug mixed to a 17.0 ppg density will be spotted utilizing the balanced plug method to extend the P &A plug and serve as a kick off plug. The drill string will then be POOH, a full BOP test will be performed and an 8 -3/4" directional drilling assembly will be RIH to kick off the plug and drill to the intermediate casing point in the Kuparuk reservoir. Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) A copy of the proposed P&A Procedure. 3) The directional plan for the sidetrack. 4) P&A Diagram. 5) All casing strings, drilling fluid and cementing programs, BOP Schematics and well bore diagrams will be implemented as per the programs approved by AOGCC as per the original Permit to Drill Form 10 -401. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vance Hazzard, Drilling Superintendent (20 AAC 25.070) (907) 343 -2116 vance.hazzard@pxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) (907) 343 -2133 tavia.jackson@pxd.com Sincerely 4 , 10 9 ance Ha D rilling Superintendent Attachments: Form 10-403 Supporting permit information cc: ODSK -33 Well File 1 Pioneer Natural Resources ODSK -33PB1 P &A and ODSK -33 Side Track Plug Procedure 1. The Kuparuk Interval is penetrated at 9696' and and TD is at 9730' md. The BHA is currently stuck off bottom 1756' off bottom at 7974' md. Circulation is possible with full returns. The Torok Shale, HRZ Shale and Kalubik Shales are exposed between the BHA and TD in the Kuparuk reservoir. 2. Pioneer proposes the following P &A and Sidetrack procedure. a. A P &A plug will be circulated into place around and inside the bha with 12.5 ppg cement which is equal density to the current drilling fluid. b. The rig will close the bag and shut in on a TIW valve at surface. c. While waiting on cement a wireline unit will be rigged up to perform a free point and back off. d. After the drill pipe is backed off above the bha, a second sidetrack cement plug equaling 17.0 ppg will be spotted utilizing the balanced plug method. e. The drill string will then be POOH, a full BOP test will be performed and an 8 -3/4" directional drilling assembly will be utilized to kick off the plug and drill to the intermediate casing point in the Kuparuk reservoir. 3. Circulate out the Black Magic Pill and separate at surface. 4. R/U Halliburton. 5. Pump 25 bbl Lead Dual Spacer. a. Based upon a 5 -10 minute contact time @ 5 bbl /min. 6. Pump 39 bbl Cement. a. Volume to cover BHA (30% excess) and ID. 7. Pump 5 bbl Tail Dual Spacer. 8. Drop dart. 9. Pump 65 bbl of mud displacement to spot cement. Spacer Lead 25 n/a Cement 39 n/a Spacer Tail 5 n/a Mud Displacement to s.ot 65 772 Total 134 772 10. Shut in and wait on cement — RU Schlumberger wireline unit. 11. RIH to free point. 12. RIH w/ string shot and back off. 13. Pull up above Torok Sand and reciprocate pipe. 14. R/D Schlumberger. 15. R/U Halliburton. 16. Pump 25 bbl Lead Spacer. 17. Pump 44 bbl Cement. a. Volume to cover BHA (30% excess). 18. Pump 5 bbl Tail Spacer. 19. Drop dart. 20. Pump 60 bbl of mud displacement to spot cement. Pioneer Natural Resources ODSK -33 • S • acer Lead 25 n/a Cement 44 n/a S•acer Tail 5 n/a Mud Displacement to s•ot 60 715 Total 134 715 21. POOH. 22. Test BOPE as per Permit. 23. MU 8 -3/4" directional drilling assembly. 24. RIH, Dress off top of cement plug and sidetrack well as per directional program ODSK -33 wp09. ODSK -33 2 Pill Spotting Procedure March 17, 2008 • • Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSK -33 - Slot ODS -33 ODSK -33 KupA Plan: ODSK -33 KupA wp09 Standard Proposal Report 18 March, 2008 HALLI BURTON Sperry Drilling Services • WELL DETAILS: ODSK -33 REFERENCE INFORMATION HALL1®URTON (w� WelODSK- 33- Slot ODS- 33, True Nore, ' Coordhlah Reference G roun d L eve l : 13 Vertical (TVD) Reference: 42.5' • 13.5' 0 56.0ft (Nabors 19AC) '" .,, :rr•..•a - +N / - +F/ - Northing Easting Iatittude Longitude Slot Measured Depth Reference: 42.5' • 13.5' © 56.Oft (Nabors 19AC) . Sperry Drilling IS.rvtons 0.0 0.0 6031080.67 469896.50 70° 29' 45.546 N 150° 14' 46.161 W ODS -33 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO- ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name p TVD +N/-S +E/-W Northing Easting Shape Calculation Method: Minimum Curvature Project: Oooguruk Developement KupA v6 T1 6066.0 - 1930.5 -3604.7 6029164.95 466284.35 Point on Error System: ISCWSA KupA v6 T2 B 6102.8 - 2528.9 - 3092.8 6028564.57 466793.75 Point Ewn Surface: Method: Tray. Cyl C oni North Site: Oooguruk Drill Site KupA v6 T3 6118.8 - 3415.0 - 2388.3 6027675.74 467494.64 Point Error Surface: Elliptical Conic Well: ODSK -33 KupA v6 77 6123.1 - 6621.6 -631.9 6024462.34 469237.84 Point Warning Method: Rules Based Wellbore: ODSK 33 KupA KupA v6 T6 6129.8 - 6046.1 -947.2 6025039.05 468924.94 Point KupA w O9 KupA v6 T5 6143 9 -5292.1 -13 0.2 6025794.70 4685 Plan: ODSK -33 Ku 15.04 Point p p KupA SURVEY PROGRAM Date: 2008-03-18T00:00:00 Validated: Yes Version: FORMATION TOP DETAILS Depth From Depth To Survey /Plan Tool 98.8 1001.8 ODSK -33 KupA Gyro CB-GYRO-SS NDPath TVDssPath MDPath Formation 1043.2 6700.0 ODSK -33 KupA MWD MWD +SAG +CA +IIFR +M 167a ssPath MDPath Base t i Permanfrost 6700.0 15186.0 ODSK -33 KupA wp09 MWD +SAG +CA +IIFR +M .0 2332.0 2276.0 2383.4 Top West Sak 4 DDI = 6.86 2839.0 2783.0 2926.9 Hue Shales W 2944.0 2888.0 3046.3 Tuffaceous Shales SECTION DETAILS 4013.0 3957.0 4384.0 Confining Shale 5021 0 4965.0 6620.1 Top Torok Sand Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target 5286 0 5230.0 7307.3 Base Torok Sand 1 6700.0 67.56 246.73 5051.7 330.4 - 3414.1 0.00 0.00 -4.6 5797.0 5741.0 8634.5 Top HRZ End Dir 8994.00' MD, 5919.60' TVD 2 6800.0 67.54 242.41 5089.9 290.7 - 3497.5 4.00 -91.00 42.8 5923.0 5867 0 9004.7 Base HRZ 3 7317.1 67.50 220.00 5289.8 -6.2 - 3866.8 4.00 -94.45 373.4 6001.0 5945.0 9264.0 Kalubik Marker 5? I 4 7778.7 67.50 200.00 5467.9 -373.1 - 4078.7 4.00 -93.86 758.8 6065.0 6009.0 9600.4 Top Kuparuk C 5 8994.0 71.61 148.04 5919.6 - 1455.6 - 3958.2 4.00 -95.17 1825.0 Start Dir 4.50/100' 9144.10' MD, 5967.00' ND 6 9144.1 71.61 148.04 5967.0 - 1576.4 - 3882.8 0.00 0.00 1938.1 1200 * I 7 9406.1 80.00 139.50 6031.3 - 1780.8 - 3732.6 4.50 -45.76 2127.2 CASING DETAILS I 8 9606.1 80.00 139.50 6066.0 - 1930.5 - 3604.7 0.00 0.00 2264.2 KupA v6 T1 B - 10? i End Dir 9406.10' MD, 6031.30' TVD 9 9908.0 89.06 139.44 6094,8 - 2158.7 - 3409.6 3.00 -0.36 2472.8 - TVD MD Name Size r , 10 10391.0 89.06 139.44 6102.7 - 2525.6 3095.7 0.00 0.00 2808.2 1800 3051.8 3172.7 95/8" 9.625 ' I , 11 10395.3 89.19 139.44 6102.8 - 2528.9 - 3092.8 3.00 -1.66 2811.2 KupA v6 T2 B 2 6066.0 7' _ 66.0 9606.1 7.000 , Start Dir 3.00/100' 9606.10' MD, 6066.00' TVD 12 10396.4 89.22 139.44 6102.8 - 2529.7 - 3092.1 3.00 2.53 2812.0 6123.1 15186.0 4 1/2" 4.500 I / / / 13 11133.8 89.22 139.44 6112.8 -3089.9 - 2612.7 0.00 0.00 3324.1 0 14 11529.6 89.05 151.32 6118.8 - 3415.0 - 2388.3 3.00 90.91 3626.4 KupA v6 T3 15 11529.7 89.04 151.32 6118.8 -3415.1 - 2388.2 3.00 0.00 3626.5 g 2400 1 , End Dir 9908.00' MD,6094.80' TVD 16 12625.2 89.04 151.32 6137.1 -4376.0 - 1862.5 0.00 0.00 4533.1 20? 1 , 17 12644.8 89.63 151.26 6137.3 -4393.2 - 1853.1 3.00 -5.30 4549.3 KupA v6 T4 18 12644.9 89.63 151.26 6137.3 - 4393.3 - 1853.0 3.00 0.00 4549.4 Z _ f Start Dir 3.00/100' 10391.00' MD, 6102.70' NI 19 13657.5 89.63 151.26 6143.9 -5281.1 - 1366.2 0.00 0.00 5387.0 a 3000 _ d , 0? , , , 20 13670.0 90.00 151.29 6143.9 - 5292.1 - 1360.2 3.00 4.40 5397.3 KupA v6 T5 , , , , , 21 13702.0 90.96 151.29 6143.7 - 5320.2 - 1344.8 3.00 0.00 5423.8 22 14517.3 90.98 151.29 6130.0 - 6035.1 -953.2 0.00 0.00 6098.4 1 35? End Dir 10396.40' MD, 6102.80' TVD 23 14529.8 90.59 151.29 6129.8 - 6046.1 -947.2 3.00 - 179.26 6108.7 KupA v6 T6 N 3600 , , , , , �' 24 15186.0 90.59 151.29 6123.1 - 6621.6 -631.9 0.00 0.00 6651.7 KupA v6 T7 2 , / I / ID 40? Start Dir 4.00/100' TFb 91.({0 °L 6700!00' MD, 5051 70' TVD Start Dir 3.00/100' 13657.50' MD, 6143.90' TVD I-• 4200- 50? ; " , , / , , , , I , / / ' Start Dir 3.00/100' 11133.80' MD, 6112.80' TVD - - " , ' , ' ' ' End Dir 13702.00' MD, 6143.70' ND g5? , , , , / End Dir 11529.60' MD, 6118.80' TVD - - , 4800- - " Start Dir 4.00/100' 600.60' MD T)1D '' , , -Start Dir 3.00/100' 14517.30' MD, 6130.00' TVD • - ,' i ' ' / / ' Start Dir 3.00/100' 12625.20' MD, 6137.10' NjY' - - - Base Torok Sand_____ r , / , - 5400- 1 , i ' i ' , ' End Dir 12644.90' MD, 6137.30,TVD " End Dir 14529.80' MD, 6129.80' ND / , , , - - Top HRZ - - - - \ el / , - -- -- - - - 1 • , ,, - 6000- Base HRZ _ - - ? � ' 4' - : " 4 112- _ - - Total Depth at 15366.60' MD, 6123.10' TVD - Kalubik Marker - - - - - . ; 1 ` v � - - - _ 6600 - ■ KupA v6 T1 B t KupA v6 T2 t (KupA v8 T4� LupA v6 T�6 ODSK -33 KupA wp09 - Top Kuparuk C 1 , 1 , ODSK -33 KupA PB1 [KupA v6 , KupA v6 T5 [KupA v6 T7 - I I l 1 I I i 1 i I i 1 1 1 I 1 1 i 1 l 1 1 1 1 I I 1 1 1 I l l l I I I I I1 I I I I I I I I I I I I I I I I I I I I 1 1 1 P 1 11 I i I i t I I i I I I i 1 1 1 I I 1 I I I I 1 r t I l I r r I t r I r I l 1 1 1 I I 1 1 1 I 1 1 1 1 I l l -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 185.45bearing (1500 ft/in) ca WELL DETAILS: ODSK -33 REFERENCE INFORMATION HALLI BURTON Ground Level: 13.5 Coordinm(N/E) Reference: Well ODSK-33 - that ODS- 33. True North V. +N/-S +E/ - Northing Easting Latittude Longitude Slot Vertical (TVD) Reference: 42.S + 13.5' @ 56.0* (Nabors 19AC) 0.0 0.0 6031080.67 469896.50 70° 29' 45.546 N 150° 14' 46.161 W ODS -33 Measured Depth Reference: 42.5' + 13.5' a 58.0* (Nabors 19AC) • Sperry Drilling M ing MVIO . . . . rr Calculation Method: Minimum Curvahre PIONEER WELLBORE TARGET DETAILS (MAP COORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name TVD +N/ -S +E/ -W Northing Easting Shape Calculation Method: Minimum Curvature Prot: Oooguruk Develo Inent Geo Poly KupA 6066.0 - 2110.9 - 3857.7 8028985.61 466030.67 Polygon Error System: ISCWSA J g KupA v6 TI B 6068.0 -1930.5 3604.7 6029164.95 466284.35 Point Scan Method: Tray. Cylinder North Site: Oooguruk Drill Site KupA v6 T2 8 6102.8 - 2528.9 - 3092.8 6028564.57 466793.75 Point Error Surface: Elliptical Conic Well: ODSK -33 KupA v6 T3 6118.8 - 3415.0 - 2388.3 6027675.74 467494.64 Point Warning Method: Rules Based KupA v6 T7 6123.1 - 6621.6 -631.9 6024462.34 469237.84 Point Wellbore: ODSK -33 KupA KupA v6 T6 6129.8 - 6046.1 -947.2 6025039.05 468924.94 Point Plan: ODSK -33 KupA w p (1� KupA v6 T4 6137.3 4393.2 - 1853.1 6026695.45 468025.84 Point p KupA v6 T5 6143.9 - 5292.1 - 1360.2 6025794.70 488515.04 Point SURVEY PROGRAM Date: 2008-03-18T00:00:00 Validated: Yes Version: DDI =6.86 98.8 Depth 01.8 ODSK -33 KupA Gyro CB-GYRO-SS .. 1043.2 6700.0 ODSK -33 KupA MWD MWD +SAG +CA +IIFR +MS 600- a 6700.0 15186.0 ODSK- 33KupAwp09 MWD +SAG +CA +IIFR +MS •9 5/8" SECTION DETAILS 0- ° Start dK 4.00 /100' TFO 91.00°L 6700.00' MD, 5051.70' TVD Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target 1 6700.0 67.56 246.73 5051.7 330.4 - 3414.1 0.00 0.00 -4.6 Start Dir 4.00/100' 6800.00' MD, 5089.90' TVD 2 8800.0 67.54 242.41 5089.9 290.7 - 3497.5 4.00 -91.00 42.8 3300 3 7317.1 67.50 220.00 5289.8 -6.2 - 3866.8 4.00 -94.45 373.4 4 7778.7 67.50 200.00 5467.9 -373.1 - 4078.7 4.00 -93.86 758.8 End Dir 8994.00' MD, 5919.60' TVD 5 8994.0 71.61 148.04 5919.8 - 1455.6 - 3958.2 4.00 -95.17 1825.0 6 9144.1 71.61 148.04 5967.0 - 1576.4 - 3882.8 0.00 0.00 1938.1 Start Dir 4.50/100' 9144.10 MD 5967 TVD 7 9406.1 80.00 139.50 6031.3 - 1780.8 - 3732.6 4.50 -45.76 2127.2 -1200- , 8 9608.1 80.00 139.50 8066.0 - 1930.5 - 3604.7 0.00 0.00 2264.2 KupA v6 T1 E - - - - 9 9908.0 89.06 139.44 6094.8 - 2158.7 - 3409.6 3.00 -0.36 2472.8 - End Dir 9406.10 MD, 6031.30 TVD 10 10391.0 89.06 139.44 6102.7 - 2525.6 - 3095.7 0.00 0.00 2808.2 KupA v6 TI 11 10395.3 89.19 139.44 6102.8 - 2528.9 -3092.8 3.00 -1.66 2811.2 KupA v6 T2 E - Start Dir 3.00/100' 9606.10' MD, 6066.00' TVD 12 10396.4 89.22 139.44 6102.8 - 2529.7 -3092.1 3.00 2.53 2812.0 -1800- -: .7" _ - _ - - - - _ - 13 11133.8 89.22 139.44 6112.8 - 3089.9 - 2612.7 0.00 0.00 3324.1 ^p ODSI4 33 KupA PBI- - - \\ D 14 11529.8 89.05 151.32 6118.8 - 3415.0 - 2388.3 3.00 90.91 3626.4 KupA v6 T3 r . End Dir 9908.00' M,6094.80' TVD 15 11529.7 89.04 151.32 6118.8 - 3415.1 - 2388.2 3.00 0.00 3626.5 = lc P°17 Kup 4376.0 - 1862.5 0.00 0.00 4533.1 8 -2400- ; \ _ Start Dir 3.00/100' 10391.00' MD, 6102.70' TVD 17 12644.8 89.63 151.26 6137.3 -4393.2 - 1853.1 3.00 -5.30 4549.3 KupA v6 T4 vt i � \ \ `'_ - _ _ _ _ 18 12644.9 89.63 151.26 6137.3 -4393.3 -1853.0 3.00 0.00 4549.4 _ LDD Poly 95 T \ - End Dir 10396.40' MD, 6102.80' TVD 19 13657.5 89.63 151.26 6143.9 - 5281.1 -1366.2 0.00 0.00 5387.0 \ \ • 20 13670.0 90.00 151.29 6143.9 - 5292.1 - 1360.2 3.00 4.40 5397.3 KupA v6 T5 .+. -3000- / \ '\, 21 13702.0 90.96 151.29 6143.7 - 5320.2 - 1344.8 3.00 0.00 5423.8 t. \•\ - - Start Dir 3.00/100' 11133.80' MD, 6112.80' TVD 22 14517.3 90.96 151.29 6130.0 - 6035.1 -953.2 0.00 0.00 6098.4 p LK v6 T21 \ • \ 23 14529.8 90.59 151.29 6129.8 - 6046.1 -947.2 3.00 - 179.26 6108.7 KupA v6 T6 - End Dir 11529.60' MD, 6118.80' TVD 24 15186.0 90.59 151.29 6123.1 - 6621.6 -631.9 0.00 0.00 6651.7 KupA v6 T7 ' -3600- \ 0 _ - .. " \ \ Start Dir 3.00/100' 12625.20' MD, 6137.10' TVD • \ CASING DETAILS en CKepA v6 TIf - - -4200 _ \ - . - - ' End Dir 12644.90' MD, 6137.30' TVD TVD MD Name Size 3051.8 3172.7 95/8" 9.625 - \ 6066.0 9606.1 7" 7.000 .A \ Start Dir 3.00/100' 13657.50' MD, 6143.90' TVD 6123.1 15186.0 41/2" 4.500 \ -- -4800- r KupA v6 7� t\ \ End Dir 13702.00' MD, 6143.70' TVD -5400- --% Start Dir 3.00/100' 14517.30' MD, 6130.00' TVD 1 I KupA v6115 _ \ - End Dir 14529.80' MD, 6129.80' TVD -6000- \ \ a- \ KupAv Total Depth at 15366.60' MD, 6123.10' TVD • 41/2" __ - -- - -6600- a = -ODSK -33 KupA wpO9 ' _ I KupA v6'IP \ 1 1 - IIIIIiliiiiiiliiflliitiliii111I111 , "Ifii111111iiiiiii I1111111iiiiiii11I111111111' iliili111111iiiiii1111111itillli11i111ii - 4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 _ 7200 7800 8400 9000 9600 West(- )IEast( +) (1500 ft/in) • 40 Sperry Drilling Services HALLIBURTON Standard Proposal Report • EDM_Alaska — , . �. - +_ : - Well ODSK -33 Slot ODS -33 ' - Well Planning - Pioneer - Oooguruk • ,~ 42.5' + 13.5' @ 56.0ft (Nabors 19AC), Oooguruk Developement a aka 42.5 + 13.5' @ 56.Oft (Nabors 19AC) Oooguruk Drill Site = r a True 1 ODSK -33 _ a � Minimum Curvature < < . _ ODSK -33 KupA • ODSK -33 KupA wpO9 , Oo ••uruk Develo ment , . ,o- . e7, ,<m ., 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 -s Oo• • uruk 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 ? . f ODSK 33 Slot ODS 33 Well Position +N/-S 0.0 ft Northing: 6,031,080.67 ft Latitude: 70° 29' 45.546 N +E / -W 0.0 ft Easting: 469,896.50 ft Longitude: 150° 14' 46.161 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft ODSK33Ku•A rt - .fi t IGRF200510 2/14/2007 23.26 80.81 57,641 .. ;_ ODSK 33 Ku •A • 09 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,700.0 42.5 0.0 0.0 185.45 3/18/2008 2:08:46PM Page 2 COMPASS 2003.16 Build 42B i • • • Sperry Drilli Services HALLIBURTON Standard P roposal Report �.. _ _ __ .EDM Alaska a � � : Well ODSK 33 - Slot ODS -33 � � �� = Well Planning - Pioneer Oooguruk a �. 42.5 + 13.5 @ 56.Oft (Nabors 19AC) Oooguruk Developement 42 + 13.5' @ 56.Oft (Nabors 19AC) Oooguruk Drill Site True ODSK -33 > Minimum Curvature ODSK -33 KupA ODSK 33 KupA wp09 .x.. -. ,mow _ " w., s 6,700.0 67.56 246.73 5,051.7 4,995.7 330.4 3,414.1 0.00 0.00 0.00 0.00 6,800.0 67.54 242.41 5,089.9 5,033.9 290.7 - 3,497.5 4.00 -0.01 -4.33 -91.00 7,317.1 67.50 220.00 5,289.8 5,233.8 -6.2 -3,866.8 4.00 -0.01 -4.33 -94.45 7,778.7 67.50 200.00 5,467.9 5,411.9 373.1 4,078.7 4.00 0.00 4.33 93.86 8,994.0 71.61 148.04 5,919.6 5,863.6 1,455.6 - 3,958.2 4.00 0.34 4.28 95.17 9,144.1 71.61 148.04 5,967.0 5,911.0 1,576.4 3,882.8 0.00 0.00 0.00 0.00 9,406.1 80.00 139.50 6,031.3 5,975.3 1,780.8 3,732.6 4.50 3.20 -3.26 -45.76 9,606.1 80.00 139.50 6,066.0 6,010.0 -1,930.5 -3,604.7 0.00 0.00 0.00 0.00 9,908.0 89.06 139.44 6,094.8 6,038.8 -2,158.7 -3,409.6 3.00 3.00 -0.02 -0.36 10,391.0 89.06 139.44 6,102.7 6,046.7 -2,525.6 -3,095.7 0.00 0.00 0.00 0.00 10,395.3 89.19 139.44 6,102.8 6,046.8 2,528.9 3,092.8 3.00 3.00 -0.09 -1.66 10,396.4 89.22 139.44 6,102.8 6,046.8 2,529.7 - 3,092.1 3.00 3.00 0.13 2.53 11,133.8 89.22 139.44 6,112.8 6,056.8 3,089.9 2,612.7 0.00 0.00 0.00 0.00 11,529.6 89.05 151.32 6,118.8 6,062.8 - 3,415.0 2,388.3 3.00 -0.04 3.00 90.91 11,529.7 89.04 151.32 6,118.8 6,062.8 - 3,415.1 2,388.2 3.00 2.99 0.28 0.00 • 12,625.2 89.04 151.32 6,137.1 6,081.1 - 4,376.0 1,862.5 0.00 0.00 0.00 0.00 12,644.8 89.63 151.26 6,137.3 6,081.3 -4,393.2 1,853.1 3.00 2.99 -0.28 -5.30 12,644.9 89.63 151.26 6,137.3 6,081.3 - 4,393.3 -1,853.0 3.00 2.99 -0.23 0.00 13,657.5 89.63 151.26 6,143.9 6 66 ,0 °0 8 58 7 1 .9 33 ,087.9 - 5,281.1 -1,366.2 0.00 0.00 0.00 0.00 13,670.0 90.00 151.29 6,143.9 6,087.9 -5,292.1 - 1,360.2 3.00 2.99 0.23 4.40 13,702.0 90.96 151.29 6,143.7 6,087.7 -5,320.2 - 1,344.8 3.00 3.00 0.00 0.00 14,517.3 90.96 151.29 6,130.0 6,074.0 -6,035.1 -953.2 0.00 0.00 0.00 0.00 14,529.8 90.59 151.29 6,129.8 6,073.8 6,046.1 -947.2 3.00 -3.00 -0.04 -179.26 15,186.0 90.59 151.29 6,123.1 6,067.1 6,621.6 -631.9 0.00 0.00 0.00 0.00 • 3/18/2008 2:08:46PM Page 3 COMPASS 2003.16 Build 428 • • Sperry 1- ALL I B U R T O N Standard Proposal Drilling Services Report _� -.' a..� �N a ' _. - ..EDM_Alaska ; _ Well ODSK 33 Slot ODS -33 ;, n . . Well Planning - Pioneer - Oooguruk . 42.5' + 13.5 @ 56.Oft (Nabors 19AC) r f Oooguruk Developement ' W �� 42.5' + 13.5' @ 56.0ft (Nabors 19AC) , Oooguruk Drill Site � �� . : :� True ODSK -33 . Minimum Curvature ODSK -33 KupA ODSK -33 KupA wp09 :, ,, ° , , , E 6,700.0 67.56 246.73 5,051.7 4,995.7 - 330.4 3,414.1 6,031,424.85 466,484.12 0.00 -4.63 Start Dir 4.00/100' TFO 91.00 °L 6700.00' MD, 5051.70' ND 6,800.0 67.54 242.41 5,089.9 5,033.9 290.7 - 3,497.5 6,031,385.51 466,400.53 4.00 42.79 Start Dir 4.00/100' 6800.00' MD, 5089.90' TVD 6,900.0 67.29 238.08 5,128.3 5,072.3 244.9 - 3,577.7 6,031,340.03 466,320.22 4.00 96.00 7,000.0 67.15 233.75 5,167.0 5,111.0 193.2 - 3,654.0 6,031,288.69 466,243.68 4.00 154.67 7,100.0 67.14 229.40 5,205.9 5,149.9 136.0 - 3,726.2 6,031,231.74 466,171.28 4.00 218.52 7,200.0 67.24 225.07 5,244.7 5,188.7 73.4 - 3,793.8 6,031,169.45 466,103.39 4.00 287.23 7,300.0 67.45 220.74 5,283.2 5,227.2 5.8 - 3,856.6 6,031,102.13 466,040.32 4.00 360.47 7,307.3 67.47 220.42 5,286.0 5,230.0 0.7 - 3,861.0 6,031,097.05 466,035.93 4.00 365.97 Base Torok Sand 7,317.1 67.50 220.00 5,289.8 5,233.8 -6.2 - 3,866.8 6,031,090.15 466,030.05 4.00 373.41 7,400.0 67.32 216.41 5,321.6 5,265.6 -66.3 - 3,914.2 6,031,030.21 465,982.47 4.00 437.78 7,500.0 67.20 212.08 5,360.3 5,304.3 -142.5 - 3,966.1 6,030,954.21 465,930.29 4.00 518.57 7,600.0 67.20 207.74 5,399.1 5,343.1 -222.4 - 4,012.0 6,030,874.52 465,884.02 4.00 602.46 7,700.0 67.32 203.40 5,437.7 5,381.7 -305.6 - 4,051.8 6,030,791.52 465,843.89 4.00 689.04 7,778.7 67.50 200.00 5,467.9 5,411.9 -373.1 - 4,078.7 6,030,724.16 465,816.76 4.00 758.76 7,800.0 67.43 199.08 5,476.1 5,420.1 -391.6 - 4,085.3 6,030,705.63 465,810.10 4.00 777.87 7,900.0 67.15 194.75 5,514.7 5,458.7 - 479.9 - 4,112.1 6,030,617.52 465,782.91 4.00 868.24 8,000.0 66.99 190.41 5,553.7 5,497.7 - 569.7 - 4,132.2 6,030,527.76 465,762.49 , 4.00 959.59 8,100.0 66.94 186.07 5,592.9 5,536.9 - 660.8 - 4,145.3 6,030,436.77 465,748.93 4.00 1,051.48 8,200.0 67.02 181.72 5,632.0 5,576.0 - 752.6 - 4,151.6 6,030,345.01 465,742.31 4.00 1,143.46 8,300.0 67.22 177.39 5,670.9 5,614.9 - 844.7 - 4,150.9 6,030,252.92 465,742.66 4.00 1,235.07 8,400.0 67.53 173.07 5,709.4 5,653.4 - 936.6 - 4,143.2 6,030,160.94 465,749.97 4.00 1,325.88 8,500.0 67.95 168.77 5,747.3 5,691.3 - 1,028.0 - 4,128.6 6,030,069.54 465,764.21 4.00 1,415.44 8,600.0 68.49 164.50 5,784.4 5,728.4 - 1,118.3 - 4,107.1 6,029,979.14 465,785.31 4.00 1,503.31 8,634.5 68.70 163.03 5,797.0 5,741.0 - 1,149.2 - 4,098.1 6,029,948.24 465,794.18 4.00 1,533.18 Top HRZ 8,700.0 69.13 160.26 5,820.6 5,764.6 - 1,207.1 - 4,078.9 6,029,890.20 465,813.17 4.00 1,589.06 8,800.0 69.88 156.07 5,855.6 5,799.6 - 1,294.0 - 4,044.1 6,029,803.14 465,847.65 4.00 1,672.29 8,900.0 70.73 151.92 5,889.3 5,833.3 - 1,378.6 - 4,002.8 6,029,718.39 465,888.58 4.00 1,752.57 8,994.0 71.61 148.04 5,919.6 5,863.6 - 1,455.6 - 3,958.3 6,029,641.21 465,932.77 4.01 1,825.01 End Dir 8994.00' MD, 5919.60' TVD 9,000.0 71.61 148.04 5,921.5 5,865.5 - 1,460.4 - 3,955.2 6,029,636.42 465,935.86 0.02 1,829.47 9,004.7 71.61 148.04 5,923.0 5,867.0 - 1,464.2 - 3,952.8 6,029,632.59 465,938.23 0.00 1,833.05 Base HRZ 9,100.0 71.61 148.04 5,953.0 5,897.0 - 1,540.9 - 3,904.9 6,029,555.71 465,985.76 0.00 1,904.85 9,144.1 71.61 148.04 5,967.0 5,911.0 - 1,576.4 - 3,882.8 6,029,520.12 466,007.76 0.00 1,938.09 Start Dir 4.50/100' 9144.10' MD, 5967.00' TVD 9,200.0 73.38 146.16 5,983.8 5,927.8 - 1,621.2 - 3,853.8 6,029,475.25 466,036.54 4.50 1,979.89 9,264.0 75.42 144.05 6,001.0 5,945.0 - 1,671.8 - 3,818.5 6,029,424.55 466,071.60 4.50 2,026.88 Kalubik Marker 9,300.0 76.57 142.88 6,009.7 5,953.7 - 1,699.8 - 3,797.8 6,029,396.42 466,092.27 4.50 2,052.83 9,400.0 79.80 139.69 6,030.2 5,974.2 - 1,776.2 - 3,736.6 6,029,319.84 466,153.16 4.49 2,123.01 COMPASS 2003.16 Build 42B 3/18/2008 2:08:46PM Page 4 t r Sperry Drilling Services HALLIBURTON Standard Proposal Report •� >. tea._ �._� .EDM_Alaska ` Well ODSK-33 - Slot ODS -33 Well Planning - Pioneer - Oooguruk w 42.5' + 13.5 @ 56.0ft (Nabors 19AC) O ooguruk Developement ` s� 42.5 + 13.5 @ 56.0ft (Nabors 19AC) Oooguruk Drill Site' . True ODSK -33 r m Minimum Curvature ODSK -33 KupA ODSK 33 KupA wp09 w - ;r 9,406.1 80.00 139.50 6,031.3 5,975.3 - 1,780.7 - 3,732.7 6,029,315.25 466,157.04 4.49 2,127.20 End Dir 9406.10' MD, 6031.30' TVD 9,500.0 80.00 139.50 6,047.6 5,991.6 - 1,851.1 - 3,672.6 6,029,244.69 466,216.80 0.00 2,191.50 9,600.0 80.00 139.50 6,064.9 6,008.9 - 1,925.9 - 3,608.7 6,029,169.55 466,280.44 0.00 2,259.97 9,600.4 80.00 139.50 6,065.0 6,009.0 - 1,926.2 - 3,608.4 6,029,169.27 466,280.68 0.00 2,260.23 Top Kuparuk C 9,606.1 80.00 139.50 6,066.0 6,010.0 - 1,930.5 - 3,604.7 6,029,164.95 466,284.35 0.00 2,264.17 Start Dir 3.00/100' 9606.10' MD, 6066.00' TVD - 7" - KupA v6 T1 B 9,700.0 82.82 139.48 6,080.0 6,024.0 - 2,001.1 - 3,544.4 6,029,094.15 466,344.34 3.00 2,328.69 9,800.0 85.82 139.46 6,089.9 6,033.9 - 2,076.7 - 3,479.8 6,029,018.27 466,408.68 3.00 2,397.83 9,900.0 88.82 139.45. 6,094.6 6,038.6 - 2,152.6 - 3,414.9 6,028,942.12 466,473.29 3.00 2,467.22 9,908.0 89.06 139.44 6,094.8 6,038.8 - 2,158.7 - 3,409.7 6,028,936.02 466,478.46 3.00 2,472.77 End Dir 9908.00' MD,6094.80' TVD 10,000.0 89.06 139.44 6,096.3 6,040.3 - 2,228.6 - 3,349.9 6,028,865.90 466,537.99 0.00 2,536.67 10,100.0 89.06 139.44 6,097.9 6,041.9 - 2,304.5 - 3,284.8 6,028,789.68 466,602.68 0.00 2,606.12 10,200.0 89.06 139.44 6,099.6 6,043.6 - 2,380.5 - 3,219.8 6,028,713.45 466,667.38 0.00 2,675.56 10,300.0 89.06 139.44 6,101.2 6,045.2 - 2,456.5 - 3,154.8 6,028,637.23 466,732.07 0.00 2,745.01 10,391.0 89.06 139.44 6,102.7 6,046.7 - 2,525.6 - 3,095.7 6,028,567.87 466,790.95 0.00 2,808.21 Start Dir 3.00/100' 10391.00' MD, 6102.70' TVD 10,395.3 89.19 139.44 6,102.8 6,046.8 - 2,528.9 - 3,092.8 6,028,564.57 466,793.75 3.03 2,811.22 KupA v6 T2 B 10,396.4 89.22 139.44 6,102.8 6,046.8 - 2,529.7 - 3,092.2 6,028,563.75 466,794.44 3.00 2,811.96 End Dir 10396.40' MD, 6102.80' TVD 10,400.0 89.22 139.44 6,102.8 6,046.8 - 2,532.4 - 3,089.8 6,028,561.01 466,796.77 0.01 2,814.46 10,500.0 89.22 139.44 6,104.2 6,048.2 - 2,608.4 - 3,024.8 6,028,484.79 466,861.47 0.00 2,883.91 10,600.0 89.22 139.44 6,105.6 6,049.6 - 2,684.4 - 2,959.8 6,028,408.57 466,926.17 0.00 2,953.36 10,700.0 89.22 139.44 6,106.9 6,050.9 - 2,760.3 - 2,894.8 6,028,332.34 466,990.87 0.00 3,022.81 10,800.0 89.22 139.44 6,108.3 6,052.3 - 2,836.3 - 2,829.7 6,028,256.12 467,055.58 0.00 3,092.26 10,900.0 89.22 139.44 6,109.6 6,053.6 - 2,912.3 - 2,764.7 6,028,179.90 467,120.28 0.00 3,161.70 11,000.0 89.22 139.44 6,111.0 6,055.0 - 2,988.3 - 2,699.7 6,028,103.68 467,184.98 0.00 3,231.15 11,100.0 89.22 139.44 6,112.4 6,056.4 - 3,064.2 - 2,634.7 6,028,027.46 467,249.68 0.00 3,300.60 11,133.8 89.22 139.44 6,112.8 6,056.8 - 3,089.9 - 2,612.7 6,028,001.69 467,271.55 0.00 3,324.08 Start Dir 3.00/ 100' 11133.80' MD, 6112.80' TVD 11,200.0 89.19 141.43 6,113.7 6,057.7 - 3,140.9 - 2,570.6 6,027,950.50 467,313.50 3.00 3,370.87 11,300.0 89.14 144.43 6,115.2 6,059.2 - 3,220.7 - 2,510.3 6,027,870.50 467,373.44 3.00 3,444.55 11,400.0 89.10 147.43 6,116.7 6,060.7 - 3,303.5 - 2,454.3 6,027,787.46 467,429.11 3.00 3,521.67 11,500.0 89.06 150.43 6,118.3 6,062.3 - 3,389.1 - 2,402.7 6,027,701.63 467,480.35 3.00 3,602.02 11,529.6 89.05 151.31 6,118.8 6,062.8 - 3,415.0 - 2,388.3 6,027,675.74 467,494.64 3.00 3,626.37 End Dir 11529.60' MD, 6118.80' TVD - KupA v6 T3 11,529.7 89.04 151.32 6,118.8 6,062.8 - 3,415.1 - 2,388.2 6,027,675.59 467,494.72 3.07 3,626.51 11,600.0 89.04 151.32 6,120.0 6,064.0 - 3,476.7 - 2,354.5 6,027,613.84 467,528.19 0.00 3,684.65 11,700.0 89.04 151.32 6,121.7 6,065.7 - 3,564.5 - 2,306.5 6,027,525.94 467,575.82 0.00 3,767.41 11,800.0 89.04 151.32 6,123.3 6,067.3 - 3,652.2 - 2,258.5 6,027,438.04 467,623.45 0.00 3,850.17 11,900.0 89.04 151.32 6,125.0 6,069.0 - 3,739.9 - 2,210.5 6,027,350.14 467,671.08 0.00 3,932.93 12,000.0 89.04 151.32 6,126.7 6,070.7 - 3,827.6 - 2,162.5 6,027,262.24 467,718.71 0.00 4,015.69 3/18/2008 2:08:46PM Page 5 COMPASS 2003.16 Build 42B • . Sperry Drilling Services HALLIBURTDN Standard Proposal Report -,• ..EDM_Alaska Well ODSK -33 - Slot ODS -33 Well Planning - Pioneer - Oooguruk a - _ ¢ ` 42.5' + 13.5 © 56.0ft (Nabors 19AC) Oooguruk Developement 42.5 + 13.5 @ 56.0ft (Nabors 19AC) Oooguruk Drill Site , - :, True ODSK -33 , ��_ Minimum Curvature ODSK -33 KupA , �_= r ODSK -33 KupA wp09 - , 12,100.0 89.04 151.32 6,128.3 6,072.3 - 3,915.3 - 2,114.5 6,027,174.34 467,766.34 0.00 4,098.45 12,200.0 89.04 151.32 6,130.0 6,074.0 - 4,003.0 - 2,066.5 6,027,086.44 467,813.97 0.00 4,181.22 12,300.0 89.04 151.32 6,131.7 6,075.7 - 4,090.8 - 2,018.6 6,026,998.54 467,861.60 0.00. 4,263.98 12,400.0 89.04 151.32 6,133.3 6,077.3 - 4,178.5 - 1,970.6 6,026,910.64 467,909.23 0.00 4,346.74 12,500.0 89.04 151.32 6,135.0 6,079.0 - 4,266.2 - 1,922.6 6,026,822.74 467,956.86 0.00 4,429.50 12,600.0 89.04 151.32 6,136.7 6,080.7 - 4,353.9 - 1,874.6 6,026,734.84 468,004.49 0.00 4,512.26 12,625.2 89.04 151.32 6,137.1 6,081.1 - 4,376.0 - 1,862.5 6,026,712.68 468,016.49 0.00 4,533.12 Start Dir 3.00/100' 12625.20' MD, ,6137.10`TVD 12,644.8 89.63 151.26 6,137.3 6,081.3 - 4,393.2 - 1,853.1 6,026,695.45 468,025.84 2.99 4,549.34 KupA v6 T4 12,644.9 89.63 151.26 6,137.3 6,081.3 - 4,393.3 - 1,853.0 6,026,695.37 468,025.89 2.46 , 4,549.42 End Dir 12644.90' MD, 6137.30' T VD 12,700.0 89.63 151.26 6,137.7 6,081.7 - 4,441.6 - 1,826.5 6,026,646.96 468,052.18 0.00 4,594.99 12,800.0 89.63 151.26 6,138.3 6,082.3 - 4,529.3 - 1,778.5 6,026,559.09 468,099.90 0.00 4,677.71 12,900.0 89.63 151.26 6,139.0 6,083.0 - 4,617.0 - 1,730.4 6,026,471.23 468,147.62 0.00 4,760.43 13,000.0 89.63 151.26 6,139.6 6,083.6 - 4,704.6 - 1,682.3 6,026,383.36 468,195.34 0.00 4,843.15 13,100.0 89.63 151.26 6,140.3 6,084.3 - 4,792.3 - 1,634.2 6,026,295.49 468,243.06 0.00 4,925.86 13,200.0 89.63 151.26 6,140.9 6,084.9 - 4,880.0 - 1,586.1 6,026,207.63 468,290.78 0.00 5,008.58 13,300.0 89.63 151.26 6,141.6 6,085.6 - 4,967.7 - 1,538.1 6,026,119.76 468,338.50 0.00 5,091.30 13,400.0 89.63 151.26 6,142.2 6,086.2 - 5,055.4 - 1,490.0 6,026,031.90 468,386.22 0.00 5,174.02 13,500.0 89.63 151.26 6,142.9 6,086.9 - 5,143.0 - 1,441.9 6,025,944.03 468,433.94 0.00 5,256.74 13,600.0 89.63 151.26 6,143.5 6,087.5 - 5,230.7 - 1,393.8 6,025,856.17 468,481.66 0.00 5,339.45 13,657.5 89.63 151.26 6,143.9 6,087.9 - 5,281.1 - 1,366.2 6,025,805.64 468,509.10 0.00 5,387.02 Start Dir 3.00/100' 13657.50' MD, 6143.90' TVD 13,670.0 90.00 151.29 6,143.9 6,087.9 - 5,292.1 - 1,360.2 6,025,794.70 468,515.04 3.01 5,397.32 KupA v6 TS 13,700.0 90.90 151.29 6,143.7 6,087.7 - 5,318.4 - 1,345.7 6,025,768.29 468,529.36 3.00 5,422.18 13,702.0 90.96 151.29 6,143.7 6,087.7 - 5,320.2 - 1,344.8 6,025,766.53 468,530.31 3.00 5,423.84 End Dir 13702.00' MD, 6143.70' TVD 13,800.0 90.96 151.29 6,142.0 6,086.0 - 5,406.1 - 1,297.7 6,025,680.41 468,577.03 0.00 5,504.92 13,900.0 90.96 151.29 6,140.4 6,084.4 - 5,493.8 - 1,249.7 6,025,592.53 468,624.70 0.00 5,587.65 14,000.0 90.96 151.29 6,138.7 6,082.7 - 5,581.5 - 1,201.7 6,025,504.65 468,672.37 0.00 5,670.39 14,100.0 90.96 151.29 6,137.0 6,081.0 - 5,669.2 - 1,153.6 6,025,416.78 468,720.04 0.00 5,753.13 14,200.0 90.96 151.29 6,135.3 6,079.3 - 5,756.9 - 1,105.6 6,025,328.90 468,767.71 0.00 5,835.86 14,300.0 90.96 151.29 6,133.6 6,077.6 - 5,844.6 - 1,057.6 6,025,241.02 468,815.38 0.00 5,918.60 14,400.0 90.96 151.29 6,132.0 6,076.0 - 5,932.3 - 1,009.5 6,025,153.14 468,863.05 0.00 6,001.33 14,500.0 90.96 151.29 6,130.3 6,074.3 - 6,020.0 -961.5 6,025,065.26 468,910.72 0.00 6,084.07 14,517.3 90.96 151.29 6,130.0 6,074.0 - 6,035.1 -953.2 6,025,050.06 468,918.97 0.00 6,098.38 Start Dir 3.00/100' 14517.30' MD, 6130.00' TVD 14,529.8 90.59 151.29 6,129.8 6,073.8 - 6,046.1 -947.2 6,025,039.05 468,924.94 3.00 6,108.75 End Dir 14529.80' MD, 6129.80' TVD - KupA v6 T6 14,600.0 90.59 151.29 6,129.1 6,073.1 - 6,107.7 -913.5 6,024,977.38 468,958.40 0.00 6,166.81 14,700.0 90.59 151.29 6,128.1 6,072.1 - 6,195.4 -865.4 6,024,889.49 469,006.08 0.00 6,249.55 14,800.0 90.59 151.29 6,127.1 6,071.1 -6,283.1 -817.4 6,024,801.61 469,053.76 0.00 6,332.28 14,900.0 90.59 151.29 6,126.1 6,070.1 - 6,370.8 -769.3 6,024,713.73 469,101.44 0.00 6,415,02 3/18/2008 2:08:46PM Page 6 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HALLIBURTON Standard Proposal Report ..EDM_Alaska Well ODSK -33 - Slot ODS -33 Well Planning - Pioneer - Oooguruk a _ , . 42.5 + 13.5 @ 56.0ft (Nabors 19AC) Oooguruk Developement - o'••-- 42.5' + 13.5' @ 56.0ft (Nabors 19AC) Oooguruk Drill Site .",?5,11"g True ODSK -33 E{ Minimum Curvature ODSK 33 KupA ODSK 33 KupA wp09 15,000.0 90.59 151.29 6,125.0 6,069.0 - 6,458.5 -721.3 6,024,625.85 469,149.13 '0.00 6,497.76 15,100.0 90.59 151.29 6,124.0 6,068.0 - 6,546.1 -673.3 6,024,537.96 469,186.81 0.00 6,580.50 15,186.0 90.59 151.29 6,123.1 6,067.1 - 6,621.6 -631.9 6,024,462.38 469,237.81 0.00 6,651.66 Total Depth at 15366.60' MD, 6123.10' TVD - 4 1/2" - KupA v6 T7 KupA v6 T5 0.00 0.00 6,143.9 - 5,292.1 - 1,360.2 6,025,794.70 468,515.04 - plan hits target - Point KupA v6 T3 0.00 0.00 6,118.8 - 3,415.0 - 2,388.3 6,027,675.74 467,494.64 - plan hits target - Point KupA v6 T7 0.00 0.00 6,123.1 - 6,621.6 -631.9 6,024,462.34 469,237.84 - plan hits target - Point KupA v6 T4 0.00 0.00 6,137.3 - 4,393.2 - 1,853.1 6,026,695.45 468,025.84 - plan hits target - Point KupA v6 T1 B 0.00 0.00 6,066.0 - 1,930,5 - 3,604.7 6,029,164.95 466,284.35 - plan hits target - Point Geo Poly KupA 0.00 0.00 6,066.0 - 2,110.9 - 3,857.7 6,028,985.61 466,030.67 - plan misses by 309.5ft at 9579.4ft MD (6061.4 TVD, - 1910.5 N, - 3621.8 E) - Polygon Point 1 6,066.0 - 3,184.0 - 2,670.5 6,027,907.82 467,213.40 Point 2 6,066.0 - 4,468.3 - 2,077.9 6,026,621.26 467,800.73 Point 3 6,066.0 - 5,415.7 - 1,591.4 6,025,671.99 468,283.34 Point4 6,066.0 - 6,303.0 - 1,053.3 6,024,782.61 468,817.79 Point 5 6,066.0 - 6,699.7 -816.4 6,024,385.00 469,053.06 Point 6 6,066.0 - 7,093.7 -465.1 6,023,989.62 469,402.72 Point 7 6,066.0 - 6,777.3 -144.5 6,024,304.68 469,724.57 Point 8 6,066.0 - 5,250.7 - 1,131.5 6,025,835.11 468,743.86 Point 9 6,066.0 - 3,411.4 - 2,074.7 6,027,678.03 467,808.21 Point 10 6,066.0 - 1,854.8 - 3,543.0 6,029,240.41 466,346.37 Point 11 6,066.0 - 2,056.6 - 3,821.1 6,029,039.76. 466,067.49 Point 12 6,066.0 - 2,110.9 - 3,857.7 6,028,985.61 466,030.67 KupA v6 T2 B 0.00 0.00 6,102.8 - 2,528.9 - 3,092.8 6,028,564.57 466,793.75 - plan hits target • - Point KupA v6 T6 0.00 0.00 6,129.8 - 6,046.1 -947.2 6,025,039.05 468,924.94 - plan hits target - Point 3/18/2008 2:08:46PM Page 7 COMPASS 2003.16 Build 428 ' I 1 • • Sperry Drilling Services HALLI B U RTO N Standard Proposal Report EDM_Alaska , . o- Well ODSK -33 - Slot ODS -33 r = - - E Well Planning - Pioneer - Oooguruk " 10 - _ P 42.5' + 13.5' @ 56.0ft (Nabors 19AC) , Oooguruk Developement , 42.5' + 13.5' @ 56.0ft (Nabors 19AC) st y Oooguruk Drill Site t .� . . True ODSK -33 Minimum Curvature - ODSK -33 KupA �. : _ . , ° ODSK -33 KupA wp09, 3,172.7 3,051.8 9 5/8" 9.625 12.250 9,606.1 6,066.0 7" 7.000 8.750 15,186.0 6,123.1 4 1/2" 4.500 6.125 deg z 5 •s _ c j 5 fi ter: n . - ��... '.: � �m �. a. 4,384.0 4,013.0 Confining Shale 0.00 9,264.0 6,001.0 Kalubik Marker 0.00 3,046.3 2,944.0 Tuffaceous Shales 0.00 . 2,383.4 2,332.0 Top West Sak 0.00 7,307.3 5,286.0 Base Torok Sand 0.00 2,926.9 2,839.0 Hue Shales 0.00 6,620.1 5,021.0 Top Torok Sand 0.00 1,683.6 1,670.0 Base of Permanfrost 0.00 9,004.7 5,923.0 Base HRZ 0.00 9,600.4 6,065.0 Top Kuparuk C 0.00 8,634.5 5,797.0 Top HRZ 0.00 s 3 , . 6,700.0 5,051.7 330.4 - 3,414.1 Start Dir 4.00/100' TFO 91.00 °L 6700.00' MD, 5051.70' ND 6,800.0 5,089.9 290.7 - 3,497.5 Start Dir 4.00/100' 6800.00' MD, 5089.90' ND 8,994.0 5,919.6 - 1,455.6 - 3,958.3 End Dir 8994.00' MD, 5919.60' ND 9,144.1 5,967.0 - 1,576.4 - 3,882.8 Start Dir 4.50/100' 9144.10' MD, 5967.00' ND 9,406.1 6,031.3 - 1,780.7 - 3,732.7 End Dir 9406.10' MD, 6031.30' ND 9,606.1 6,066.0 - 1,930.5 - 3,604.8 Start Dir 3.00/100' 9606.10' MD, 6066.00' ND 9,908.0 6,094.8 - 2,158.7 - 3,409.7 End Dir 9908.00' MD,6094.80' ND 10,391.0 6,102.7 - 2,525.6 - 3,095.7 Start Dir 3.00/100' 10391.00' MD, 6102.70' ND 10,396.4 6,102.8 - 2,529.7 - 3,092.2 End Dir 10396.40' MD, 6102.80' ND 11,133.8 6,112.8 - 3,089.9 - 2,612.7 Start Dir 3.00/100' 11133.80' MD, 6112.80' ND 11,529.6 6,118.8 - 3,415.0 - 2,388.3 End Dir 11529.60' MD, 6118.80' ND 12,625.2 6,137.1 - 4,376.0 - 1,862.5 Start Dir 3.00/100' 12625.20' MD, 6137.10' ND 12,644.9 6,137.3 - 4,393.3 - 1,853.0 End Dir 12644.90' MD, 6137.30' ND 13,657.5 6,143.9 - 5,281.1 - 1,366.2 Start Dir 3.00/100' 13657.50' MD, 6143.90' ND 13,702.0 6,143.7 - 5,320.2 - 1,344.8 End Dir 13702.00' MD, 6143.70' ND 14,517.3 6,130.0 - 6,035.1 -953.2 Start Dir 3.00/100' 14517.30' MD, 6130.00' ND 14,529.8 6,129.8 - 6,046.1 -947.2 End Dir 14529.80' MD, 6129.80' ND 15,186.0 6,123.1 - 6,621.6 -631.9 Total Depth at 15366.60' MD, 6123.10' ND 3/18/2008 2:08:46PM Page 8 COMPASS 2003.16 Build 428 Pioneer Natural Resources STUCK BHA DIAGRAM ODSK -33 • 17.0 ppg Sidetrack Plug #2 12.5ppgP &APlug #1 / ,... Top Torokfd 6621' MD / 5022' TVD rte.. Top of ST Plug @ 6608' MD ^^ • z Base Toroq 0 0 7300' MD / 5288' TVD Top of Fishing Assy N • 7067' MD / 5199' TVD Top of Fish (Drill Assy) ,,, , \ > 7371' MD / 5317' ND @ Top HRZ 8602' MD ! 5798' ND 'tf, Bottom of Fish (Drill Assy) 4 Top of Kalubik Shale 0 8961' MD / 5925' ND 7974' MD / 5559' ND Top Kuparuk Reservoir 0 9696' MD / 6066' T TD @ 9730' MD / 6072' ND XO 1.58 6 „500 3. Accelerator 12, 6.250 2 @250 DC 276.02 6.375 2.750 Pump out 1.49 6.250 2.063 Jar. 11.57 6.250 2.250 a,. -r 9.03 6.250 3. ..r �±+ • k $ kkd A� .5 1 C 4', 6@ B lill 13 � � Y B 3 @ 4 y baler �{ F F to t . P 3/4 Mr C Y , I, 55 %, ; °6� € S . € g� 5 tg 18.813 1 '' 13 � py� i G2..,....m, it t ,. r ��. 4 ?'.d^ EE4 (i �,:)`'c 1.3, Overall Length 906.55 3/19/2008 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 19, 2008 9:33 AM To: 'Polya, Joe' Subject: RE: Spreadsheet and Corrected Procedure — ODSK -33 (207 -183) Thanks Joe. I have spoken with Commissioner Seamount and he has given oral approval for you to proceed. Best regards, Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Wednesday, March 19, 2008 9:22 AM To: Maunder, Thomas E (DOA) Subject: Spreadsheet and Corrected Procedure Tom, As discussed. Corrected Procedure and I will hand deliver the 403 directly. 7G'.a#, Po o Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya(upxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 3/19/2008 • • MD TVD Spacer DP out DP in Mud Spacer 6118 6084 Cement Plug BHA P&A Pump Capacity bbl /stk 0.0846 Got this from the rig Drill String stks 938 Drill string bbls 79.35 DP out DP in I 11 Top Plug 6608 6574 Hole Capacity bbl/ft 0.0744 8 75 Use 8.75 and /or 10.75 to compare volumes w BHA Top 7058 5193 P & A Previously Spacer Lead bbl /min 5 Contact Time (5 to 10 per min) as per Halliburton Spacer Lead min 5 Contact Time (5 to 10 per min) as per Halliburton 25 stks 296 Spacer Lead ft 490 Length based upon Average Drill Pipe annuluar capacity Spacer Lead MD 6118 Top of Spacer Lead after displacement Cement MD 6608 Top of Cement Plug (450 ft above fish) Cement ft 450 Required to cover BHA Cement bbl 33 Volume based upon Hole Capacity Cement bbl 44 Volume based upon 30% excess Cement stks 514 Strokes to pump cement Cement bbl 450 Final Cement Plug Height Cement ppf 17.59 Nominal Weight of Cement String (DP) Cement bbl 2.9 Cement Displaced by DP Cement ft 34 Adder! Cement Height in Annulus and inside DP c' ft 6574 t with Pipe Stung In Cement Plug Spacer Tail MD 6084 Top of Spacer Lead Spacer Tail MD 6574 Top of Plug Spacer Tail ft 490 Length of Drill Pipe Spacer I ac 001 5 Voiurne of Space( in dnil pipe Spacer Tail stks 58 Strokes to pump Spacer Tail Displacement bbl 60 Volume of Mud to Place Cement Displacement stks 715 Strokes to place Cement • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 19, 2008 9:25 AM To: 'Jackson Jr., Robert' Cc: Polya, Joe; Hazzard, Vance Subject: RE: Sundry Application - Digital Copy Robert, Joe and Vance, I have examined your proposal and the proposed plugging plan is as we discussed. I will speak with the Commissioners to seek oral approval. In your letter, you state that the "new" penetration will be named ODSK -33A. This is not necessary since the new penetration will sidetrack around junk and the originally planned BHL is still the target. The lost hole section will be named ODSK- 33PB1. Your directional and logging personnel should be familiar with the protocol. In our latest conversation, you indicated a desire to reduce the circulated plug volume to the gage volume due to expectation (since you are stuck) that the hole likely does not have much washout. This is probably prudent. Call or message with any questions. We look forward to receiving the "hard copies" shortly. Tom Maunder, PE AOGCC From: Jackson Jr., Robert [mailto:Robert.Jackson @pxd.com] Sent: Wednesday, March 19, 2008 7:30 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: Sundry Application - Digital Copy Tom, Please note the attached pdf of the Sundry Application for ODSK -33. We will be hand delivering the signed hard copy (with attachments) this morning but wanted to give you an opportunity to read it earlier. Regards, Robert Jackson Senior Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. Office 907- 343 -2186 Cell 907- 748 -3914 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. 3/19/2008 • • MD TVD Spacer bbl Mud bbl Cement bbl Pump Capacity bbl /stk 0.0846 Got this from the rig Drill String stks 938 Drill string bbls 70 Hole Diam. inch 8.7 NMI Use 8.75 and /or 10.75 to compare volumes with Drill String Inch 6.25 Average OD (better to use actual OD) Annulus Cap bbl/ft 0.0364 0% Washout BHA Top 7058 5193 BHA Top ft 7058 Using Wet View Report Information BHA Bottom ft 7965 Using BHA strap from Well View BHA Length ft 907 Using BHA strap from Well View Spacer Lead bbl /min 5 Contact Time (5 to 10 per min) as per Halliburton Spacer Lead min 5 Contact Time (5 to 10 per min) as per Halliburton 25 ion Con: Bott. Fish 7965 Spacer Lead ft 490 Length based upon Average Drill Pipe annuluar capacity Spacer Lead MD 6568 Top of Spacer Lead after displacement Cement MD 7058 Top of Cement to cover BHA Cement ft 907 Required to cover BHA TD 9730 6072 Cement bbl 33 Volume based upon BHA Annular Capacity Cement bbl 33 Volume based upon % excess Cement bbl 6 Volume of cement in BHA bbl 39 Total volume required (including 30% exc.= bbl 457 Strokes to numb cement Spacer Tail MD 6568 Top of Spacer Lead Spacer Tail MD 7058 Top of BHA Spacer Tail ft 490 Length of Drill Pipe Spacer 1 5 .er in drill pipe Spacer Taii 58 Si -+;, r ,rip Spacer Tail Displacement bbl 65 Volume of Mud to Place Cement Displacement stks 772 Strokes to place Cement • • IMIT rrj) \ [ L M I SARAH PALIN, GOVERNOR ALASKA. OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279 -1433 Joe Polya FAX (907) 276 -7542 Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G. Street, Suite 600 Anchorage, Alaska 99503 Re: Oooguruk Unit, Oooguruk- Kuparuk undefined, ODSK -33 Sundry Number: 308 -088 Dear Mr. Polya: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, pi r Daniel T. Seamount, Jr. Chairman DATED this day of March, 2008 End. Page 1 of 1 • Maunder, Thomas E (DOA) From: Polya, Joe [Joe.Polya @pxd.com] Sent: Tuesday, March 18, 2008 11:38 AM To: Maunder, Thomas E (DOA) Subject: FW: Stuck BHA Diagram Attachments: D00001.PDF; Stuck BHA Diagram.xls Tom, I will be calling you about ODSK -33 Plan Forward here is some well info to facilitate our discussion. 9oe Po4a Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya(cUpx d.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 From: Jackson Jr., Robert Sent: Tuesday, March 18, 2008 11:35 AM To: Polya, Joe Subject: Stuck BHA Diagram Here is the diagram, spreadsheet (which we can change), pdf of diagram with surveys, etc.... Regards, Robert Jackson Senior Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. Office 907 - 343 -2186 Cell 907 - 748 -3914 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. 9/2/2009 1 Top Toroq @ 6621' MD / 5022' TVD Top of Fishing Assy • 7058' MD / 5193' TVD .i Base Toroq @ 7300' MD / 5288' TVD Top of Fish (Drill Assy) 7371' MD / 5317' TVD 4 Top HRZ @ 8602' MD / 5798' TVD Base HRZ @ 8961' MD / 5925' TVD Bottom of Fish (Drill Assy) 7974' MD / 5559' TVD Top Kalubik @ 9312' MD / 6002' TVD • • Ku saruk @ 9696' MD / 6066' TVD BHA Description Length OD ID XO 1.58 6.500 3.125 Accelerator 12.84 6.250 2.250 TD @ 9730' MD / 6072' TVD DC 276.02 6.375 2.750 mp out 1.49 6.250 2.063 A 11.57 6.250 2.250 umper 9.03 6.250 3.125 HWDP 335.70 4.000 2.563 Drilling Jars - Hydraulic 37.72 6.250 2.250 HWDP 91.65 4.000 2.563 XO Sub 1.00 6.750 2.500 NMDC 31.05 6.750 2.813 NMDC 31.08 6.750 2.813 8.5 Stabilizer" 5.65 6.750 2.830 Drill Collar - Flex Non Mag 31.07 6.813 2.813 6 3/4 TM HOC" 9.55 6.500 1.920 Drill Collar - Flex Non Mag 15.33 6.813 2.813 8.5 Stabilizer - Near Bit (PF)" 4.22 6.750 2.813 Overall Length 906.55 • • Sperry Drilling Services < INEITE DIRECTIONAL SURVEY REPORT Pioneer Natrual Res AK ODSK -33 Oooguruk North Slope Bourough Alaska U.S.A. 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W 2289.95 3.86 9697.58 80.19 134.95 6066:46 1982.82 S 3767.94 W 2331.73 2.78 At e t - x w v A CA1. li S lib A18 NRJNI GUR1Y "TARE a E , , � SUN OQR E t,i. O S a E a PO f A T z A ,SE 3O `15 A D +' C 0 EEG E5 h Sit ToTA CORRECTIO . AF 22 57 EG F ' ,MAG 7 TR H t 1 = es r .. ',,". sRI20 . `DIS • L:AC NE 1 = ` °T T ':,4,-,. ° , , W • 0 & - H OE.@ E ., A CENI �' ic 7 . J ' ,, - s :" -.' ,, -.7 - -- ^B us ' s E C .- v, EEG . :�n . „' ...... .:.. : ..:� ,.;.:....0 _ ...e .,.,..:, <,...... )ate Printed:06 March 2008 • ! 0 - c t I ... __. _ m.... i 400 ! { 800 . " i , 1 I ; 1200 ' i i--' �.._ _ �___,__..... {.... 1600 `. I , I I ! I i _ 2000 1- I ._....- .. _• ..__..._ _ i • . __- _._ _ ...- - _._... ._ - - __ .... - _ - ___- - _.-.,- __,..__ _. -_ - .. _ - •_•. _ _ -. _ ._ _ _ _ ._.. _. .._ - . -...._ =; ±- -- - ---- -- °-- - -.___ --- .--- -._--- -- - - - -- i ._ __.._ .__.__. ..._ 2400 ! I ■ { I 3 i O 2800 �' I ` r - -- -_ 1 r CO 1 D 3200 E — . _ .. . > 3600 [ I i j ! F L r L + I ' 4000 ; I 1, I I . i 4400 I I I i' 4600 1 ' - __ .,__, .._ 4 i 5200 5600 ! j : ■ 6000 I I 1 1 1 1 1 T 1 1 1 1 1 1 I I - r I I I r ' r r 1 r ' i I r 1 1 1 1' III I 11 I I I I I I 1 r I 1 1 1 1 1 ! I I I 1 7 1 1 -1600 - 1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 Vertical Section at 185.45bearing (800 ft/in) Page 1 of 2 • Regg, James B (DOA) From: Crisp, John H (DOA) Sent: Sunday, March 09, 2008 1:22 PM To: OoogurukDrillingSupervisor 5 1 (t A p eb Cc: Regg, James B (DOA) aq Subject: RE: Nabors 19AC Weekly BOP Test I can grant you an extension from the 7 day test to run casing & cement. Please give us an opportunity to witness your BOP test after casing is run & cemented. If for any reason you should have to POOH with casing you would be expected to test @ that time. Good luck with your Operation. Thanks JC. From: OoogurukDrillingSupervisor [mailto:OoogurukDrlgCm @ pxd.com] Sent: Sunday, March 09, 2008 8:16 AM To: DOA AOGCC Prudhoe Bay Subject: FW: Nabors 19AC Weekly BOP Test From: OoogurukDrillingSupervisor Sent: Sunday, March 09, 2008 7:20 AM To: 'doa.aogcc.prudoe.bay @alaska.gov' Cc: Franks, James (James.Franks @pxd.com); Polya, Joe (Joe.Polya @pxd.com) Subject: FW: Nabors 19AC Weekly BOP Test Wrong e -mail address the first time, sorry. From: OoogurukDrillingSupervisor Sent: Sunday, March 09, 2008 7:15 AM To: 'doa.aogcc.prudhoe.bay @alaska.com' Cc: Franks, James (James.Franks @pxd.com); Polya, Joe (Joe.Polya @pxd.com) Subject: Nabors 19AC Weekly BOP Test John, It doesn't look like we will be running our 7" Casing before 2400 hrs on 3/9. During the trip out we had to backream a lot because of adverse hole conditions. That and having to do a clean out run to wipe the hole will put us past our deadline at 2400hrs. on 3/9. It would be nice if we could delay the test until after we get our 7" casing on bottom. I know we talked about this already and was just wondering what your thoughts are. My thoughts are getting this casing stuck off bottom creates a lot of issues we really don't need to deal with if we can help it. Not only on the rig side but not getting the HRZ and Kalubik shale covered and cemented off. Your thoughts? Rodney This email was sent on 3/9/08 at 7:15 AM by klepzigr. This email was sent on 3/9/08 at 7:20 AM by klepzigr. This email was sent on 3/9/08 at 9:15 AM by klepzigr. 3/10/2008 Page 2 of 2 • 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. 3/10/2008 Page 1 of 1 i Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Saturday, March 08, 2008 8:27 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance; Campoamor, Kathy Subject: Deviation from planned Ooogruuk development schedule Tom, With the delays we are experiencing on the ODSK -33 well, it now appears that we will not be able to get back onto the ODSK -35 well and drill the Kuparuk prior to the commencement of the restricted drilling season. As such, we will get a 10-407 package together and turned into you ASAP. If you have any questions or comments, please don't hesitate to contact me. Take care, james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. c 96O9 Page 1 of 2 • Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Friday, February 29, 2008 2:41 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; AOGCC North Slope Office Subject: RE: (PTD 207 -183) ODSK -33 BOP Test Extension Request Understand the caveat. Thanks for the discussion. james From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, February 29, 2008 2:35 PM To: Franks, James Cc: Polya, Joe; AOGCC North Slope Office Subject: RE: (PTD 207 -183) ODSK -33 BOP Test Extension Request James, You captured our discussion. The one caveat to this forward plan is, if you have to come to the bank before reaching TD then you have to test the BOP equipment. Call or message with any questions. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @ pxd.com] Sent: Friday, February 29, 2008 2:30 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe Subject: (PTD 207 -183) ODSK -33 BOP Test Extension Request Tom, Just wanted to get the conversation with Joe documented and make sure I didn't miss anything in translation - I had to step out to talk to the rig... Current Status: The rig is currently about 1000' from TD and is experiencing a bit of hole trouble. We are currently attempting to regain pipe movement and fluid flow as we speak. We have a BOPE Test due 3/1 based on a 7 day testing schedule. We request an extension on the BOPE testing requirements. Plan forward: Once we have alleviated the trouble we are currently in, the plan would be to drill to TD, perform out wiper trips and conditioning of the hole to run casing and then trip out of the hole. Change out the pipe rams from 4" DP to 7" casing. Test the rams and the annular preventer to the 7" tubular and perform a body test on the choke manifold as we have not broken anything on the manifold (A full test 2/29/2008 Page 2 of 2 • on the manifold will be done following the changing of the rams back to 4" dp) Run our casing and cement. Change the rams from 7" casing to 4" dp and conduct a full BOPE test on the rams, preventer and choke manifold - this would allow us to restart the 7 day clock and stay in the hole as long as possible in the lateral. Please let me know if you concur with our plan. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 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. 2/29/2008 • • Weekly Operations Report ODSK -33 Permit No. #207 -183 PIONEER ` �. NATURAL RESOURCES C Weekly February Activities Februa 18 - February 24, 2008 2/18/2008 199' RECONNECT SUPPLY LINES IN HUTZ. MOVE RIG OVER ODSK -33. LEVEL PAD & SQUARE TO WELL BAYS. INSTALL VETCO STARTING HEAD, FUNCTION TEST DIVERTER & GAS DETECTORS. RU GYRO WIRELINE. MU BHA, REAM OUT CONDUCTOR T/153'. DRILL T/199'. CLEAR PLUGGED CCU LINES. 2/19/2008 1746' DRILL, SLIDE/ROTATE & SURVEY F/199' T/1,746' MD. 2/20/2008 3183' DRILL & SURVEY F/1,746' T/3,183' MD. CBU HI -VIS SWEEP 1 -1/2 TIMES. POOH TO 3000'. TROUBLE SHOOT TRIP TANK. 2/21/2008 3183' SHORT TRIP TO JARS, WORK THRU TIGHT SPOTS. CIRCULATE & CONDITIOIN UNTIL SHAKERS CLEAN. POOH, WORK THRU TIGHT SPOT AT 2944'. CONTINUE POOH, RACK BACK 5 STDS HWDP. LD DIRECTIONAL ASSEMBLY, RU CASING TOOLS. MU SHOE JOINT & 1 INTERMEDIATE JOINT & CIRC THRU FLOAT SHOE. 2/22/2008 3183' RUN 9 -5/8 CASING, WORK THRU TIGHT SPOTS FROM 2920' TO 2985'. LAND CASING WITH HANGER AND LANDING JOINT. CIRC & CONDITION, MIX & PUMP CEMENT. PUMP LEAD CEMENT 240bbIs TYPE 'L' PERMAFROST & 45bbis TYPE 'G' TAIL CEMENT. 80bbls CEMENT RETURN TO SURFACE. FLUSH DIVERTER AND RISER, ND SAME. 2/23/2008 3183' INSTALL VETCO WELLHEAD, TEST TO 5000psi. NU BOP STACK, TEST BOPE. SLIP & CUT DRILL LINE. MU BHA & SURFACE TEST SAME. PU 4" DRILLPIPE. 2/24/2008 3183' MU BHA #2. PU & SINGLED IN 60 JTS DRILL PIPE. DRILL OUT PLUGS/FLOAT COLLAR & CEMENT TO 3,161'. CBU & ATTEMPT TO TEST CASING, POOH. e Ha v'. riln Date ng Superij nt Pioneer Natural Resources, Alaska, Inc. • • ,,I Weekly Operations Report ODSK -33 Permit No. #207 -183 PIONEER NATURAL RESOURCES Weekly Activities February 25 - March 2, 2008 2/25/2008 3196' LD & RACK BACK BHA #2. MU BHA #3 WITH RTTS & TIH. SET & TEST CASING 3500psi FOR 30 MIN. POOH RTTS & LD SAME. MU BHA #4 & TIH. DRILL CEMENT & FLOAT SHOE F/3163' T/3173'. CLEAN OUT RAT HOLE T/3183' & DRILL 13' NEW FORMATION. 2/26/2008 4821' DRLG AHEAD 8 -3/4" HOLE SECTION F/3196' T/3203'. CIRC & RU TEST EQUIPMENT. PERFORM LOT, RD TEST EQUIPMENT. DRILL F/3203' T/4064'. GEO PILOT EXPERIENCING SOME ROLL & HOOKING ISSUES. TROUBLESHOOT MODE SWITH ON MWD TOOL. CHANGE SHAKER SCREENS. DRILL F/4064' T/4821'. EXPERIENCING HOOK UP PROBLEMS WITH GEO PILOT. EXPERIENCE PACK OFF & LARGE SHALE TO SURFACE. 2/27/2008 6500' DRILL AHEAD F/4821' T/5610'. DRILL F/5610' T/6340'. CHANGED #1 PUMP CENTER SUCTION CAP GASKET. DRILL F/6340' T/6500'. 2/28/2008 8034' DRILL AHEAD F/6500' T/7347'. DRILL F/7347' T/8034'. SERVICE TOP DRIVE & TRAVELING BLOCK WHILE CHANGE SWAB & LINER ON #2 PUMP. 2/29/2008 8491' Drill F/8034' T/8491'. WORK STUCK PIPE; PIPE FREE. CIRCULATE & CONDITION MUD. WIPER TRIP TO 7814'. 3/1/2008 8491' FINISH SHORT TRIP TO 6640', WORKED THRU TIGHT SPOTS. TIH TO 8313', WASH & REAM F/8313' T/8491'. REAMED OUT OBSTRUCTION F/8474' T/8484'. CIRC & CONDITION, PUMPED HI -VIS WEIGHTED SWEEP. TROUBLESHOOT MWD FAILURE. PUMP 30bbls FRESH WATER PILL - NO SUCCESS. POOH T/6478. TROUBLESHOOT MWD WHILE CIRC & COND, NO SUCCESS. PUMP SLUG, POOH. LD BHA, UNLOAD NUKES & DOWNLOAD MWD. CLEAN BALLED UP STABS & BIT. 312/2008 8491' POOH, LD BHA #4. TEST BOPE. MU BHA #5, TIH. MIA 3465 ante Y. zzar• ` Date I tilling Superintendent Pioneer Natural Resources, Alaska, Inc. • • 0:7 Weekly Operations Report ODSK -33 Permit No. #207 -183 PIONEER NATURAL RESOURCES Weekly Activities March 3 - March 9, 2008 3/3/2008 9029' FINISH TIH T/8400' & WASH T/8491'. NO FILL, CIRC & CONDITION. DRILL 8 -3/4" HOLE T/9029'. 3/4/2008 9471' DRILL 8 -3/4" HOLE WITH GEO -PILOT F/9029' T/9199'. CIRC & CONDITION, ATTEMPT CHECK TRIP HAD EXCESS DRAG AT 8990'. TIH, WASH & REAM TO BOTTOM. DRILL AHEAD T/9471' WHILE BUILDING MUD WEIGHT TO 11.0ppg. 3/512008 9730' DRILL F/9471' T/9682', CIRCULATE BU. DRILL F/9682' T/9705', CIRCULATE BU, DRILL F/9705' T/9730'. BACK REAM OUT OF HOLE F/9730' T/9374'. TIGHT HOLE, HOLE PACKING OFF. WORK THRU TIGHT SPOTS. 3/6/2008 9730' BACK REAM & CIRCULATE F/9374' T/6960'. USE PARAMETERS AS HOLE DICTATES. GHOST REAMERS HAD PROBLEMS COMING THRU 5538' - POSSIBLE KEY SEAT. 3/7/2008 9730' BACK REAM F/6960' T/5899'. HIT TIGHT SPOT & JAR PIPE FREE. RESUME BACK REAMING F/5839' T/5250'. HIT SECOND TIGHT SPOT, JAR PIPE FREE. RESUME BACK REAMING F/5190' T/4800'. 3/8/2008 9730' BACK REAM F/4800' TO SHOE AT 3173'. OBSERVE WELL, CBU AT SHOE & OBSERVED A LOT OF CUTTINGS UPON BOTTOMS UP. POOH & LD BHA. CONDUCT POST JARRING DERRICK INSPECTION. 3/9/2008 9730' FINISH WITH POST JARRING RIG SERVICE, MU BHA # 6 & RIH TO 8424' ON ELEVATORS. EXPEREINCING HOLE PROBLEMS & STARTED REAMING TO BOTTOM F/8424' T/8850' WITH NO PROBLEMS. ENCOUNTERED HIGH TORQUE & DRAG AT 8850'. WORKED THRU TIGHT SPOT F/8850' T/8884'. RESUME REAMING TO 8819' AND PIPE BECAME STUCK. WORKED PIPE FREE AND ATTEMPT TO WORK THRU THIS AREA. Ott i 0 100 V ce H. 4;1 1b. Date ri ing Superinte t sneer Natural Resources, Alaska, Inc. • • Weekly Operations Report ODSK -33 Permit No.#207 -183 PIONEER NATURAL RESOURCES Weekly Activities March 10 - March 16, 2008 3/10/2008 9730' PULL PIPE TO SAFE ZONE AT 8696'. BUILD MUD WEIGHT TO 11.5ppg WHILE WORKING PIPE. WASH & REAM T/8,991'. PIPE BECAME STUCK AGAIN. WORK BACK UP T18,805' & ESTABLISH GOOD HOLE. SLOWLY WASH DOWN CLEANING HOLE T/8,836'. 3/11/2008 9730' WASH & REAM T/8861'. BECAME STUCK, JAR FREE & WORK PIPE T/8,704'. BUILD & DISPLACE 11.5ppg MUD WITH 12.0ppg MUD. WASH & REAM F/8,704' T/9,008'. REAM FOR 32' AND BACKREAM SAME 32' SECTION. LOG CHANGE IN PARAMETERS AND CONTINUE WITH NEXT 32' SECTION. 3/12/2008 9730' WASH & REAM TIGHT SPOTS F/9,008' T/9,383'. 3/13/2008 9730' WASH & REAM F/9,348' T/9,707'. HIT REFUSAL AT 9,707'. DECISION MADE TO STOP. 3/14/2008 9730' HIT REFUSAL 0 9707'; ATTEMPT DIFFERENT COMBINATIONS TO WORK PAST SPOT. CBU 3 TIMES. PULL A WIPER TRIP TO 8,250' WITH NO PROBLEMS. RIH F/8,250' T/9,280'. WASH F/9,280' T/9,707'. CIRC & DISPLACE, CIRCULATE HOLE CLEAN. POOH F/9,707' T/5,130'. TEST CHOKE MANIFOLD ON TRIP OUT. 3/15/2008 9730' POOH WITH BHA # 6 F/5,132' TO SURFACE. DISCOVERED BOTTOM TOOL JOINT WAS MISSING ALONG WITH 15 OF THE TUBE & THE REST OF THE BHA WAS LEFT IN THE HOLE. RU & TEST BOP TO AOGCC REGULATIONS. PU FISHING TOOLS & 6-1/4' DRILL COLLARS T/320'. 3/16/2008 9730' RIH W/FISHING ASSEMBLY F/324' T/6,826'. WORK TIGHT SPOT F/6,826' T/6,890'. JARRED TWICE & WORK PIPE BACK T/6,788'. RIH F/6,788' T/7,000' WHERE FISHING ASSEMBLY BECAME STUCK. WORK PIPE DOWN WITHOUT JARRING T17,094' WHERE WEIGHT BROKE OVER. RIH F/7,094' T/7,566'. SPOT LCM PILL ACROSS THE BHA TO THE TOP OF THE TOROK FORMATION 0 6,812'. RIH F/7,566' T/8,435'. START WASHING F/8,435' TO THE TOP OF THE FISH AT 8,842' (BIT AT 9,438'). HOOK ONTO & ESTABLISH CIRCULATION THRU FISH. PULL FISH FREE WITH MAX OVERPULL - NO JARRING. POOH WITH FISH F/9,438' T/7,980' WHERE THE ASSEMBLY BECAME STUCK. el3144 I i_t ,_ aVaplos Vance Hazzaid Date Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. • Agar 7-iito% Weekly Operations Report ODSK -33 . Permit No. #207 -183 ( �. PIONEER NATURAL RESOURCES Weekly Activities March 17 - March 23, 2008 3/17/2008 9730' WORK STUCK PIPE @ 7,964'. 3/18/2008 9730' CONTINUE TO JAR ON FISH. 3/19/2008 9730' CEMENT FISH IN HOLE, RU SLB WIRELINE & RUN FREE POINT. 3/20/2008 9730' RIH WITH SEVERING TOOL, SEVER PIPE @ 6920' MD. POOH. 3/21/2008 9730' MU CEMENT DIVERTER SUB. TIH TO TOP OF FISH, SPOT 17.9ppg MUD. PULL 100'. CIRCULATE & CONDITION TO BALANCE FLUID. 3/22/2008 9730' CBU, SET CEMENT KICK OFF PLUG. POOH TO +1- 6100'. CBU, POOH. TEST ROPE, MU 8 -3/4" MOTOR SIDE TRACK ASSEMBLY. RIH. 3/23/2008 9730' RIH, WASH & REAM. HAD FIRM CEMENT, SIDE TRACK WELL. DRILL & SURVEY T/7002'. Coe 1454(rf 0 3A(e/08 Vance Hazzard Date Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. • • Weekly Operations Report ODSK -33 Permit No. #207 -183 PIONEER NATURAL RESOURCES Weekly Activities March 24 - March 30, 2008 3/24/2008 7560' SLIDE, DRILL & SURVEY F/7002' T/7560'. 3/25/2008 7933' SLIDE, DRILL & SURVEY F/7560' T17933'. 3/26/2008 8190' SLIDE, DRILL & SURVEY F/7933' T/8190'. CBU 2 TIMES, PULL ON ELEVATORS T /6610'. PUMP & BACK REAM F /6610' T/5844'. 3/27/2008 8190' WORK TIGHT. SPOTS F/5844'- T/5837', JAR FREE. BACK REAM T/4111'. PUMP OUT F/4111' T/3148', CBU 2 TIMES UNTIL SHAKERS CLEAN. PUMP SLUG, BLOW DOWN TDS. POOH, LD BHA. PU GEO- PILOT, BIT & MWD. RIH. 3/28/2008 8617' RIH TO SHOE, CBU. RIH B/C EACH 30 STANDS. TAG OBSTRUCTION AT 7012'. WASH & REAM F/7012 T/8190. DRILL F /8190' T/8617'. 3/29/2008 9265' DRILL F/ 8817' T/9265'. 3/30/2008 9718' DRILL F/9265' T19718'. ATTEMPTED DIFFERENT WEIGHTS & ROTARY WITH NO SIGNIFICANT CHANGE IN ROP. nce H - .71 Date fling Supe - • : nt - toneer Natural - -sources, Alaska, Inc. • • Weekly Operations Report ODSK -33 Permit No. #207 -183 PIONEER NATURAL RESOURCES Weekly Activities March 31 - April 6, 2008 3/31/2008 9808' DRILL T/9808'. ATTEMPT SHORT TRIP, HAD TIGHT HOLE & PRESSURE LOSS. WASH BACK TO BOTTOM & VERIFY PRESSURE LOSS. POOH, WASH & REAM AS NEEDED. POOH WITH LOW PUMP RATE. 4/1/2008 9808' POOH THROUGH MULTIPLE TIGHT AREAS. DRILL STRING FAILED WITH TOP OF FISH AT 4,199' & BOTTOM AT 6,225'. POOH WITH DRILLPIPE. RU, TEST ROPE. WITNESS OF TEST WAIVED BY JOHN CRISP WITH AOGCC. RD & SET WEAR RING. SLIP & CUT DRILL LINE. MU FISHING ASSEMBLY. 4/2/2008 9808' MU FISHING BHA & RIH PICKING UP NEW 4" DP T/4,187'. START WASHING & ENGAGE FISH AT 4,216'. JAR ON FISH WHEN GRAPPLES RELEASED AT 4,163'. POOH TO FIND 4.875 GRAPPLES SLIPPED OFF & PACK -OFF WAS WASHED OUT. CHANGE OUT GRAPPLES, INSTALL A MECHANICAL JAR ABOVE THE OVERSHOT. CHANGE OUT PACK -OFF. 4/3/2008 9808' MU FISHING ASSEMBLY WITH 4.75 GRAPPLE. RIH START WASHING AT 4,163' & CHASE FISH DOWN TO 4,266' WHERE WE ENGAGED SAME. JAR FISH FREE & POOH. LD FISHING BHA & FISH. 4/4/2008 9808' LAY OUT DC USED IN FISHING OPERATIONS. RIH WITH USED 4" DRILLPIPE & LAY OUT SAME. 4/5/2008 9808' PU NEW 4" DRILLPIPE T/3,090' & RACK BACK. PU BHA & SHALLOW PULSE TEST THE MWD. RIH WITH REST OF BHA T/598'. PU 28 JTS 4' DRILLPIPE & LAY OUT. PU 75 JTS NEW 4' DRILLPIPE T/2,912'. CIRCULATE DRILLPIPE VOLUME & RIH ON ELEVATORS FILLING EVERY 20 STANDS T/8,505' WHERE WE HIT REFUSAL. WASH & REAM F/8,505' T/8,600'. 4/6/2008 9808' RIH ON ELEVATORS F/8,600 T18,700. PUMP WITH NO ROTATION F/8,700 T/8,800. RIH ON ELEVATORS F/8,800' T/8,993'. EXPERIENCED HOLE PROBLEMS. WASH & REAM F/8,993' T/9,764'. REAMING EXTREMELY DIFFICULT F/8,993' T/9,275'. PREPARE NEW MUD. 4trik .60 rice H- Date 4 ! ling Superinte dent Pioneer Natural Resources, Alaska, Inc. • • Weekly Operations Report ODSK -33 tr„ Permit No. #207 -183 PIONEER NATURAL RESOURCES Weekly Activities April 7 - April 13, 2008 4/7/2008 9808' WASH & REAM T19,808'. CIRCULATE & CONDITION, DILUTE OLD MUD WITH 500bbls OF NEW MUD PRIOR TO SHORT TRIP. STAND BACK 1 STAND EVERY HOUR TO PREVENT UNDER CUTTING HOLE. PULL SHORT TRIP F/9,669' T18,525'. HIT TIGHT SPOTS & WORKED THRU SAME. RIH T19,808' & WASH TIGHT SPOT AT 9,115'. CIRCULATION & CONDITION MUD & ADD SECOND DILUTION OF NEW MUD. SPOT LCM PILL ON BOTTOM & POOH. HIT TIGHT SPOT @ 6,050'. CIRC & CLEAN SECTION. 4/8/2008 9808' BACK REAM; PUMP OUT OF HOLE. HOLE CLEANED UP. POOH ON ELEVATORS. RACK BACK 4 STANDS HWDP & LAY OUT 2 JOINTS HWDP & JARS. LD REST OF THE BHA. TEST CHOKE MANIFOLD. PULL WEAR BUSHING. CHANGE PIPE RAMS TO 7'. PU TEST JOINT & TEST PLUG, RIH & SET. TEST UPPER 7" RAMS & ANNULAR. 4/9/2008 9808' FINISH TESTING 7" RAMS & VALVES. RU TO RUN CASING. MU FLOAT, SHOE TRACK & FLOAT. RIH WITH 7" 26# L -80 CASING T/9,741'. 4/10/2008 9808' LAND 7' CASING, SHOE AT 9,793'. FLOAT AT 9,707'. CIRCULATE AT STAGED RATE & INCREASE SLOWLY. CBU. CEMENT 7' CASING WITH 181 SACKS PREMIUM CEMENT. DID NOT PUMP PLUG - FLOAT HOLDING. RD CASING & CEMENT EQUIPMENT. PU TEST PLUG & TEST BOP'S. MWD HAVING TROUBLE COMMUNICATING. SHIFT OPERATION FROM PU BHA TO PU DRILLPIPE NEEDED FOR NEXT HOLE SECTION. 4/11/2008 9808' PU 4' DRILLPIPE WHILE WORKING ON MWD TOOLS. CIRCULATE ONE DRILLPIPE VOLUME & POOH. STAND BACK PIPE IN DERRICK. PU BHA & TEST MWD TOOLS. 4/12/2008 9808' MU BHA # 13, LOAD SOURCES & TEST. TESTED OK. PU REMAINING PIECES & COMPLETE FINAL TEST. FREEZE PROTECT 7" X 9-5/8' ANNULUS. RIH ON DRILLPIPE - ENCOUNTERED DRAG. WASH F/9,436' T/9,682' WHERE TOP PLUG WAS ENCOUNTERED. RU TO TEST CASING. PERFORM LOT. DRILL SHOE TRACK EQUIPMENT. FINISH DRILLING FLOAT 0 9,709' & WENT TO 9,793' WITH NO CEMENT IN SHOE TRACK. 4/13/2008 9828' FINISH DRILLING OUT FLOAT EQUIPMENT & BBL SHOE 0 9,793' WITH NO PROBLEMS. CLEAN OUT RATHOLE 9,793' TO 9,808'. DRILL NEW 6-1/8" HOLE T/9,828'. CBU & PULLED BACK INTO CASING. PEFORM LOT. RD TEST EQUIPMENT & SUP/CUT DRILLING LINE. PUMP DRY JOB. BLOW DOWN TOP DRIVE & POOH FOR RTTS. RACK BACK BHA. 8 Vance Hazza • _ Date rifling Superintendent Pioneer Natural Resources, Alaska, Inc. !- Weekly Operations Report ODSK -33 Permit No.#207 -183 PIONEER NATURAL RESOURCES Weekly Activities April 14 - April 20, 2008 4/14/2008 9808' FINISHED RIH 179.650' & SET RTTS. PERFORM 3500asi CASING TEST. UNSEAT RTTS & POOH FOR BHA #15. PU & MU HES TOOLS & RIH WITH SAME FILLING PIPE EVERY 25 STANDS. 4/15/2008 9967 FINISH RIH WBHA #15 T/9,828' - NO FILL WORK ON BHA COMMUNICATION PROBLEMS. DRILL T/9,845' - FRACTURE WITH 120bph LOSSES, SPOT Ca CARBONATE PILL CONTINUE TO DRILL 179,882' - 2nd FRACTURE, SPOT 2nd Ca CARBONATE PILL CONTINUE DRILLING T/9,967. MIX MUD DUE TO 3rd FRACTURE. PULL TO SHOE & SPOT ANOTHER Ca CARBONATE PILL IN CASING & MONITOR LOSSES, BUILD VOLUME. 4/16/2008 10448' BUILT VOLUME DUE TO LOSSES, STAGE PUMPS UP TO CIRCULATION LOSS. SPOT 25bbls BARACARB 150 LCM PILL & NOTE LOSSES WITH PILL IN PLACE, 7-8 BPH WITH FILL ACROSS TOP OF ANNULUS. DRILL F/9,967' T/10,448'. LOST TOTAL RETURNS. SPOTTED 30bbls 75# • YT• .• ; • _ ► v •n_.. . o. ACROSS TOP OF HOLE 4 BPH. LOSSES DOWN TO ZERO WITH NO PUMP. 4/17/2008 10448' PUMP FORM -A -PLUG FROM VAC TRUCK TO Prr. TIH WHILE MIX SPACER. PUMP SPACER, ADD ACCELERATOR TO PLUG PILL & PUMP SAME. DISPLACE WITH 109bbis 9.9 MUD & PULL T/9,280'. WELL SWABBING, ROTATE EACH STAND TO ALLEVIATE SWAB. ATTEMPT TO , B/CIRC. PIPE PLUGGED. HESITATE SQUEEZE DOWN ANNULUS AT 35Svm FOR 4Obbls WITH 9.9ppg MUD. BACK PRESSURE STEADY WHEN WELL PUMP SHUT DOWN. BUILD MUD WEIGHT & PUMP DOWN ANNULUS. OPEN ANNULAR, MUD FELL BELOW WELLHEAD. FILL 11bbIs 10.5ppg. MONITOR FOR LOSS RATES WITH PIPE STATIC. PULL F/9,280' T/7,863'. CHECK LOSS RATES. 4/18/2008 10448' POOH, MONITOR LOSSES EACH 5 STANDS. FOUND DRIFT AT 4,005'. STATIC LOSSES 13bph, LD PLUGGED DRILLPIPE TO 1,511'. 4/19/2008 10448' POOH, LD BHA PLUGGED WITH FORM -A -PLUG. BULL HEAD 30bbis TO BALANCE FLUID. BULL HEAD 40bbis 10.0ppg TO RU KILL UNE TO OA VALVE TO MONITOR WELL DURING BOPS. TEST BODE PER AOGCC. BULL HEAD lObbis BELOW TEST PLUG - WELL STATIC. RD TEST EQUIPMENT. RIH WITH DRILLPIPE. CIRC 10bbis SAP/NUT PLUG PILL TO CLEAR RESIDUAL FORM -A -PLUG, 3500 UNITS GAS, SLIGHT FLOW WHEN PUMPS SHUT OFF. PUMP 50bbls 10.5ppg MUD TO INDUCE SLIGHT LOSSES FOR TRIP OUT OF HOLE. POOH, kW NEW BHA & SURFACE TEST. 4/20/2008 11042' FINISH MU BHA #16 & RIH. BC AT 427' & SURFACE TEST, ALL OK. RIH, BC AT 3320. CIRC 01 IT 2614 UNITS GAS & BALANCE MUD COLUMN WITH 15bbbls MUD DOWN PIPE. RHH 177,180'. CBU, EXPERIENCED 3bbl LOSS DURING TIH. WELL STATIC WHEN PIPE STILL. CIRC OUT 1050 UNITS, LOSSES 13.8% PUMP RATE. OBSERVED TRACES OF FORM - A-PLUG ON SURFACE RIH T/9,780'. B/CIRC, ATTEMPT TO CBU 0 190wm.100% MUD LOSSES. HOLE FULL & STATIC. — A IN WITH BHA T/10,270' WITH 18 -24bhp LOSSES. WASH & REAM F/10,207 T/10,448'. 42spm, 900psi, 100% LOSSES AT 192bph. DRILL 6-1/8" HOLE T/10,945' WITH MUD & CHANGED TO RFA WATER DOWN DRILLSTRING 10.0opq MUD CAP ON ANNULUS. DRILL T/11,047.100% LOSSES WITH MUD IN ANNULUS STAYING FULL 4e# 7 : H .r. Date D ing Superinte 71' Pioneer Natural Resources, Alaska, Inc. • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 08, 2008 1:37 PM To: 'Franks, James' Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207 -183: ODSK -33 suspension All, The original plan was to only drill the surface hole at this time. Although you plan to drill the entire well, the actual completion will be delay roughly 45 days. The well will be secured with a retrievable bridge plug and kill weight fluid and a kill string will be left in the well. The well should be satisfactorily secured. Prior to completing the well operations, the wellbore above the RBP should be pressure tested to verify integrity. No further paperwork is needed. I will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC Original Message From: Franks, James [mailto:James.Franks @ pxd.com] Sent: Friday, February 08, 2008 1:29 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207 -183: ODSK -33 suspension Tom, 10.2 ppg to 10.2 ppg drilling fluid... james From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Fri 2/8/2008 12:13 PM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207 -183: ODSK -33 suspension Thanks. Another question ...Will 10.2 ppg brine be in the hole when the RBP is set? Tom From: Franks, James [mailto:James.Franks @pxd.com] Sent: Friday, February 08, 2008 12:10 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207 -183: ODSK -33 suspension Roughly 45 days later... 1 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, February 08, 2008 12:08 PM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: PTD 207 -183: ODSK -33 suspension James, When would it be planned to return to ODSK -33? Tom From: Franks, James [mailto:James.Franks @pxd.com] Sent: Friday, February 08, 2008 11:33 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: PTD 207 -183: ODSK -33 suspension Tom, I promised to send you a note...a bit later than I intended. Sorry to swamp you with things today... We would like to deviate from the plan in the approved permit to drill on the ODSK -33 well, but only slightly. Here is what we would like to do: 1. MIRU ODSK -33 2. Drill and case the surface hole 3. Drill and case the intermediate hole 4. Drill and case the production interval (slotted liner) 5. Set a Retrievable Bridge Plug in the 7" @ 2500' MD or so 6. Run a 3 -1/2" kill string 7. Move over to ODSK -36i to drill out and complete the remaining well By doing this we are going to be able to get 3 Oooguruk - Kuparuk wells drilled prior to the beginning of restricted season. Thanks for the consideration. Let us know how we should proceed. Take care, james 2 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Friday, February 01, 2008 3:01 PM To: Maunder, Thomas E (DOA) Subject: Pioneer Oooguruk near term schedule Tom, I am not sure if I sent this to you, but here is what we are looking at for a near term schedule The current plan would be the following • Finish Surface casing on ODSK -36i with kill string • Batch Set 2 more surface casing strings with kill strings o ODSK -35 (Kup B) o ODSN -34i (IN9) • Drill ODSK -33 (Kup A) to TD — run liner — set a bridge plug in the 7" and kill string and move to ODSK -36i o by setting the bridge plug, we can defer the drilling of the ODSN -32i surface casing until after the 3 ODSK wells are drilled to TD • Drill ODSK -36i to TD — run liner and completion and move to ODSK -35 • Drill ODSK -35 to TD — run liner and complete and move to ODSN -32i o Drill to TD must be completed prior to 4/15/08 • Drill ODSN -32i surface hole and case with kill string • Complete ODSK -33 • Continue on... I will send a summary on the ODSK -33 well shortly for you to review. Have a good weekend. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. i a • • '' h\ L [f nI.LASEn SARAH PALIN, GOVERNOR ALASKA OIL AND `=AS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Polya Sr. Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Re: Oooguruk Field, Oooguruk Kuparuk Undefined Oil Pool, ODSK -33 Pioneer Natural Resources Alaska Inc. Permit No: 207 -183 Surface Location: 2965' FSL, 1102' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 1684' FSL, 1629' FEL, SEC. 14, T13N, R7E, UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness - y required test, contact the Commission's petroleum field inspector at (9 • ) 6' 9 -3607 (pager). . o : a . -- an DATED this /'"day of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA -1111.; RECEIVED ALA OIL AND GAS CONSERVATION COMWION PERMIT TO DRILL ) ` \' C3� 20 AAC 25.005 Alaska 011 & Gal Com Commission la. Type of Work: 1b. Current Well Class: Exploratory ❑ r Development Oil El lc. Specify if well is proposed for: ; dlr, l,. t,5 , ., Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 1151 Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 ODSK -33 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 15156' TVD: 6048' 4a. Location of Well (Governmental Section): 7. Property Designation: Oooguruk Surface: 2965' FSL, 1102' FEL, Sec. 11, T13N, R7E, UM ADL 355036 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 763' FSL, 4461' FEL, Sec. 11, T13N, R7E, UM 417497 1/20/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 1684' FSL, 1629' FEL, Sec. 14, T13N, R7E, UM 5760 Property: 7150' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 469896.5 y- 6031080.67 Zone- ASP 4 (Height above GL): 42.66 feet Within Pool: N/A 16. Deviated wells: N/A Kickoff depth: ‘pp ' A feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) AP Maximum Hole Angle: 9 f� deg Downhole: 3070 psig Surface: 2408 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 65# H -40 Welded 101' Surface Surface 157' 157' Driven 12 -1/4" 9 -5/8" 40# L -80 BTC 2838' Surface Surface 2894' 2806' 484 sx Permafrost'L'; 203 sx Class 'G' 8 -3/4" 7" 26# L -80 BTC -M 9858' Surface Surface 9914' 6091' 362 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 IBT -M 5392' 9764' 6084' 15156' 6048' uncemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program 12 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ell Diverter Sketch SI Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joe Polya, 343 -2111 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Joe Polya Title Sr. Drilling Engineer Signature Phone 343-2116 Date C ommission Use Only Permit to Drill 7 API Number: Permit Appro al See cover letter for other Number: ? - 1a� 50- 70 —� szcz_ OO Date: 01 pi ob requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coaled m thanee,, gas hydrates, or gas contained in shales:Rf Other: Samples req'd: Yes❑ NorZ Mud log req'd: YesR No 1 H measures: Yes❑ No ' Directional svy req'd: Yes ®' No❑ . �?, - t\ - (9.5 Q`G� , z.0?, V�5� \ r \ ° t ` �c��:v� ��,.�t -�� \\, ` ?C��,C� .jtZ. �/ elle HE Sr' - ‘,9 ► 9 ��s 1 / 4 JSPC"�� r�\WE`\ A r ROVED BY T COMMISSION DATE: J - / $.^ O g , COMMISSIONER Form 10 -401 Revised 12/2005 / Submit in Duplicate • t e.„ g c„,„ PIONEER NATURAL RESOURCES ALASKA, INC December 13, 2007 x g ,;.1 ‘ r )E-4, . 1 4 KO/ State of Alaska f41asi4 ;, I Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 ' ' ? � ' Anchorage, AK 99501 RE: Application for Permit to Drill ODSK -33 Surface Location: 2965' FSL, 1102' FEL, Sec 11, T13N, R7E, UM X = 469896.5, Y = 6031080.67, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a production 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 Pool Rules turned in, but yet to be approved. As indicated in the attachments, the drilling program will entail drilling a directional 12'/4' surface hole to approximately 2,894' MD / 2,806' TVDrkb, where surface casing will be set. An 8 -3/4" directional wellbore will be drilled into and set at the top of the Oooguruk - Kuparuk interval at approximately 9,914' MD / 6,091' TVDrkb. The horizontal production interval will be drilled to 15,156' MD / 6,048' TVDrkb, the final TD of the well. The proposed casing program will utilize 9%" surface casing, 7" intermediate casing and 4 %2" slotted liner production casing. The completion will utilize 3 %2" x 2 7/8" tubing and an ESP. It is planned to batch set a series of surface casing strings from ODS Slot 36 to slot 31 to mitigate the risk of wellbore collision and to allow PNRA to run Magnetic Ranging tools to further aid in reducing the wellbore placement uncertainty. As such, PNRA plans to drill the surface casing string for this well and then suspend the well to continue to batch drill the next slot. 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: 700 G STREET, STE 600 • ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • Alaska Oil & Gas Conservation Commission el December 13, 2007 111 Page2of3 ). PIONEER NATURAL RESOURCES ALASKA, INC 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path. 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2s contamination in the drilling mud system will be maintained on the ODS. In the future, PNRA will provide information and permitting requesting annular disposal of drilling wastes on this well. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joe Polya, Senior Drilling Engineer (20 AAC 25.070) 907/343 -2111 ioe.polya(c�pxd.com 700 G STREET, STE 600 ANCHORAGE, ALASKA 99501 • MAIN: (907) 277 -2700 • Alaska Oil & Gas Conservation Commission December 13, 2007 Page 3of34 i. .\ ` PIONEER NATURAL RESOURCES ALASKA, INC 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) 907/343 -2133 tavia.jackson @pxd.com The anticipated spud date for this well is January 20, 2008. If you have any questions or require further information, please contact Joe Polya at 907/343 -2111. Sincerely, Joe Polya Senior Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -33 Well File 700 G STREET STE 600 • ANCHORAGE ALASKA 99501 MAIN: (907) 277 -2700 • . . 1 - • . .. . . . . ..- . . . . . . . 1 .----..,..-....----....—.... 4. . . I!. . ''..= 4 1. • Legend -. %i 4j • • : : • , I 1... .. • . . 1 1Wi r rih ‘r • I As-built Conductor 0 4 , • 4 rasseel • 11 SJ".,/ s ' . I , • "A' d' ' • TI .. • 0 • . } . ..• a • 0.. e s' ..,.......,, . • e•■ 5 1. • • • ..•,... . • • . ' % % • 4 • 4. 4, l• • • .. • fo e 'f ........... • 1 - I I .I, 1 : • t* 970 ' 4 -\,.. 6 szx • . i' 1 ki intir • Location Map • • 0' • • GRAPHIC SCALE • ; / • . . . 3o IC 0 30 • ••T'f_ OF 4 k _,:h„ . . .. i • LI••=1 I t , • . • drisr......... ••1 et 1 I . , I 111 1••• ) * • • ,,,, • of ok, 0 ... Q .' %÷ I I .. c9 / :.•- ;IP. S la• •• all. • .2) 0. • • 4 . • op 11\1., • .a., t • , •.st?' $%f4. • • • 4 • • .4s • i r,••• ,' ......• 4 0,1•01r •:‘ • . . , . • t. . .. 9 , Oa • • • . i if 1 • . • r 0 • ' igp G.Dalk 6 . 1. • . .0 • . 4;5, .._. Na. 411D-5 • (is % • - 4) i i 44) '• o „„it- ow ; lb O ..••• 09. " IP • P • ‘ " •,.....• ...t, .... • • . k "°FEssiont4A" •■ • 4` . 0 ' 0 . - ‘‘, N10■06.1...." 00 "! .... r:5' • • • .1, • 4. bi ,e- .4-•-•'....::- • 0 . • J:•0 , •th• - •• ..N. • . • 1. 4if 1/ • 0 . ki 'NO 1 • ,t‘ i • 1 e el . h,. 1., . • . • . • 4 • ... t tvi.:/. • op • . • 4 41 . ' . • . • 1 : Pioneer Noturol Rosouosro . • JOB NAME: Ooliguruk DrM Sltp .• : DRAWN BY: et. CHECKED BY: MJD • LOCATION: Prot/opted Soction 11 • SCALE: 1 . Tounittlp 13 North Rang. 7 East's DATE: 7 • I • Umlot Meridian ; . Notes; . I NANUQ JOB NO. SHEET Coordinates ore listed on Ghosts 3 and 41 DESCRIPTION: Alaska Mad 27. Zone 4 Canduatcw As Kan ' i I 05204 1 of 4 I . ' . • . • I I . 1 • • 0 • 3 , , j: -sr • _ 1 i i Vistrici Evun • ' t ' SE orner o OOOGJRUX SITE Protracted Section 11 " . gi -• !1 i �'''� r I ' r a o P1- , - t ; � Ref. AK,BLAA= tt + ¢ i �• \ % i Harrison. Bay . Tract. "A 1 1� -24 \ ` I ReWl� V i l rcwir g I: _" ,Z 1 z L ` ° R�77 r f *: \ • v, : ;p 12 • 4 o Mshore Icernci oc Vbas • �� Niter Shore lcrrool:3.S1' ' la a PI 20 to Docc_orak DL • • . PI 7 it Is 1. A ��� a :,1.. • b a • .•-' a a s. 7'• ■ftwoOP ". -. • Tundra Icarno .-. ' • s a S ; PI ' Roods fo` : -ar o • ' PJ • r JS 3y.: 7i ...di i� . a te/ / P S I // y 'n, -tc ,I " r ? 5 : " I, Basis of Location I Bi•C , Mk\-- ,Q'l / .! DS -3H West Monument �' t Coordinates .1.1 la. 4 • "i N 6001016.61 • ?.R314. . . ;; • 1 E 498081.23 • S7AKED PI INFORMATION ONLY ' p • ';\1 , � A n - "I » i V „ ; - „ 'VT L Ref. Lownsbury & Assoc. Drawing No. or . ^ ' " i ----.--1". NSK 601 -d672 4 �p� 0 ...--- ...... s , , p- .'l -� 0 C 2 e 0 . e y`' » r * I y = ice = 6 .... -. ...., F I 'sa � ! ;ly G. Dods .*° ' " t � _ vti ,r,. ,t-... . i, S No.41103 : 4 • 4 ° � r ti ir , v -r 1, ,%,% b,„ 0 %,.. ) 1* or > 4 ‘''ortssierol '+ Pioneer Natural Resouces JOB NAME: Ooogu•ruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protrocted Section 11 SCALE: N/A Township 13 North ' Range 7 Eost DATE: 7 - - Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Bosis of Location 05204 2 of 4 • • • • - Wc11 -- No, -- - ... -- -- - --- --;,----- -EM--i--.:orvt. '.`` 1 6:0$1, i.n 4 469,920,45 70 29 46,241 16 - 14 45;0 3035 ion i'uo 2 6,031,10,36 09,916,62 70 29 40,19262 160 14 4:K922 P030 loe2 'mot) • a --- 6,031,1411,39 4c9,910,9 7Q 29 48,14:N - M 14 45,70375 - 3025 1087 13,50 • 4 6031,1 469i906,07 7 70 29 40.09465 150 14 4669799 3020 1092 1360 5 - 6W111,45 40,900,74 ' 70 29 40,04636 160 14 46 3015 1097 10 5 --- 0,031,126,61 09,696,60 29 46,99600 1 4 1102 - 13, - ,$0 ---- 7 0,03 9,313 - /0 29 46,87039 160 . 4666679 - 2997 11 I 8 - 6, - 031i - 00$ --- 4076:78:2 - 7 1 - 1 160 10303 2992 1120 •13 9 0,01,1 0.75 469,87,26 70 29 4.77)84 -- i$Q 14 4064814 2967 I 18,80 10 6031,098,79 469,868,4 70 2.9 "U 14460179 2562 - 7 1140 I $ 60 11 6031 09364 469,863.3 70 29 4)5,0 '10 14 2977 1136 13,50 . IIMPAIIIII • ! .7.: - 6 ),P58.47 - 70 - 150 2972 1140 Milatill 13 503101606 4645,8 1 70 29 46,498-40 160 14 47.258 2950 1152 13,50 14 0W 4904067 70 29 1 .. 160 14 4179710 Mall 157 1 ----- 603106015 - 40963696 - 70 2 160 14 47,94165 2950 11 13,50 10 ------ 0,031,001;10 409,831,04 - 70 29 46,3614 46 294 1167 13,50 17 6,031,066,26 46962611 70 294,30217 160 14 023042 2940 1172 13 1 8 - • a7416, $4 - 1 - 6-0 -- i - 4 -- A673:7 - 40 - 5 - 205 1177130 ----- - 0 - 409 - 7ti 29 4 - 1 - 60 i ii 2922 1189 150 20 -6,031,033,50 4C$,K$ 7C) 2$ 45,07e1 1 14 , g.,U0$1 - 2917 1194 13,50 Mal 6,031,028 ,6 ,als, 70 a46290f 18 2912 1199 _ 13,00 22 e,01,020,58 - 460;7937;67 --- 70 2.9 44,96014 160 14 ;49,1044 - 2907 1204 - 13,50 23 5,041:016.57 49,768.78 70 29 44, 906 1 w 14 49,32637 2902 1209 - 0, - 50 • 24 0, 469,763,64 70 29 44.66169 160 14 494 2697 1214 - 13,50 ..___ • 1 _ ..,-;,.."4%., ......••7 OF 44 12 ..--....4.6- . /' , -..,: gi ------ ----- 0 --- l'i - . . . 1 1, 9 1. i 9 7 y-'t • • ' _......t.- ,--:-- !- - -:--;,-.--- • - ,-- - ....--; •0 „ • no*, G. Davis • kV , 4 ......:..,,:,_,„ ._....,;.,,,.„....„ , Ho . 41104 4 'N.. ''' - 4- 1F-N-:‘..=4' . -- Notec NI _;•:•: ---..:: „e_. .. 1...s ... 1 S rif Ygtigng or bpeed on OP mewl SVC' LVVei, 2, Coordinotee ore boecd On AlcOsQ StOte Plane No 27, Zont 4, 3, All condvctors or within Protrocied Section 11, Pioncer Ns:turf:I Regpudev --------------- -- ---- - _ JOE NAME: Occ9uruk Drill Sit nd tQrs Condu ctors RAWN Eff: 13L CHECKED SY: MJD LOCATION; Protroot@d F 11 SCALE: N/A Towuhip 13 North Ronge 7 Ecift DATE: 7-12-07 _________ _______ AN Limit:A mer7dion ,__________ • N. - 0 - -- j (3 B - ' NO SHEET DESCRIPTION: u ili CcordinOteS 0e 2 04 3 of 4 • 1 . Alaska State Plane Section Line Offset Wet Y X -La de (i�1)- -Lo rci3 d =::- Er - -�-E� 25 6,031,128.32 469,943.64 70 29 46.01630 150 14 44.77930 3_ 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 6,031,0E5.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 allan 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 IIIIMI Ar''' . 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 , • '1; ..7:.• J 44.45.9574 • • : 13. 1 i 38 6,031,047.99 • 469,864.14 70 29 45.22304 ` 150 14 47.10995 2932 1134• , 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 _ 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 .•1144 _ 13.50 • • 41 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 _ 13.50 - 42 6,031,028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 1154. 13.50 43 6,031,015.46 469,831.70 70 29 44.90 180 . 150 14 48.06099 2899 1166 13.50 MI 6,031,010.49 469,826.79 70 29 44.65272 150 14 48.20493 2894. 1171 13.50 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 •.� pF A ( 1 11 SURVEYOR'S CERTIFICATE • - -- •-- +' :_____ •' • q' 1 HEREBY CERTIFY THAT I AM • • • - • 1 r PROPERLY REGTS`1EREI3` ANI3"+ - '•`• M -- ° J * / 4 ` m � * d LICENSED TO PRAC110E LAND YZz 0 SURVEYING IN "THE STATE OF • • .. • ALASKA ANO THAT THIS PLAT 4 - - v ` ``k �° flip G. Dovia l REPRESENTS A SURVEY DONE BY . a , .g • No. 41104 o ° r s` Ice ?:._::4-,:-‘,. " .:,-Par, ME OR UNDER MY SUPERVISION �" �°" ` �'X'f ' ' z :: ? 1( . « � • ,.. q . „ HA I BELIEVE THAT ALL AND TT ; ,L:"'" _ Y A- v- IMENSIONS l �'- 1..;;:° " A N ARE CORRECT SS 4 UEMITTED TO 5 `� �`lf -- ME BY NANUO, INC. AS OF JULY s ` -� ~� 1271-1, 2007. Pioneer Natural Resouces JOB NAME: Oocguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD. LOCATION: Protrocied Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 - 12-•07 Umiot Meridian NANUQ JOB NO. SHEET • DESCRIPTION: As - built Coordinates 05204 4 of 4 Oooguruk Well Plan Summary: Permit to Drill ODSK -33 — Kuparuk Production Well Surface Location: 2965' FSL, 1102' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469896.5 1 Y = 6031080.67 Target: 762.9' FSL, 4461.1' FEL, Sec 11, T13N, R7E, UM X = 466530.89 1 Y = 6028892.9 1 6,091' TVDrkb Bottom Hole Location: 1683.7' FSL, 1629.0' FEL, Sec 14, T13N, R7E, UM X = 469348.53 Y = 6024522.18 6,048' TVDrkb AFE Number: TBD Est. Start Date: January 20, 2008 Rig: Nabors 19AC Operating days: 4.1 days Drill Surface and Suspend 21.5 days Drill Intermediate, Production and Complete TD: 15156 MD / 6,048 TVDrkb Objective: Kuparuk 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Ultra -slim hole — Producer Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Well Control: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1230 psi @ 2750' TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 928 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Intermediate Section: • Maximum anticipated BHP: 3070 psi @ 6025' TVDss • Maximum surface pressure: 2408 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3070 psi @ 6025' TVDss • Maximum surface pressure: 2408 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Planned BOP test pressure: 3500 psi (annular to 2500 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 1 of 9 • • Diverter (see attached schematic): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9 -5/8" Surface Shoe Rathole + 20' to 50' from 9 -5/8" shoe LOT 12.0 ppg 7" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 13.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 12 -1/4" hole S ud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 — 15 unrestricted Final 9.2 -9.6 70 -100 25 — 35 15 — 25 10 — 15 <12 Intermediate Hole Mud Properties: 8 -3/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 8.8 -9.3 40 - 60 15 - 25 15 — 20 < 12 6 - 8 HRZ to TD 11.0 40 — 60 15 - 25 20 - 30 < 15 3 — 5 (8 -10 HTHP) Production Hole Mud Pro erties: 6 -1/8" hole Baradril -N Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 10.4 40 - 60 15 - 25 15 — 20 0 <4 Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44 Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44 Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 2 of 9 . . Hydraulics: Surface Hole: 12 -1/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf to BPRF 550 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 BPRF to TD 650 4" 15.7# 110 2400 10.2 N/A 18,18,18,16 .942 Intermediate Hole: 8 - 3 /4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf Shoe to TD 550 4" 15.7# 215 3500 11.0 N/A 6x14 0.902 Production Hole: 6 -1/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Int Shoe to TD 275 4" 15.7# 275 2800 11.57 N/A 3x14 0.451 Formation Markers: Formation Tops MD TVD (ss) Pore Press. EMW Comments (psi) (ppg) Base Permafrost 1669.8 1600 Top West Sak 2421.5 2309 1044 8.7 Base of fluvial sands Tuffaceous Shales 3109.8 2939 Hue Shale 5062.4 3970 Top Torok Sand 7230.8 4996 2260 8.7 Top of Disposal Zone Base Torok Sand 7577.9 5208 Base of Disposal Zone Top HRZ 8683.1 5785 Base HRZ 8993.5 5895 Top Kuparuk C 9705.9 6025 3070 9.8 Base Kuparuk C N/A 6085 Not penetrated Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 3 of 9 • Logging Program: 12 -1/4" Section: Drilling: Mud logging / Magnetic Ranging on the adjacent well Dir/GR Open Hole: N/A Cased Hole: N/A 8 -3/4" Section: Drilling: Mud logging Dir / GR / Res / Dens / Neut' Open Hole: N/A Cased Hole: N/A 6 -1/8" Section: Drilling: Mud logging Dir / GR / Res (Azm) / Dens (Azm) / Neut Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 101.5' Surface 157.7' / 157.7' 12 - 9 -5/8" 40# L -80 BTC 2838' Surface 2894' / 2806' 8 -3/4' 7" 26# L -80 BTC -M 9858' Surface 9914' / 6091' 6 -1/8" 4 -1/2 12.6# L -80 IBT -M 5392' 9764' / 6084' 15156' / 6048' Slotted Tubing 3 -1/2" 9.3# L -80 IBT -M 3444' Surface 3500' / 3303' Tubing 2 -7/8" 6.5# L -80 IBT -M 6264' 3500' / 3303 9764' / 6084' Casing Properties Size Weig Grade ID Drift ID Conn. Internal Collapse Tensile ht Yield (psi) Strength (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 9 -5/8" 40# L -80 8.835" 8.679" BTC 5750 3090 916 M 916 M 7" 26# L -80 6.276" 6.151" BTC -M 7240 5410 604 M 604 M 4-1/2" 12.6# L -80 3.958" 3.833" IBT -M n/a n/a 289 M 289 M Slotted Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 4 of 9 • • Cement Calculations: Casing Size: 1 9 -5/8" Surface Casing - single stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 2384' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 358 bbls / 484 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 43 bbls / 203 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 213 bbls Seawater Temp BHST -55° F, BHCT -60° F estimated 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. During drilling operations, should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar will be run in the casing string and a staged cement job will be performed, if needed. Casing Size: 1 7" Intermediate Casing - single stage ** Basis: Lead: 2183' of open hole with 30% excess Lead TOC: -6731' MD (500' MD above top of disposal interval) Tail: 1000' of open hole with 30% excess, plus 85' shoe track Tail TOC: -8914' MD (1000' above the shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Lead . 76 bbls / 181 sx of 12.5 ppg Premium "G" + adds. 2.36 cf /sk, 13.38 gps water req. Tail 38 bbls / 181 sx of 15.8 ppg Premium "G" + adds. 1.18 cf /sk, 5.18 gps water req. Temp BHST - 165° F at 6100' TVDrkb, -135° F BHCT * *This well is within 1/2 mile of the disposal well at the well path intersection with the disposal zone and will need the calculated top of the cement to be 500' MD above the top of the disposal interval. Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 5 of 9 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. The Oooguruk Drill Site Class 1 / Class 2 Disposal Well, ODSDW1 -44, has been drilled and commissioned for disposal. 3. Surface Slot 34 should have the surface casing set due to the need to have magnetic ranging tools run in it to reduce the risk for collision while drilling the surface hole of slot 33 Riq Activity: Batch Drill Surface Hole and Set Surface Casing 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up and function test the 21 -1/4" diverter system prior to spud. (Notify the AOGCC Field Inspectors 48 hours prior to diverter function test). 3. MU 12 -1/4" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point at -2894' MD / 2806' TVDrkb, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 9 -5/8 ", 40# surface casing - a Port Collar may be run based on hole conditions at Company Rep discretion. Displace the cement with seawater. 5. Ensure floats are holding. WOC if needed. 6. RIH with enough drill collars and HWDP to displace a volume equivalent to the pipe displacement of 2100' of 3 -1/2" tubing. Note: This is to remove the seawater from the upper part of the 9 -5/8" casing and allow for the installation of a 3 -1/2" or 2 -7/8" tubing circulation string. 7. ND Diverter and NU wellhead. 8. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. 9. Land the tubing and RILDS. Install TWC. 10. NU Tree and test. 11. Pull TWC. Circulate diesel freeze protection fluid to freeze protect the well to -2000' TVDrkb 12. Temporarily suspend the well. RDMO to slot 32 to drill the surface hole for that well. Note: With the conductors on 7' centers, the well will be temporarily suspended due to the need to batch drill the surface casing strings. Batch drilling of the surface casing strings will aid in avoiding a wellbore collision along with reducing the hazards associated with a wellbore collision, should one occur. Riq Activity: Drill and Complete Remaining Well 1. MIRU to ODSK -33. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree and NU BOPE. Test BOPE to 250/3500 psi. 3. Pull circulation tubing string from the well. 4. MU 8 -3/4" directional drilling, MWD /LWD assembly. RIH and cleanout the casing to landing collar. Displace the well over to intermediate hole drilling fluid. 5. Test the 9 -5/8" casing to 3,500 psi for 30 min. 6. Drill out shoe tract, cement, rat hole and 20' of new formation below 9 -5/8" shoe. Pull the bit back into the 9 -5/8" casing and perform LOT. 7. Drill 8 -3/4" intermediate hole to casing point at -9914' MD/ 6091' TVDrkb. Circulate and condition the drilling fluid to run casing. Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 6 of 9 • 8. Run and cement the 7 ", 26# intermediate casing. .9. MU 6 -1/8" directional drilling, MWD /LWD assembly. RIH and cleanout to landing collar. 10. Pressure test the 7" casing to 3,500 psi for 30 min. 11. Drill out shoe tract, cement, rat hole and 20' of new formation below 7" shoe. Pull the bit back into the 7" casing and perform an FIT. 12. Displace the well over to production hole drilling fluid. 13. Drill the 6 -1/8" production hole to TD at - 15156' MD/ 6048' TVDrkb. 14. Circulate and condition the hole to run liner. POH. 15. Run 4 -1/2" Slotted liner on 4" DP 16. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine. POH. 17. MU completion with ESP and RIH. 18. Land the tubing and RILDS. Install TWC. 19. ND BOPE, NU tree and test to 5,000 psi. 20. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 21. 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. 22. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 23. RD Slickline. RDMO to next well. Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 7 of 9 • • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test: • Calculate the required test pressure to reach leak off 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. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. • 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 Leak Off Test pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 8 of 9 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • A ConocoPhillips well drilled to the south of the Oooguruk development showed communication with the main body of the Kuparuk field. In that well, they took a 2 ppg kick over planned mud weight - to -12.5 ppg. Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outlined hightened awareness and kick detection o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation /Breathing /Formation Stability • Lost circulation is not expected, but if encountered, consult the Lost Circulation Decision Tree. • 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 welibore. • A formation study was conducted by GMI which indicated mud weights >12.5 ppg to maintain hole stability across the HRZ above the Kuparuk. Should shale instability be observed, pay close attention to the cuttings returned to surface and attempt to make small changes to mud weight to regain stability. o Splintered shales - indicates the mud weight may be too low o Tabular shales - indicates the mud weight may be too high Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Interval Maximum Influx Mud Exp Pore Min LOT / FIT Volume Weight Press 9 -5/8" Surface / 8 -3/4" hole 34 bbls 10.2 3070 12.0 ppg (LOT) 7" Intermediate / 6 -1/8" hole . Infinite 10.2 3070 13.5 ppg (FIT) NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults • No seismically visible faults are expected to be crossed although sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Fault Location MD TVDss Throw Direction Uncertainty N/A CONSULT THE ODS DATA SHEET AND WELL PLAN FOR ADDITIONAL INFORMATION Pioneer Natural Resources Last Revised: December 12, 2007 ODSK -33 Permit To Drill Page 9 of 9 ODSK -33 Proaction Well Proposed Smpletion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal I : Vent Valves Control Line 16" Conductor I I 158' MDrkb / 158' TVDrkb 3 -1/2 ", 9.3# L -80 IBT M ' ! 2 -7/8" ScSSSV, 2.313" ID @ —750' 4 2 -7/8" GLM @ 4216' MDrkb / 3718' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 2894' MDrkb / 2806' TVDrkb ■ X Nipple, 2.313" ID @ 4256' MD 7" x 2 -7/8" Packer @ -4296' MDrkb / —3750' TVDrkb X Nipple, 2.313" ID w RHC -M Profile @ 4336' MD 2 -7/8" GLM @ 8524' MDrkb / 5774' TVDrkb 2 -7/8 ", 6.5# L -80 IBT -M Estimated Top of Cement © 6731' MD / —4751' TVDss ESP Cable 0 0 U ! 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID © 8564' MDrkb XN Nipple, 2.205" ID Nogo @ 8604' MDrkb 65 degrees ESP @ 937' MDrkb 9914' MDrkb / 6091' TVDrkb 4 -1/2" Slotted Liner 7 ", 26# L -80 BTC -M, 6.276" ID 15156' MDrkb / 6048' TVDrkb Date: Revision By: Comments 12/12/2007 JDF /AJB Proposed Completion ODSK -33 Producer Well Schematic IONEER TURAL RESOURCES • • t PIONEER Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSK -33 - Slot ODS -33 ODSK -33 KupA Plan: ODSK -33 Kup A wp01 Standard Planning Report - Geographic 13 December, 2007 HALLIBURTON Drilling and Formation Evaluation WELL DETAILS; ODSK - REFERENCE INFORMATION H A L L I B U RTA N Co-ordinate (N/E) Reference: Well ODSK -33 - Slot ODS -33, True North Ground Level' 13.5 Vertical (TVD) Reference: 56' @ 56.0(1 +N/ -S +FJ Northing Fasting Latittude Longitude Slot Measured Depth Reference: 56' @ 56.0(1 Sperry Drilling Services 0.0 0.0 6031080.67 469896.50 70.496 - 150.246 ODS-33 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO- ORDINATES) CASING DETAILS Name TVD +N / -5 +E / -W Northing Easting Shape ND MD Name Size Project: Oooguruk Developement Geo Poly KupA 0.0 - 2110.9 - 3857.7 6028985.61 466030.67 Polygon 2806.0 2894.2 9 5/8" 9 -5/8 13.9 7" 7 Site: Oooguruk Drill Site 6048.3 KupA T7 - 6561.3 -521.5 6024522.17 469348.53 Point 6048.3 19 41/7" 4-1/2 Well: ODSK -33 6074.1 KupA T6 - 6035.8 -885.6 6025049.16 468986.60 Point 6091.4 KupA T1 - 2201.6 - 3357.1 6028892.89 466530.90 Point Wellbore: ODSK -33 KupA 6095.4 KupA T5 - 5292.9 - 1332.0 6025793.76 468543.25 Point Plan: ODSK -33 Kup A wp01 6110.3 KupA T2 - 2490.1 - 3051.9 6028603.21 466834.81 Point COMPANY DETAILS: WellPlanning - Pioneer - Oooguntk 6119.6 KupA T4 - 4348.7 - 1774.5 6026739.66 468104.55 Point 6124.6 KupA T3 - 3367.5 - 2296.5 6027722.80 467586.65 Point Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North D D I = 6.88 Error Surface: Elliptical Conic Warning Method: Rules Based Start Dir 1.00/100' 600.00' MD, 600.00' TVD 0- SECTION DETAILS - - - Start Dir 2.00/100' 1100.00' MD, 1099.40' ND - -' Sec MD Inc Azi ND +NI -S +E / -W DLeg TFace VSec Target - - 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 600 _--- _ Start Dir 3.00/100' 1350.00' MD, 1347.10' TVD 2 600.0 0.00 0.00 600.0 0.0 0.0 0.00 0.00 0.0 - - _ - - 3 1100.0 5.00 280.00 1099.4 3.8 -21.5 1.00 - 280.00 -15.4 - - - - .. " - - = End Dir 1663.50 MD, 1650.00' ND 4 1350.0 10.00 280.00 1347.1 9.5 -53.6 2.00 0.00 -38.5 - " - 5 1663.5 19.40 280.00 1650.0 23.2 -131.9 3.00 0.00 -94.7 1200 _ -- . - - - - 6 2670.7 19.40 280.00 2600.0 81.4 -461.4 0.00 0.00 -331.3 - _ - - S tart Di r 3 2670 MD, 2600.00' ND 7 2894.2 26.08 278.29 2806.0 94.9 -546.7 3.00 6.45 391.3 _ " - 8 2914.2 26.08 278.29 2824.0 96.2 -555.4 0.00 0.00 -397.3 - 15 - - - - - - - - 9 4344.8 68.94 274.88 3768.1 203.4 - 1580.0 3.00 -4.67 - 1072.9 End Dir 2894.20' MD, 2806.00' ND 10 5729.1 68.94 274.88 4265.6 313.4 - 2867.2 0.00 0.00 - 1901.3 1800 - 11 9713.9 87.12 128.29 6081.4 - 2077.9 - 3513.8 3.50 - 122.22 -313.4 - - ' - 12 9913.9 87.12 128.29 6091.4 - 2201.6 - 3357.1 0.00 0.00 -122.1 KupA T1 - - -' - - - ._ Start Dir 3.00/100' 2914.20' MD, 2824.00' ND 13 10167.7 87.22 135.91 6104.0 - 2371.4 -3169.1 3.00 89.44 124.8 - _ - ' - ' _ _ _ - - - 14 10240.0 87.22 135.91 6107.5 - 2423.2 - 3118.9 0.00 0.00 196.1 2400 _ - - " - - 15 10334.6 89.33 134.00 6110.3 - 2490.1 - 3051.9 3.00 -42.21 289.2 KupA T2 9 5/8" - - ' _ - 16 10477.4 89.18 138.28 6112.2 - 2593.0 - 2953.1 3.00 92.06 430.2 0 - - - _ _ - - - End Dir 434 MD, 3768.10 TVD 17 11181.7 89.18 138.28 6122.3 - 3118.6 - 2484.4 0.00 0.00 1129.6 Lc) - - 18 11493.9 90.00 147.61 6124.6 - 3367.5 - 2296.5 3.00 85.00 1441.3 KupA T3 19 11646.5 90.22 152.18 6124.3 - 3499.5 - 2220.0 3.00 87.24 1593.3 a Start Dir 3.5/100 • 3000- 3p" 5729.10' MD, 4265.60' ND 20 12508.1 90.22 152.18 6121.0 - 4261.5 - 1817.9 0.00 0.00 2448.1 a - - - 21 12605.5 91.33 154.89 6119.6 -4348.7 - 1774.5 3.00 67.65 2544.4 KupA T4 ' - - - 22 12628.8 91.32 155.59 6119.1 - 4369.9 - 1764.8 3.00 90.81 2567.4 End Dir 10477.40' MD, 6112.20' ND 23 13429.3 91.32 155.59 6100.7 - 5098.6 - 1434.0 0.00 0.00 3354.0 O 3600- , S Q°' - - - - 24 13648.9 91.41 149.00 6095.4 - 5292.9 - 1332.0 3.00 -89.17 3571.7 KupA T5 ti 25 13660.1 91.33 149.32 6095.2 - 5302.4 - 1326.3 3.00 103.86 3582.8 � S , - - ' " St Dir 3.00/100 11181.70' MD, 6122.30' TVD 26 14377.6 91.33 149.32 6078.5 - 5919.4 -960.3 0.00 0.00 4298.1 N _ - .' 27 14516.0 92.32 145.29 6074.1 - 6035.8 -885.6 3.00 -76.13 4436.3 KupA T6 • 4200 - - - End Dir 11646.50' MD, 6124.30' ND 28 15155.9 92.32 145.29 6048.3 - 6561.3 -521.5 0.00 0.00 5075.6 KupA T7 m End Dir 9713.90' MD, 6081.40' ND 2 Start Dir 3.00/100' 9913.90' MD, 6091.40' ND' Start Dir 3.00/100' 12508.10' MD, 6121.00' ND Start Dir 3.00/100' 13429.30' MD, 6100.70' ND - 4800- 55° -- - = 4800 End Dir 10167.70' MD, 6104.06' ND - - - End Dir 13660.10' MD, 6095.20' ND _ End Dir 1262 MD, 6119.10' ND, - - - 5400- o Start Dir 3.00/100' 10240.00'lhlD, 6107,56 ND,' Start Dir 3.00/100' 14377.60' MD, 6078.50' ND -5400 -' _ - - End Dir 14516.00' MD, 6074.10' ND 6000- ' ' ' . - - - - -- _- _ 6000 - / Total Depth at 15155.90' MD, 6048.30' TVD - 7 i 1 41/2" -6600 6600- KupA T11 KupA T3 ' KupA T5 / KupA T7 ODSK - 33 Kup A w p 0 1 _ - - KupA T2 KupA T KupA T6 _ 7200- _ 7200 - I I I I I l l l l I l l l I I l l l l I l l l i I i l I I I i l l l I l l l i i I I l l I l l l l I l l T,` i i I I I I I I r I l l l I 1 I l I I l l l I I l I l l I l l l l I l l l l I I I l l I l l l l I l l - - I [Imp I I I -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 Vertical Section at 145.O0bearing (1500 ft/in) !✓" -`, WELL DETAILS: ODSK -33 REFERENCE INFORMATION .+' , t rt" l ' ; Co-ordinate (N/E) Reference: Well ODSK -33 - Slot ODS -33, True North {tt� H AL L I B U R TO N Ground Level: 13.5 o Vertical (TVD) Reference: 56 @ 56 05 , +N / -S +E/-W Northing Fasting Latittude Longitude Slot Measured Depth Reference: 56 @ 56.05 Sperry Drilling Services 0.0 0.0 6031080.67 469896.50 70.496 - 150 ODS -33 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO-ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name ND +N / -S +E / -W Northing Easting Shape Calculation Method: Minimum Curvature Oooguruk Geo Poly KupA 0.0 - 2110.9 - 3857.7 6028985.61 466030.67 Polygon Project: g Developement uruk Develo ement Error System: ISCWSA KupA 6048.3 -6561.3 -521.5 6024522.17 469348.53 Point Scan Method: Tray. Cylinder North Site: Oooguruk Drill Site KupA T6 6074.1 - 6035.8 -885.6 6025049.16 468986.60 Point Error Surface: Elliptical Conic Well: ODSK -33 KupA T1 6091.4 - 2201.6 -3357.1 6028892.89 466530.90 Point Warning Method: Rules Based KupA T5 6095.4 - 5292.9 - 1332.0 6025793.76 468543.25 Point Wellbore: ODSK -33 KupA KupA T2 6110.3 - 2490.1 - 3051.9 6028603.21 466834.81 Point Plan: ODSK -33 Ku A W O1 KupA T4 6119.6 - 4348.7 - 1774.5 6026739.66 468104.55 Point p p KupA T3 6124.6 - 3367.5 - 2296.5 6027722.80 467586.65 Point CASING DETAILS C ND MD Name Size � � � =6 . � � 6091.4 9913.9 9 5/ 7' 7 -5/8 - 6048.3 15155.9 4 1/2" 4 -1/2 600- S o 95/8" SECTION DETAILS _ 0 i �� Start Dir 1.00 /100' 600.00' MD, 600.00' TVD Sec MD Inc Azi ND +N / -S +E/ -W DLeg TFace VSec Target _ ` o0 Start Dir 3.5/100' 5729.10' MD, 4265.60' TVD j , / _ _ 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 - Start Di�2.00 /100' 1 100.00' MD, 1099.40' TVD 2 600.0 0.00 0.00 600.0 0.0 0.0 0.00 0.00 0.0 End Dir 4344.80' MD, 3768.10' TVD 3 1100.0 5.00 280.00 1099.4 3.8 -21.5 1.00 280.00 -15.4 -600- ' � Start`Dir 3.00 /100' 1350.00'MD, 1347.10' TVD 4 1350.0 10.00 280.00 1347.1 9.5 -53.6 2.00 0.00 -38.5 _ Start Dir 3.00/100' 2914.20' MD, 2824.00' TVD 5 1663.5 19.40 280.00 1650.0 23.2 -131.9 3.00 0.00 -94.7 / End 1ji5 1663.50' MD, 1650.00' TVD 6 2670.7 19.40 280.00 2600.0 81.4 -461.4 0.00 0.00 -331.3 End Dir 2894.20' MD, 2806.00' TVD • 7 2894.2 26.08 278.29 2806.0 94.9 -546.7 3.00 -6.45 -391.3 -1200- s 8 2914.2 26.08 278.29 2824.0 96.2 -555.4 0.00 0.00 -397.3 End Dir 9713.90' MD, 6081.40' TVD Start Dir 3.00/100' 2670.70' MD, 2600.00' TVD 9 4344.8 68.94 274.88 3768.1 203.4 - 1580.0 3.00 -4.67 - 1072.9 - 10 5729.1 68.94 274.88 4265.6 313.4 - 2867.2 0.00 0.00 - 1901.3 11 9713.9 87.12 128.29 6081.4 - 2077.9 - 3513.8 3.50 - 122.22 -313.4 -1800- - Geo • Start Dir 3.00/100' 9913.90' MD, 6091.40' TVD 12 9913.9 87.12 128.29 6091.4 - 2201.6 - 3357.1 0.00 0.00 -122.1 KupA T1 Poly 1Q ! _ - - 13 10167.7 87.22 135.91 6104.0 - 2371.4 - 3169.1 3.00 89.44 124.8 i - ' 14 10240.0 87.22 135.91 6107.5 - 2423.2 - 3118.9 0.00 0.00 196.1 _ ='k,- _ _�-•: End Dir 10167.70' MD, 6104.00' TVD 15 10334.6 89.33 134.00 6110.3 - 2490.1 - 3051.9 3.00 -42.21 289.2 KupA T2 ' - 16 10477.4 89.18 138.28 6112.2 - 2593.0 - 2953.1 3.00 92.06 430.2 O -2400- IKupATI N•N I i' - '\ • - 17 11181.7 89.18 138.28 6122.3 - 3118.6 - 2484.4 0.00 0.00 1129.6 'N - - Start Dir 3.00/100' 10240.00' MD, 6107.50' TVD '" o� - `N � -_.� -- 18 11493.9 90.00 147.61 6124.6 - 3367.5 - 2296.5 3.00 85.00 1441.3 KupA T3 \ N 19 11646.5 90.22 152.18 6124.3 - 3499.5 - 2220.0 3.00 87.24 1593.3 ' N N End Dir 10477.40' MD, 6112.20' TVD 20 12508.1 90.22 152.18 6121.0 4261.5 - 1817.9 0.00 0.00 2448.1 .+., -3000- I KupA T2 N•N N 21 12605.5 91.33 154.89 6119.6 - 4348.7 - 1774.5 3.00 67.65 2544.4 KupA T4 N - -' _ _ _ 22 12628.8 91.32 155.59 6119.1 - 4369.9 - 1764.8 3.00 90.81 2567.4 N, 1 \'N Start Dir 3.00/100' 1 1 181.70' MD, 6122.30' TVD 23 13429.3 91.32 155.59 6100.7 - 5098.6 - 1434.0 0.00 0.00 3354.0 `- 24 13648.9 91.41 149.00 6095.4 - 5292.9 - 1332.0 3.00 -89.17 3571.7 KupA T5 -3600- I 25 13660.1 91.33 149.32 6095.2 - 5302.4 -1326.3 3.00 103.86 3582.8 - I KupA T3' N\ - _ , \ - _ _ _ - - End Dir 11646.50' MD, 6124.30' TVD \ 26 14377.6 91.33 149.32 6078.5 -5919.4 -960.3 0.00 0.00 4298.1 \ 27 14516.0 92.32 145.29 6074.1 1 -6035.8 -885.6 3.00 -76.13 4436.3 KupA T6 \ •\ 28 15155.9 92.32 145.29 6048.3 - 6561.3 -521.5 0.00 0.00 5075.6 KupA T7 N - \ '\ Start Dir 3.00 /100' 12508.10' MD, 6121.00' TVD -4200- _ , ---- - - ` - V End Dir 12628.80' MD, 6119.10' TVD - _ IKupATi 1, \ _ ,\ -4800- , 1 \•\ Start Dir 3.00/100' 13429.30' MD, 6100.70' TVD - -4800 1 1- - - \ r ' _ - . End Dir 13660.10' MD, 6095.20' TVD _ - -5400 j ,.... -- =\-- -5400- IKupATi" \ 1 •\ _ •\ •\ Start Dir 3.00 /100' 14377.60' MD, 6078.50' TVD -6000- KKupA Tfl- - _\ �\ _ _ _ _ -- End Dir 14516.00' MD, 6074.10' TVD --6000 _ '\ I \ 1 KupA - \ 4 1/2" - -6600- _ _ - '\- i• ' - -� - - - Total Depth at 15155.90' MD, 6048.30' TVD - -6600 ODSK -33 Kup A wp01 \ 1 i i i i i i i i i I l i I i i l i i l i l i i l i i l i l l l l i l i i l i (r i i l i l i i l i i r l i l l l r l l l r t l l i i i l i - r 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 l i i l i l l i l i i l i l i 1 1 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 . West( - )/East( +) (1500 ft/in) 411, 110 Halliburton Company HALLIBURTON Planning Report - Geographic Drilling and Formation PJQNLE8 Evaluation Database:. ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Welibore: ODSK -33 KupA . Design: ODSK -33 Kup A wp01 Project Oooguruk Developement Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70.496 From: Map Easting: 469,920.45ft Longitude: - 150.246 Position Uncertainty: 0.0 ft Slot Radius: " Grid Convergence: -0.23 ? Well ODSK -33 - Slot ODS -33 Well Position +N /S 0.0 ft Northing: 6,031,080.67 ft Latitude: 70.496 +E / -W 0.0 ft Easting: 469,896.50 ft Longitude: - 150.246 Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSK -33 KupA Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 2/14/2007 23.26 80.81 57,641 Design ODSK -33 Kup A wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 0.0 Vertical Section: Depth From (TVD) +WS +E/-W Direction (ft) (ft) (ft) (bearing) 0.0 0.0 0.0 145.00 12/13/2007 11:53:23AM Page 2 COMPASS 2003.16 Build 42B Halliburton Company HattIBtJRTON Planning Report - Geographic °ruling and Formation PiONIF.8 Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Welibore: ODSK -33 KupA . • Design: ODSK -33 Kup A wp01 Plan Sections Measured Vertical Dogleg Build Turn Depth inclination Azimuth Depth +N/-S +E/ -W Rate Rate Rate TFO (ft) ( ?) (bearing) (ft) (ft) (ft) (7/100ft) ( ? /100ft) (7/100ft) ( ?) Target 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.00 0.00 600.0 0.00 0.00 600.0 0.0 0.0 0.00 0.00 0.00 0.00 1,100.0 5.00 280.00 1,099.4 3.8 -21.5 1.00 1.00 0.00 280.00 1,350.0 10.00 280.00 1,347.1 9.5 -53.6 2.00 2.00 0.00 0.00 1,663.5 19.40 280.00 1,650.0 23.2 -131.9 3.00 3.00 0.00 0.00 2,670.7 19.40 280.00 2,600.0 81.4 -461.4 0.00 0.00 0.00 0.00 2,894.2 26.08 278.29 2,806.0 94.9 -546.7 3.00 2.99 -0.77 -6.45 2,914.2 26.08 278.29 2,824.0 96.2 -555.4 0.00 0.00 0.00 0.00 4,344.8 68.94 274.88 3,768.1 203.4 - 1,580.0 3.00 3.00 -0.24 -4.67 5,729.1 68.94 274.88 4,265.6 313.4 - 2,867.2 0.00 0.00 0.00 0.00 9,713.9 87.12 128.29 6,081.4 - 2,077.9 - 3,513.8 3.50 0.46 -3.68 - 122.22 9,913.9 87.12 128.29 6,091.4 - 2,201.6 - 3,357.1 0.00 0.00 0.00 0.00 KupA T1 10,167.7 87.22 135.91 6,104.0 - 2,371.4 - 3,169.1 3.00 0.04 3.00 89.44 10,240.0 87.22 135.91 6,107.5 - 2,423.2 - 3,118.9 0.00 0.00 0.00 0.00 10,334.6 89.33 134.00 6,110.3 - 2,490.1 - 3,051.9 3.00 2.22 -2.02 -42.21 KupA T2 10,477.4 89.18 138.28 6,112.2 - 2,593.0 - 2,953.1 3.00 -0.11 3.00 92.06 11,181.7 89.18 138.28 6,122.3 - 3,118.6 - 2,484.4 0.00 0.00 0.00 0.00 11,493.9 90.00 147.61 6,124.6 - 3,367.5 - 2,296.5 3.00 0.26 2.99 85.00 KupA T3 11,646.5 90.22 152.18 6,124.3 - 3,499.5 - 2,220.0 3.00 0.14 3.00 87.24 12,508.1 90.22 152.18 6,121.0 - 4,261.5 - 1,817.9 0.00 0.00 0.00 0.00 12,605.5 91.33 154.89 6,119.6 - 4,348.7 - 1,774.5 3.00 1.14 2.78 67.65 KupA T4 12,628.8 91.32 155.59 6,119.1 - 4,369.9 - 1,764.8 3.00 -0.04 3.00 90.81 13,429.3 91.32 155.59 6,100.7 - 5,098.6 - 1,434.0 0.00 0.00 0.00 0.00 13,648.9 91.41 149.00 6,095.4 - 5,292.9 - 1,332.0 3.00 0.04 -3.00 -89.17 KupA T5 13,660.1 91.33 149.32 6,095.2 - 5,302.4 - 1,326.3 3.00 -0.72 2.91 103.86 14,377.6 91.33 149.32 6,078.5 - 5,919.4 -960.3 0.00 0.00 0.00 0.00 14,516.0 92.32 145.29 6,074.1 - 6,035.8 -885.6 3.00 0.72 -2.91 -76.13 KupA T6 15,155.9 92.32 145.29 6,048.3 - 6,561.3 -521.5 0.00 0.00 0.00 0.00 KupA T7 • 12/13/2007 11:53:23AM Page 3 COMPASS 2003.16 Build 428 • Halliburton Company Report - Geographic Driving and Formation WNW Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site; Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Welibore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth ' +N /-S +E/ -W Northing Easting (ft) (7) (bearing) (ft) (ft) (ft) (ft) (ft) Latitude Longitude I 0.0 0.00 0.00 0.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 100.0 0.00 0.00 100.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 200.0 0.00 0.00 200.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 300.0 0.00 0.00 300.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 400.0 0.00 0.00 400.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 500.0 0.00 0.00 500.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 600.0 0.00 0.00 600.0 0.0 0.0 6,031,080.67 469,896.50 70.496 - 150.246 Start Dir 1.00/100' 600.00' MD, 600.00' TVD 700.0 1.00 280.00 700.0 0.2 -0.9 6,031,080.83 469,895.64 70.496 - 150.246 800.0 2.00 280.00 800.0 0.6 -3.4 6,031,081.29 469,893.07 70.496 - 150.246 900.0 3.00 280.00 899.9 1.4 -7.7 6,031,082.06 469,888.77 70.496 - 150.246 1,000.0 4.00 280.00 999.7 2.4 -13.7 6,031,083.15 469,882.77 70.496 - 150.246 1,100.0 5.00 280.00 1,099.4 3.8 -21.5 6,031,084.54 469,875.05 70.496 - 150.246 Start Dir 2.00/100' 1100.00' MD, 1099.40' TVD 1,200.0 7.00 280.00 1,198.8 5.6 -31.8 6,031,086.40 469,864.76 70.496 - 150.246 1,300.0 9.00 280.00 1,297.8 8.0 -45.5 6,031,088.87 469,851.07 70.496 - 150.247 1,350.0 10.00 280.00 1,347.1 9.5 -53.6 6,031,090.34 469,842.95 70.496 - 150.247 Start Dir 3.00/100' 1350.00' MD, 1347.10' TVD 1,400.0 11.50 280.00 1,396.3 11.1 -62.8 6,031,091.99 469,833.77 70.496 - 150.247 1,500.0 14.50 280.00 . 1,493.7 15.0 -84.9 6,031,095.99 469,811.64 70.496 - 150.247 1,600.0 17.50 280.00 1,589.8 19.8 ' -112.1 6,031,100.88 469,784.52 70.496 - 150.247 1,663.5 19.40 280.00 1,650.0 23.2 -131.9 6,031,104.45 469,764.76 70.496 - 150.247 End Dir 1663.50' MD, 1650.00' TVD 1,700.0 19.40 280.00 1,684.5 25.4 -143.8 6,031,106.61 469,752.81 70.496 - 150.247 1,800.0 19.40 280.00 1,778.8 31.1 -176.5 6,031,112.51 469,720.12 70.496 - 150.248 1,900.0 19.40 280.00 1,873.1 36.9 -209.2 6,031,118.41 469,687.43 70.496 - 150.248 2,000.0 19.40 280.00 1,967.4 42.7 -242.0 6,031,124.31 469,654.74 70.496 - 150.248 2,100.0 19.40 280.00 2,061.8 48.4 -274.7 6,031,130.21 469,622.05 70.496 - 150.248 2,200.0 19.40 280.00 2,156.1 54.2 -307.4 6,031,136.11 469,589.36 70.496 - 150.249 2,300.0 19.40 280.00 2,250.4 60.0 -340.1 6,031,142.01 469,556.67 70.496 - 150.249 2,400.0 19.40 280.00 2,344.7 65.7 -372.8 6,031,147.91 469,523.98 70.496 - 150.249 2,500.0 19.40 280.00 2,439.0 71.5 -405.5 6,031,153.81 469,491.29 70.496 - 150.249 2,600.0 19.40 280.00 2,533.4 77.3 -438.3 6,031,159.71 469,458.60 70.496 - 150.250 2,670.7 19.40 280.00 2,600.0 81.4 -461.4 6,031,163.88 469,435.50 70.496 - 150.250 Start Dir 3.00/100' 2670.70' MD, 2600.00' TVD 2,700.0 20.28 279.71 2,627.6 83.1 -471.2 6,031,165.63 469,425.69 70.496 - 150.250 2,800.0 23.27 278.90 2,720.5 89.0 -507.8 6,031,171.75 469,389.12 70.496 - 150.250 2,894.2 26.08 278.29 2,806.0 94.9 -546.7 6,031,177.77 469,350.29 70.496 - 150.251 End Dir 2894.20' MD, 2806.00' TVD - 9 5/8" 2,900.0 26.08 278.29 2,811.3 95.3 -549.2 6,031,178.15 469,347.75 70.496 - 150.251 2,914.2 26.08 278.29 2,824.0 96.2 -555.4 6,031,179.08 469,341.60 70.496 - 150.251 Start Dir 3.00/100' 2914.20' MD, 2824.00' TVD 3,000.0 28.65 277.85 2,900.2 101.7 -594.4 6,031,184.77 469,302.56 70.496 - 150.251 3,100.0 31.64 277.43 2,986.7 108.4 -644.2 6,031,191.63 469,252.82 70.496 - 150.251 3,200.0 34.63 277.07 3,070.4 115.3 -698.4 6,031,198.74 469,198.64 70.496 - 150.252 3,300.0 37.63 276.76 3,151.2 122.3 -756.9 6,031,206.06 469,140.14 70.496 - 150.252 3,400.0 40.62 276.49 3,228.7 129.6 -819.6 6,031,213.59 469,077.50 70.496 - 150.253 3,500.0 43.62 276.25 3,302.9 137.0 -886.3 6,031,221.29 469,010.89 70.496 - 150.253 3,600.0 46.61 276.03 3,373.4 144.6 -956.7 6,031,229.15 468,940.49 70.496 - 150.254 3,700.0 49.61 275.84 3,440.2 152.3 - 1,030.7 6,031,237.14 468,866.49 70.496 - 150.255 3,800.0 52.61 275.66 3,503.0 160.1 - 1,108.2 6,031,245.25 468,789.10 70.496 - 150.255 3,900.0 55.61 275.50 3,561.6 168.0 - 1,188.8 6,031,253.45 468,708.52 70.496 - 150.256 4,000.0 58.60 275.35 3,615.9 175.9 - 1,272.4 6,031,261.72 468,624.98 70.496 - 150.257 12/13/2007 11 :53 :23AM Page 4 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Planning Report - Geographic Drilling and Formation t'14NEER Evaluation Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth +N /-S +E./ -W Northing Easting (ft) (7) (bearing) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 4,100.0 61.60 275.20 3,665.7 183.9 - 1,358.7 6,031,270.03 468,538.71 70.496 - 150.257 4,200.0 64.60 275.07 3,711.0 191.9 - 1,447.5 6,031,278.37 468,449.94 70.497 - 150.258 4,300.0 67.60 274.94 3,751.5 199.8 - 1,538.6 6,031,286.71 468,358.92 70.497 - 150.259 4,344.8 68.94 274.88 3,768.1 203.4 - 1,580.0 6,031,290.44 468,317.50 70.497 - 150.259 End Dir 4344.80' MD, 3768.10' TVD 4,400.0 68.94 274.88 3,787.9 207.8 - 1,631.3 6,031,295.04 468,266.17 70.497 - 150.259 4,500.0 68.94 274.88 3,823.9 215.7 - 1,724.3 6,031,303.35 468,173.23 70.497 - 150.260 4,600.0 68.94 274.88 3,859.8 223.7 - 1,817.3 6,031,311.67 468,080.30 70.497 - 150.261 4,700.0 68.94 274.88 3,895.7 231.6 - 1,910.3 6,031,319.99 467,987.36 70.497 - 150.262 4,800.0 68.94 274.88 3,931.7 239.6 - 2,003.3 6,031,328.31 467,894.42 70.497 - 150.263 4,900.0 68.94 274.88 3,967.6 247.5 - 2,096.2 6,031,336.63 467,801.48 70.497 - 150.263 5,000.0 68.94 274.88 4,003.6 255.4 - 2,189.2 6,031,344.95 467,708.54 70.497 - 150.264 5,100.0 68.94 274.88 4,039.5 263.4 - 2,282.2 6,031,353.27 467,615.61 70.497 - 150.265 5,200.0 68.94 274.88 4,075.4 271.3 - 2,375.2 6,031,361.59 467,522.67 70.497 - 150.266 5,300.0 68.94 274.88 4,111.4 279.3 - 2,468.2 6,031,369.91 467,429.73 70.497 - 150.266 5,400.0 68.94 274.88 4,147.3 287.2 - 2,561.1 6,031,378.23 467,336.79 70.497 - 150.267 5,500.0 68.94 274.88 4,183.3 295.2 - 2,654.1 6,031,386.55 467,243.86 70.497 - 150.268 5,600.0 68.94 274.88 4,219.2 303.1 - 2,747.1 6,031,394.87 467,150.92 70.497 - 150.269 5,700.0 68.94 274.88 4,255.1 311.1 - 2,840.1 6,031,403.19 467,057.98 70.497 - 150.269 5,729.1 68.94 274.88 4,265.6 313.4 - 2,867.2 6,031,405.62 467,030.89 70.497 - 150.270 Start Dir 3.5/100' 5729.10' MD, 4265.60' TVD 5,800.0 67.63 272.61 4,291.8 317.7 - 2,932.9 6,031,410.19 466,965.24 70.497 - 150.270 5,900.0 65.84 269.34 4,331.3 , 319.3 - 3,024.7 6,031,412.15 466,873.42 70.497 - 150.271 6,000.0 64.12 265.97 4,373.6 315.6 - 3,115.2 6,031,408.83 466,782.89 70.497 - 150.272 6,100.0 62.49 262.51 4,418.6 306.6 - 3,204.1 6,031,400.25 466,694.00 70.497 - 150.272 6,200.0 60.94 258.95 4,466.0 292.5 - 3,291.0 6,031,386.44 466,607.06 70.497 - 150.273 6,300.0 59.49 255.28 4,515.7 273.1 - 3,375.6 6,031,367.45 466,522.41 70.497 - 150.274 6,400.0 58.14 251.50 , 4,567.4 248.7 - 3,457.5 6,031,343.36 466,440.36 70.497 - 150.274 6,500.0 56.91 247.62 4,621.2 219.3 - 3,536.6 6,031,314.25 466,361.22 70.497 - 150.275 6,600.0 55.80 243.63 4,676.6 184.9 - 3,612.4 6,031,280.23 466,285.28 70.496 - 150.276 6,700.0 54.82 239.54 4,733.5 145.8 - 3,684.7 6,031,241.42 466,212.83 70.496 - 150.276 6,800.0 53.99 235.36 4,791.7 102.1 - 3,753.2 6,031,197.98 466,144.13 70.496 - 150.277 6,900.0 53.30 231.10 4,851.0 53.9 - 3,817.7 6,031,150.07 466,079.45 70.496 - 150.277 7,000.0 52.77 226.77 4,911.2 1.5 - 3,877.9 6,031,097.86 466,019.02 70.496 - 150.278 7,100.0 52.40 222.39 4,971.9 -55.1 - 3,933.6 6,031,041.54 465,963.07 70.496 - 150.278 7,200.0 52.19 217.97 5,033.1 -115.5 - 3,984.7 6,030,981.34 465,911.81 70.496 - 150.279 7,300.0 52.14 213.54 5,094.5 -179.5 - 4,030.8 6,030,917.47 465,865.43 70.495 - 150.279 7,400.0 52.27 209.11 5,155.8 -247.0 - 4,071.8 6,030,850.16 465,824.10 70.495 - 150.279 7,500.0 52.55 204.71 5,216.8 -317.7 - 4,107.7 6,030,779.69 465,787.97 70.495 - 150.280 7,600.0 53.00 200.35 5,277.3 -391.2 - 4,138.2 6,030,706.29 465,757.19 70.495 - 150.280 7,700.0 53.61 196.05 5,337.1 - 467.3 - 4,163.2 6,030,630.26 465,731.87 70.495 - 150.280 7,800.0 54.36 191.82 5,395.9 -545.8 - 4,182.7 6,030,551.87 465,712.09 70.494 - 150.280 7,900.0 55.27 ' 187.69 5,453.5 -626.3 - 4,196.5 6,030,471.41 465,697.94 70.494 - 150.280 8,000.0 56.30 183.64 5,509.8 -708.6 - 4,204.6 6,030,389.19 465,689.46 70.494 - 150.281 8,100.0 57.47 179.70 5,564.4 -792.3 - 4,207.1 6,030,305.51 465,686.70 70.494 - 150.281 8,200.0 58.76 175.87 5,617.3 -877.1 - 4,203.8 6,030,220.69 465,689.65 70.494 - 150.281 8,300.0 60.16 172.14 5,668.1 -962.7 - 4,194.7 6,030,135.03 465,698.31 70.493 - 150.280 8,400.0 61.65 168.52 5,716.7 - 1,048.8 - 4,180.1 6,030,048.87 465,712.65 70.493 - 150.280 8,500.0 63.25 165.01 5,763.0 - 1,135.1 - 4,159.7 6,029,962.52 465,732.61 70.493 - 150.280 8,600.0 64.92 161.59 5,806.7 - 1,221.2 - 4,133.9 6,029,876.30 465,758.12 70.493 - 150.280 8,700.0 66.67 158.27 5,847.7 - 1,306.9 - 4,102.6 6,029,790.54 465,789.08 70.492 - 150.280 8,800.0 68.49 155.04 5,885.9 - 1,391.7 - 4,065.9 6,029,705.55 465,825.38 70.492 - 150.279 8,900.0 70.37 151.88 5,921.0 - 1,475.5 - 4,024.1 6,029,621.65 465,866.87 70.492 - 150.279 9,000.0 72.31 148.80 5,953.0 - 1,557.8 - 3,977.2 6,029,539.16 465,913.42 70.492 - 150.279 12/13/2007 11:53:23AM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLIBUR1ON ,, , Planning Report - Geographic Drilling and Formation 1101,4EER Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature WeUbore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 . Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +1 +E/ -W Northing Easting (ft) ( ?) (bearing) (R) (ft) (ft) (ft) (ft) Latitude Longitude 9,100.0 74.29 145.79 5,981.7 - 1,638.4 - 3,925.5 6,029,458.38 465,964.84 70.492 - 150.278 9,200.0 76.31 142.84 6,007.1 - 1,716.9 - 3,869.0 6,029,379.62 466,020.94 70.491 - 150.278 9,300.0 78.37 139.93 6,029.0 - 1,793.1 - 3,808.1 6,029,303.16 466,081.51 70.491 - 150.277 9,400.0 80.45 137.07 6,047.4 - 1,866.7 - 3,743.0 6,029,229.30 466,146.33 70.491 • - 150.277 9,500.0 82.56 134.25 6,062.2 - 1,937.5 - 3,673.9 6,029,158.31 466,215.15 70.491 - 150.276 9,600.0 84.69 131.45 6,073.3 - 2,005.0 - 3,601.0 6,029,090.45 466,287.72 70.491 - 150.276 9,700.0 86.82 128.67 6,080.7 - 2,069.2 - 3,524.7 6,029,025.97 466,363.77 70.490 - 150.275 9,713.9 87.12 128.29 6,081.4 - 2,077.9 - 3,513.8 6,029,017.27 466,374.63 70.490 - 150.275 End Dir 9713.90' MD, 6081.40' TVD 9,800.0 87.12 128.29 6,085.7 - 2,131.1 - 3,446.4 6,028,963.75 466,441.88 70.490 - 150.274 9,900.0 87.12 128.29 6,090.8 - 2,193.0 - 3,368.0 6,028,901.56 466,520.01 70.490 - 150.274 9,913.9 87.12 128.29 6,091.4 - 2,201.6 - 3,357.1 6,028,892.89 466,530.90 70.490 - 150.274 Start Dir 3.00/100' 9913.90' MD, 6091.40' TVD - 7" - KupA T1 10,000.0 87.15 130.87 6,095.7 - 2,256.4 - 3,290.8 6,028,837.87 466,596.92 70.490 - 150.273 10,100.0 87.19 133.87 6,100.7 - 2,323.7 - 3,217.0 6,028,770.27 466,670.42 70.490 - 150.272 10,167.7 87.22 135.91 6,104.0 - 2,371.4 - 3,169.1 6,028,722.35 466,718.13 70.490 - 150.272 End Dir 10167.70' MD, 6104.00' TVD 10,200.0 87.22 135.91 6,105.5 - 2,394.6 - 3,146.7 6,028,699.10 466,740.47 70.489 - 150.272 10,240.0 87.22 135.91 6,107.5 - 2,423.2 - 3,118.9 6,028,670.32 466,768.14 70.489 - 150.272 Start Dir 3.00/100' 10240.00' MD, 6107.50' TVD 10,300.0 88.56 134.70 6,109.7 - 2,465.9 - 3,076.7 6,028,627.51 466,810.15 70.489 - 150.271 10,334.6 89.33 134.00 6,110.3 - 2,490.1 - 3,051.9 6,028,603.21 466,834.81 70.489 - 150.271 KupA T2 10,400.0 89.26 135.96 6,111.1 - 2,536.3 - 3,005.7 6,028,556.83 466,880.85 70.489 - 150.271 10,477.4 89.18 138.28 6,112.2 - 2,593.0 - 2,953.0 6,028,499.91 466,933.27 70.489 - 150.270 End Dir 10477.40' MD, 6112.20' TVD 10,500.0 89.18 138.28 6,112.5 - 2,609.9 - 2,938.0 6,028,482.99 466,948.24 70.489 - 150.270 10,600.0 89.18 138.28 6,114.0 - 2,684.5 - 2,871.5 6,028,408.09 467,014.48 70.489 - 150.270 10,700.0 89.18 138.28 6,115.4 - 2,759.1 - 2,804.9 6,028,333.20 467,080.71 70.488 - 150.269 10,800.0 89.18 138.28 6,116.8 - 2,833.8 - 2,738.4 6,028,258.30 467,146.94 70.488 - 150.269 10,900.0 89.18 138.28 6,118.3 - 2,908.4 - 2,671.8 6,028,183.41 467,213.17 70.488 - 150.268 11,000.0 89.18 138.28 6,119.7 - 2,983.0 - 2,605.3 6,028,108.52 467,279.41 70.488 - 150.267 11,100.0 89.18 138.28 6,121.1 - 3,057.7 - 2,538.8 6,028,033.62 467,345.64 70.488 - 150.267 11,181.7 89.18 138.28 6,122.3 - 3,118.6 - 2,484.4 6,027,972.43 467,399.75 70.487 - 150.266 Start Dir 3.00/100' 11181.70' MD, 6122.30' TVD 11,200.0 89.22 138.83 6,122.6 - 3,132.4 - 2,472.3 6,027,958.67 467,411.81 70.487 - 150.266 11,300.0 89.49 141.82 6,123.7 - 3,209.3 - 2,408.4 6,027,881.47 467,475.32 70.487 - 150.266 11,400.0 89.75 144.80 6,124.4 - 3,289.5 - 2,348.7 6,027,801.06 467,534.73 70.487 - 150.265 11,493.9 90.00 147.61 6,124.6 - 3,367.5 - 2,296.5 6,027,722.80 467,586.65 70.487 - 150.265 KupA T3 11,500.0 90.01 147.79 6,124.6 - 3,372.7 - 2,293.2 6,027,717.66 467,589.87 70.487 - 150.265 11,600.0 90.15 150.79 6,124.4 - 3,458.6 - 2,242.2 6,027,631.49 467,640.58 70.487 - 150.264 11,646.5 90.22 152.18 6,124.3 - 3,499.5 - 2,220.0 6,027,590.55 467,662.61 70.486 - 150.264 End Dir 11646.50' MD, 6124.30' TVD 11,700.0 90.22 152.18 6,124.1 - 3,546.8 - 2,195.0 6,027,543.14 467,687.38 70.486 - 150.264 11,800.0 90.22 152.18 6,123.7 - 3,635.3 - 2,148.3 6,027,454.51 467,733.68 70.486 - 150.264 11,900.0 90.22 152.18 6,123.3 - 3,723.7 - 2,101.7 6,027,365.89 467,779.98 70.486 - 150.263 12,000.0 90.22 152.18 6,122.9 - 3,812.1 - 2,055.0 6,027,277.26 467,826.28 70.486 - 150.263 12,100.0 90.22 152.18 6,122.5 - 3,900.6 - 2,008.3 6,027,188.64 467,872.58 70.485 - 150.263 12,200.0 90.22 152.18 6,122.1 - 3,989.0 - 1,961.7 6,027,100.02 467,918.88 70.485 - 150.262 12,300.0 90.22 152.18 6,121.8 - 4,077.5 - 1,915.0 6,027,011.39 467,965.18 . 70.485 - 150.262 12,400.0 90.22 152.18 6,121.4 - 4,165.9 - 1,868.4 6,026,922.77 468,011.48 70.485 - 150.261 12,500.0 90.22 152.18 6,121.0 - 4,254.4 - 1,821.7 6,026,834.15 468,057.78 70.484 - 150.261 12/13/2007 11:53:23AM Page 6 COMPASS 2003.16 Build 42B ,__ • Halliburton Company HALUEURTON Planning Report - Geographic Drilling and Formation PIONLER Evaluation Database: ..EDM Alaska Local Coordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk ND Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Welibore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 Planned Survey Measured Vertical • Map Map Depth inclination Azimuth Depth +N /-S +E/ -W Northing Easting (ft) ( ?) (bearing) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 12,508.1 90.22 152.18 6,121.0 - 4,261.5 - 1,817.9 6,026,826.97 468,061.53 70.484 - 150.261 Start Dir 3.00/100' 12508.10' MD, 6121.00' TVD 12,600.0 91.27 154.73 6,119.8 - 4,343.7 - 1,776.9 6,026,744.61 468,102.25 70.484 - 150.261 12,605.5 91.33 154.89 6,119.6 - 4,348.7 - 1,774.5 6,026,739.66 468,104.55 70.484 - 150.261 KupA T4 12,628.8 91.32 155.59 6,119.1 - 4,369.9 - 1,764.8 6,026,718.44 468,114.24 70.484 - 150.261 End Dir 12628.80' MD, 6119.10' TVD 12,700.0 91.32 155.59 6,117.5 - 4,434.7 - 1,735.3 6,026,653.51 468,143.39 70.484 - 150.260 12,800.0 91.32 155.59 6,115.2 - 4,525.7 - 1,694.0 6,026,562.32 468,184.34 70.484 - 150.260 12,900.0 91.32 155.59 6,112.9 - 4,616.7 - 1,652.7 6,026,471.12 468,225.28 70.483 - 150.260 13,000.0 91.32 155.59 6,110.5 - 4,707.8 - 1,611.4 6,026,379.93 .468,266.23 70.483 - 150.259 13,100.0 91.32 155.59 6,108.2 - 4,798.8 - 1,570.1 6,026,288.74 468,307.18 70.483 - 150.259 13,200.0 91.32 155.59 6,105.9 - 4,889.8 - 1,528.7 6,026,197.55 468,348.12 70.483 - 150.259 13,300.0 91.32 155.59 6,103.6 - 4,980.9 - 1,487.4 6,026,106.35 468,389.07 70.482 - 150.258 13,400.0 91.32 155.59 6,101.3 - 5,071.9 - 1,446.1 6,026,015.16 468,430.02 70.482 - 150.258 13,429.3 91.32 155.59 6,100.7 - 5,098.6 - 1,434.0 6,025,988.44 468,442.01 70.482 - 150.258 Start Dir 3.00/100'13429.30' MD, 6100.70' TVD 13,500.0 91.35 153.47 6,099.0 - 5,162.4 - 1,403.6 6,025,924.52 468,472.15 70.482 - 150.258 13,600.0 91.39 150.47 6,096.6 - 5,250.6 - 1,356.6 6,025,836.11 468,518.77 70.482 - 150.257 13,648.9 91.41 149.00 6,095.4 - 5,292.9 - 1,332.0 6,025,793.76 468,543.25 70.482 - 150.257 KupA T5 13,660.1 91.33 149.32 6,095.2 - 5,302.5 - 1,326.2 6,025,784.16 468,548.93 70.481 - 150.257 End Dir 13660.10' MD, 6095.20' TVD 13,700.0 91.33 149.32 6,094.2 - 5,336.8 - 1,305.9 6,025,749.77 468,569.14 70.481 - 150.257 13,800.0 91.33 149.32 6,091.9 - 5,422.8 - 1,254.9 6,025,663.59 468,619.80 70.481 - 150.256 13,900.0 91.33 149.32 6,089.6 - 5,508.7 - 1,203.9 6,025,577.41 468,670.45 70.481 - 150.256 14,000.0 91.33 149.32 6,087.3 - 5,594.7 - 1,152.9 6,025,491.24 468,721.11 70.481 - 150.256 14,100.0 91.33 149.32 6,085.0 - 5,680.7 - 1,101.9 6,025,405.06 468,771.76 70.480 - 150.255 14,200.0 91.33 149.32 6,082.7 - 5,766.7 - 1,050.8 6,025,318.88 468,822.42 70.480 - 150.255 14,300.0 91.33 149.32 6,080.3 - 5,852.7 -999.8 6,025,232.70 468,873.07 70.480 - 150.254 14,377.6 91.33 149.32 6,078.5 - 5,919.4 -960.3 6,025,165.83 468,912.38 70.480 - 150.254 Start Dir 3.00/100' 14377.60' MD, 6078.50' TVD 14,400.0 91.49 148.67 6,078.0 - 5,938.6 -948.7 6,025,146.59 468,923.84 70.480 - 150.254 14,500.0 92.20 145.75 6,074.8 - 6,022.6 -894.6 6,025,062.36 468,977.61 70.480 - 150.253 . 14,516.0 92.32 145.29 6,074.1 - 6,035.8 -885.6 6,025,049.16 468,986.60 70.479 - 150.253 End Dir 14516.00' MD, 6074.10' TVD - KupA T6 14,600.0 92.32 145.29 6,070.7 - 6,104.8 -837.8 6,024,979.97 469,034.12 70.479 - 150.253 14,700.0 92.32 145.29 6,066.7 - 6,186.9 -780.9 6,024,897.61 469,090.68 70.479 - 150.253 14,800.0 92.32 145.29 6,062.7 - 6,269.0 -724.0 6,024,815.26 469,147.24 70.479 - 150.252 14,900.0 92.32 145.29 6,058.6 - 6,351.2 -667.1 6,024,732.90 469,203.80 70.479 - 150.252 15,000.0 92.32 145.29 6,054.6 - 6,433.3 -610.2 6,024,650.55 469,260.36 70.478 - 150.251 15,100.0 92.32 145.29 6,050.5 - 6,515.4 -553.3 6,024,568.19 469,316.92 70.478 - 150.251 15,155.9 92.32 145.29 6,048.3 - 6,561.3 -521.5 6,024,522.17 469,348.53 70.478 - 150.250 KupA T7 12/13/2007 11:53:23AM Page 7 COMPASS 2003.16 Build 428 • Halliburton Company HALLIBURTON Planning Report - Geographic Drilling and Formation MALE Evaluation Database: ..EDM Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Welibore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting - Shape ( ?) (bearing (ft) (ft) (ft) (ft) (ft) Latitude Longitude KupA T6 0.00 0.00 6,074.1 - 6,035.8 -885.6 6,025,049.16 468,986.60 70.479 - 150.253 - plan hits target - Point KupA T5 0.00 0.00 6,095.4 - 5,292.9 - 1,332.0 6,025,793.76 468,543.25 70.482 - 150.257 - plan hits target - Point KupA T4 0.00 0.00 6,119.6 - 4,348.7 - 1,774.5 6,026,739.66 468,104.55 70.484 - 150.261 - plan hits target - Point Geo Poly KupA 0.00 0.00 0.0 - 2,110.9 - 3,857.7 6,028,985.61 466,030.67 70.490 - 150.278 - plan misses by 4397.5ft at 0.0ft MD (0.0 TVD, 0.0 N, 0.0 E) - Polygon Point 1 0.0 - 3,619.1 - 2,274.0 6,027,471.16 467,608.09 Point2 0.0 - 4,383.4 - 1,843.1 6,026,705.20 468,035.85 Point3 0.0 - 5,164.1 - 1,668.0 6,025,923.88 468,207.77 Point4 0.0 - 5,582.3 - 1,418.1 6,025,504.71 468,455.95 Point 5 0.0 - 5,935.5 - 1,242.4 6,025,150.84 468,630.20 Point 6 0.0 - 6,303.0 - 1,053.3 6,024,782.61 468,817.79 Point 7 0.0 - 6,699.7 -816.4 6,024,385.00 469,053.06 Point 8 0.0 - 7,093.7 -465.1 6,023,989.62 469,402.72 Point 9 0.0 - 6,650.8 -2.2 6,024,430.59 469,867.37 Point 10 0.0 - 5,074.0 - 1,039.8 6,026,011.42 468,836.26 Point 11 0.0 - 3,343.5 - 1,898.6 6,027,745.21 467,984.56 Point 12 0.0 - 1,778.7 - 3,409.0 6,029,315.96 466,480.67 Point 13 0.0 - 2,056.6 - 3,821.1 6,029,039.76 466,067.49 Point 14 0.0 - 2,110.9 - 3,857.7 6,028,985.61 466,030.67 KupA T2 0.00 0.00 6,110.3 - 2,490.1 - 3,051.9 6,028,603.21 466,834.81 70.489 - 150.271 - plan hits target - Point KupA T1 0.00 0.00 6,091.4 - 2,201.6 - 3,357.1 6,028,892.89 466,530.90 70.490 - 150.274 - plan hits target - Point KupA T7 0.00 0.00 6,048.3 - 6,561.3 -521.5 6,024,522.17 469,348.53 70.478 - 150.250 - plan hits target - Point KupA T3 0.00 0.00 6,124.6 - 3,367.5 - 2,296.5 6,027,722.80 467,586.65 70.487 - 150.265 - plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth, Diameter Diameter (ft) (ft) Name ( ") (1 2,894.2 2,806.0 9 5/8" 9 -5/8 12 -1/4 9,913.9 6,091.4 7" 7 8 -1/2 15,155.9 6,048.3 41/2" 4 -1/2 6 -1/8 12/13/2007 11:53:23AM Page 8 COMPASS 2003.16 Build 428 • • Halliburton Company HALLtBURTOIV Planning Report - Geographic Drilling and Formation PIONEER Evaluation Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSK -33 - Slot ODS -33 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 56' @ 56.0ft Project: Oooguruk Developement MD Reference: 56' @ 56.0ft Site: Oooguruk Drill Site North Reference: True Well: ODSK -33 Survey Calculation Method: Minimum Curvature Wellbore: ODSK -33 KupA Design: ODSK -33 Kup A wp01 Plan Annotations Measured Vortical Local Coordinates Depth Depth +N /4 +E/ -W (ft) (ft) (ft) (ft) Comment 600.0 600.0 0.0 0.0 Start Dir 1.00/100' 600.00' MD, 600.00' TVD 1,100.0 1,099.4 3.8 -21.5 Start Dir 2.00/100' 1100.00' MD, 1099.40' TVD 1,350.0 1,347.1 9.5 -53.6 Start Dir 3.00/100' 1350.00' MD, 1347.10' TVD 1,663.5 1,650.0 23.2 -131.9 End Dir 1663.50' MD, 1650.00' TVD 2,670.7 2,600.0 81.4 -461.4 Start Dir 3.00/100' 2670.70' MD, 2600.00' TVD • 2,894.2 2,806.0 94.9 -546.7 End Dir 2894.20' MD, 2806.00' TVD 2,914.2 2,824.0 96.2 -555.4 Start Dir 3.00/100' 2914.20' MD, 2824.00' TVD 4,344.8 3,768.1 203.4 - 1,580.0 End Dir 4344.80' MD, 3768.10' TVD 5,729.1 4,265.6 313.4 - 2,867.2 Start Dir 3.5/100' 5729.10' MD, 4265.60' TVD 9,713.9 6,081.4 - 2,077.9 - 3,513.8 End Dir 9713.90' MD, 6081.40' TVD 9,913.9 6,091.4 - 2,201.6 - 3,357.1 Start Dir 3.00/100' 9913.90' MD, 6091.40' TVD 10,167.7 6,104.0 - 2,371.4 - 3,169.1 End Dir 10167.70' MD, 6104.00' TVD 10,240.0 6,107.5 - 2,423.2 - 3,118.9 Start Dir 3.00/100' 10240.00' MD, 6107.50' TVD 10,477.4 6,112.2 - 2,593.0 - 2,953.0 End Dir 10477.40' MD, 6112.20' TVD 11,181.7 6,122.3 - 3,118.6 - 2,484.4 Start Dir 3.00/100' 11181.70' MD, 6122.30' TVD 11,646.5 6,124.3 - 3,499.5 - 2,220.0 End Dir 11646.50' MD, 6124.30' TVD 12,508.1 6,121.0 - 4,261.5 - 1,817.9 Start Dir 3.00/100' 12508.10' MD, 6121.00' TVD 12,628.8 6,119.1 - 4,369.9 - 1,764.8 End Dir 12628.80' MD, 6119.10' TVD 13,429.3 6,100.7 - 5,098.6 - 1,434.0 Start Dir 3.00/100' 13429.30' MD, 6100.70' TVD 13,660.1 6,095.2 - 5,302.5 - 1,326.2 End Dir 13660.10' MD, 6095.20' TVD 14,377.6 6,078.5 - 5,919.4 -960.3 Start Dir 3.00/100' 14377.60' MD, 6078.50' TVD 14,516.0 6,074.1 - 6,035.8 -885.5 End Dir 14516.00' MD, 6074.10' TVD 15,155.9 6,048.3 - 6,561.3 -521.4 Total Depth at 15155.90' MD, 6048.30' TVD 12/13/2007 11:53:23AM Page 9 COMPASS 2003.16 Build 42B SURVEY PROGRAM Well Planning - Pioneer - Oooguruk i ANTI - COLLISION SETTINGS J Date: 2004-01- 10T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Interpolation Method: MD, Interval: 25.0 Error System: ISCWSA Depth Range From: 0.0 ?0 15155.6 Depth From Depth To Survey/Plan Tool 0.0 2100.0 ODSK -33 Kup A wp01 CB- GYRO -SS Scan Method: Tray. Cylinder North Centre Distance: Plan: erence: 5.6 Error Surface: Elliptical C Reference: Plan: ODSK -33 Kup A 90401 2100.0 15155.6 ODSK 33 Kup A 90401 MWD+SAG+CA +IIFR +MS Warning Method: Ruules s Based d ni 1 _ ! ODSN-a PSI 1005N-1011511 I OD$N-94 ' • I ODSN -B PS , 1 OOSN•51164 ODSK -7i 157 ■ ,' OQSN -4 From Color To MD ' 0 ' , - IC7D:3K•.S Kup ODSN•2 P81 0 250 1000 1250 330 r4 3 ' 3 <, .• toper SI IS4 50 500 -- OQ - -- - 2 SN - P$4 A ODBN -6I 184_ 500 - 750 _ ° ; S y i .. � 9 ° , � . +�. 1 :::0D- __ 750 1000 �ODSN - PS8 - -- : gOSN -4 P ODSN -16 PS14 ' <" "� R' ' ro t e ,, v \ 3. r'' SN 12 P81 1000 l ` ■ _.. R; '0,4.:- 36!:-;',--,,,;.";;•:,.., 6.1 y ,.e, f " !` i \ � \e �a.�,, ti ODSN 91 330 r ' e i1� +° �"„� a i 4 �� a o • 4 Ij� ' �N PN} 1250 1500 ,-,. 3D ' f; ,1 1 e 4..1 v o , -da4 cy ip 0, - f �ODSN•10t iS9 , 4 r • rc. , //ii •s 4 .h am` w r .. -r d •1 ■ y1 , 1500 1760 _ .. -�, `ti a y � ODSN -1T PS1 36° i.';'' , ' t�"�'c; ` ° a "� - a .:, \�.,, ,, i �,t ,.. , ,<06/ , �� ,4 y w ""r' ,a r' , : 1 u _ 60 '�008N- 2711Ni 1760 2000 �ODSN•12 a `f� +DSN 271 IN2 r u r- d ,f L F ,` i .'.mJ� 'Vt 2000 2250 -- .r e . �+. r w����� a j� ,° 1+'a f , ✓i -4,,. 2250 2600 �O a8'i - f3 'd+t • ` � -- $ /'• , + . y 3v .tr _. . �/ I . ia�a r 2500 -_`. 2750 , ODSN•181181ik ' ` �`�� 4 1 )1 ,. , +������ ' l 2750 - -_. LODS 20 1 •DSN- 2911N1 , rri i 'r ` ,, 4 ► i � r ' i ODSN -2911 / / P' 0 P N. 3000 3250 i r s 4 ' ODSN -3 ,,. ! S � � 3250 3500 ,., i /` - � 1 '�ti j/ �- t i 1� r .l 1+1+4e 3600 3750 270 , f ie 270 di..•. 5 e ittl OcODSN 321 3750 _ 400 , ff0 ,04 -'•":,;';'''',i, . ' � IN ODSN•141181 ► Ay. '`w ' 1 ,w;tt ,J p �� 40:101,m4"11). �� 3 , f � ,5s. N- - .. �i 7` ..;-, ,! e„ . 4 lepptif i ' � , 7 ' ODSN -30 PN 4 000 6000 1 a . -n ft1� / , ��• t5t���. k � �l�► � r c _ _. 1 _. 11 11! 3 '» � !R% "a,.4 P t a►�1 .tr, it i - 6000 1 f , r �a. --4' :3 r i„ >'t �d 1 3 0 64 1 r �i� 5000 --. ��i i � ��'. •... �,� t ' 4 y l +� 600.3 7000 �` , - ! .. ..1300u b/ 'fi` •� 1,4131 PN A 8 A .4,11 • ' . a ii "� ;.,�, • , oDeN -3.i PN8 �•., � U d �!! < '1'.' � lr � P .ttrb �:�► 7000 8000 G 3 :r. � � �((p � e z y i "s 4 � av'Iti - 6 000 9000 g - i ' . �� 1p � + i r �i to y'!�� r 2 T 0 Ii k�tilt ��� . - ..720 +� s ri , 7 . �, � � s t wl�e��� "fir *'1 dr- - - -- 9000 10000 , ; ��t r. •��� � 9 ti 5 t t 3.v 4 � r �/ ODSDW4 44 Dl� r. y rr� a iG3$ KII� 1 ', t r � w � 4 ♦ 10000 11000 •' 1 � -., � \r f is 240 �� yil x74 n ,,,h 1- : ♦ i Kv • , -120 _- - 1 1oco ...- ,. - . 1 2000 ��OSN•1411 110. 6'`� 1�,C� ODSN•341 IN9 , 4 , p !� \�\ �� _ 4 q �� - ., rV 1 Loco- - - -� 12000 13000 --- --i - . � . 41 11eF 7� r' � , \ \�_ ' P'h .. f + r� . 9 t its 6 a s 34;;;;,' v ' - 210 s 41 . ,, ....e,,Am._+ 150 _ 01:113K 0\19 r 9 / • e . ( ODSK 38I KupID 1 14000 i �. �. _ . �� : ,;;���; t y;M: d s ! ! , J L ODSN.13 ODSK -381 Kup 15000 16000 O DSN 3911N11 4 Y 1 90 80 ♦ " , Knot) 9v r • ' Ya S � a' ' . _ ���' Y•�� 1N� h ,r �. .,gym e N-3 __ - �� ODS 7 PNb t grit- -4 'm 1,� !I re t ' k _ , LODSK -41 Kupa 16000 17000 01)8N-37 PNb � � "� H �! •4.(0V 61 " ° pt O+At..1) (beanngl vs Centre to Centre Separation (40 ft/in) 210 ! _ \ \lt ` t-t � 9 w a ' ,4 `� ,,,, ::• 150 -, \ I ravelling Cylinder Azimuth (TF , -..- - 17000 18000 n X 1 . '.1 , N A iiVii. •. , OD.SN -38 PN 18000 18000 ODSN -13 P91 ‘, roDSN -391 lNt 180 , 1 19000 20000 ODSN -46 PN14 ' 20000 21000 secnory oeTa�s ' ODSN- 1111819) LO -42 Kup _ 21000 22000 5., 1.40 Inc 63. 7vo 414/4 +6693 e. 0109 TF. 5694 70,902 ODSN- 431 I N13 Lppgrj,±�" 22000 0 1 0.0 0.00 0.00 0.0 3.o 3.o 0.00 0.09 0.0 -._ - ____ - -_ - ! i 1100:0 sm 280.00 ,o�e9:a ie -x�s �:w 2aam -15,4 4 1350.0 1000 280.00 1347 95 53,6 2.00 0.00 -36,5 �L /� 9 5 1660.5 1940 280.00 1860.0 212 -131.9 3.00 0.00 -94.7 rave ling Cylinder Azimuth (TFO+AZI) lbearingf vs Centre to Centre Separation 1 100 ft /inl 6 2670,7 1940 260.00 2600.0 61.4 -481.4 0,00 0,00 -331.3 7 2894.2 26.08 278.29 28060 91.2 -546.7 3.00 $45 -391.3 8 2914.2 26.06 278.29 2824,0 96.2 -555.4 0.00 0.09 -397.3 9 4344.7 6994 274,88 3788,1 203.4 - 1580.0 3,00 -4.67 - 1072.8 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -33 10 5729.1 68.94 274,88 4285,6 3113 - 2887., 0.00 0,00 -1901,1 11 971.6 87.12 128.29 6081,4 - 2077.6 - 35118 3,50 - 122.22 113.4 12 9913.6 87.12 128.29 6091,4 -22010 -3357.5 0,00 0.00 -122.1 4.961 T1 Ground Leve1: 13.5 13 10166,9 87.23 135,90 6104,0 -2371.0 - 31695 3.00 89,39 124.3 +Nl- 14 10240.0 87,23 135,90 8107 - 2423.5 -31197 0,00 0.00 1994 S + -W Northing Easting Latittude Longttude Slot i 15 10334.3 6933 134.00 81,03 - 2490.1 -30519 100 4205 269.2 NyN 72 0.0 0.0 6031080.67 469896.50 70.496 - 150.246 ODS-33 16 1047.1 89.1 13928 61122 -2593.0 - 29530 3.90 22,08 430.3 17 11181.5 89.16 138.28 61223 -31107 -248404 0.00 0.00 1128.7 18 11493.8 90.00 1470.1 6124,6 .3387,5 - 22965 3.00 85,09 1441.3 Kup, 73 12 11818. 90.22 152.18 6124.3 - 3498.6 -22199 3.00 87,24 1593.4 REFERENCE INFORMATION 20 12507.7 90.22 152.1 6121.0 42864 - 1818.0 0.00 0.00 2448.0 21 12805.2 21.33 151.80 8119,6 43197 - 1775 3.00 6788 2544.4 Kup, T4 22 128294 91.32 15659 61191 43696 -178446 300 90.7 2567.3 23 13429.0 91.32 156.59 6100.7 -50966 - 143.0 0.00 0,00 3354.0 Co-ordinate (WE) Reference: Well ODSK -33 - Slot ODS-33, True North 24 13648,6 91,11 14 60354 -5292.9 - 1332.0 3,00 3.9,17 4471.7 K,p4 55 Vertical (TVD) Reference: 56' @ 56.0f2 35 1365113 9, .33 149 32 60951 - 5302.4 -132 8.3 3.00 20186 3582.8 26 1437.3 91.33 14,32 60715 - 5919.4 -960,3 0.00 0.00 4298,1 Section (VS) Reference: Slot - ODS33(0.ON, 0.0E) 27 14515.7 92.32 145,29 6074.1 -60 35.8 -885,6 3.00 -78,13 4436,3 KupL 76 Measured Depth Reference: 66' @ 56.Oft 2e 1155.6 92.32 145 28 6046.3 a5613 -5215 0.00 0.00 50755 Kuosn Calculation Method: Minimum Curvature • ' 1. IIGEYOY TYPE C 3 1 /8' -5880 PSI CAW VALVE ' • 2. BODY IYPE C 2 9/16' -5000 PSI CATEYALYE CHOKE MANIFOLD SC EMATIC . 3 . s o 2 1/16 -10000 PSI REMOTE CHOKE • 4. OKIRNI .L- CRAYEO 3 I /8'-5000 PSI BMW OOKE NABORS ALASKA RIG 1 9AC s. FIANCID LEE 2 1/I6 X 21/16' X 2 1 /I6 -5000 PSI • 8. 5 MAY Fu* BLOCK 3 1/8' x 3 1 /6' X 2 1/16' x 2 1/16 X 2 I /Ie -5000 PSI ' 7. 5 MAY FLOW SACK 3 1 /8' X 3 1 /8' x 3 1 /e x 3 1 /e X 2 1/10 PSI 3. 8. 4 N A Y F ' 1 D N BLOCK 2 1/16 X 2 1/16 X 2 1/16• x 2 or-5000 PSI • To • 9. 2 1/1e -5000 PSI SENSOR BLOCK 1, • . 10. 2 1/16'- I0.000P51 It 2 1/111 PSI SPOOL • • • $� • VD/ II. 3 1 /e• x 2 1/16 -9000 PSI SPOOL • • 101 .12. 2 I/16 X 2 1 /IC -5000 PSI SPOOL • 13. 3 1/8' -5000 PSI x 2 1 /16' -So00 PSI SPOOL • 15 14. 2 1 /18' -I0.000 PS x 2 1 /1e' -5000 PSI DOUBLE SFUO AOAPIOR 2 1 5 15. 2 1/16' -5000 PSI TARGET FIANCE 16. 3 1/V -5000 PSI FARCE1 FLANGE 34 ) 17. 3 1 /8' -5000 PSI X 2 1116' -5000 PSI DOUBLE SW RAPTOR P �'C �� � 18. 3 1 /8' X 3 1/8 5000 PSI SPOOL • 19. 3 MAY RIM BLOCK 3 1/8' x 3 1 /8' x 3 1/8' -5000 PSI F 2 1 20. S WAY FLOW BLOCK 2 9/16' X 2 9/16' X 2 9/1e X 2 9/16' X 2 9/1e -5000 PSI 00 • 3 • To ts� �\ S ® Q V 0 . • • • FR ©O / �g m `�- a 0 '.000" • e ■ 6 0 ■ ® �� 3 . t> . 13 d • • • . . . , _guis tINoma M s µ, Man wwKS ALASKA 14C If1ne 1k . CHOKE M*nffOLD SCMEMAIC (OW 1a MO wm m Q • L lthh!'I — ••_• — °R $• ' I ` " A ` �� -- offs .3• oM. IN IIMC —owe 1 M L • • • • • • f 1` • HYDRIL 11" 5k PS! • GK ANNUIAR OP • 3' -11' SCREWED FLANGED BOTTQM CONNECTION • . ( 47 3/4 LENGTH • • S!I. , _ ._ ------ +---- - - ---- 11. 50001 4'_7• ,. I .� -. FLANGED HYDRIL • DOUBLE CATE PREVENTOR • 13' -10' 3' !/8" 5000/ HCR VALVE' - - - ' - � • 55" LENGTH -4(11 . � . i M • 3 1/8" 50001 HCR VALVE i , -4" 3 • CHOKE L,NE I 4 I . I u 11` { - ; _„ ___ -2 KILL LINE-_ -I m�1� iii. -mils " u lr -4 ur+ MT _ t 3 z� • • 3 1/8" 5000/ GATE VALVE . I I . -: 3 50001 GATE VALVE 1 HYDRIL II' 5k PSI 3' -5' - - -- -- --- -- - - --- - -• �. HYDRAULIC RAM SINGLE GATE FLANGED LENGTH H • NABORS ALASKA RIG 19AC _ . • BOP STACK CONFIGURATION • • i • •�T - „ .;tea ....�. �, PC 1srC '° 04/0-471A 11011.0101 !� s1,« a �J A is nags wo rain _ ^ aQ *dint * we 1 /B r r w.�.. • • M r ' . . , =______,.::: • I 11 :: L �. I. MUM AMA Nana • , ` o w A[ O� Iffillill Av i � 4 AEJ 1I ( � _ � � 1 l( . 11111111111111 r MINN( saOM'lag • 1 VIM Mil . L __:., ,;, t ,,., h , 111 • '' . irA E.....t. ►► � _� 1 ,, : � ►,; NI !� 1 ' la 41 . n . i .:: • ..., 1 . illllI �lIflk . f IDA . . ir II Nabors Aiello . N1 -] • 1u t■BORS AUSSA WC IYAC 21 - I/4 MUTER . VW•111 A 140 MOM A0WWI t ?' A • • Page 1 of 1 • Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Thursday, January 10, 2008 3:32 PM To: Maunder, Thomas E (DOA) Subject: ODSK -33 and ODSN -34i Attachments: ODSN -34i IN9 wp05 Distance between Wells at TVD.xls; AC Plot ODSN -34i IN9 wp05.pdf; P lot ODSK -33 KupA w 01. .LAG df P P P Tom, $iA+o -\sr L\ & Attached are the files on the AC for the ODSK -33 and ODSN -34i as well as the distance to the nearest well (I think this will change to farther away when we take a closer look at the ODSN -11 i well in the near future). The permit requests for the ODS -32i and the ODS -31 will be coming shortly. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/10/2008 • Page 1 of 2 Maunder, Thomas E (DOA) From: Franks, James [James. Franks @pxd.comj Sent: Tuesday, January 08, 2008 12:26 PM To: Maunder, Thomas E (DOA); Polya, Joe; Lewis, Steve Cc: Hazzard, Vance Subject: RE: Information Needs Ooo Permit Packages, et at Tom, As always, thanks for the comments. The ODSN -32i and ODSN -31 are here in the office and so, so close to going out the door. I will have to add the information in your 2"d paragraph to those prior to going over to your shop and will get the information for the other 4 to you soon Thanks for the information on the 407 and mentioning the sundry to re -enter on the ODSN -34i. Joe said that you had a comment on the LOT for the surface shoes on the wells due to a possible request for annular disposal in the future. I have always intended to take those LOT and not just to an FIT, so if I have said FIT for the surface casing shoe, I apologize for the error. Prior to the end of the unrestricted season on April 15th, we are going to everything we can to get 3 Kuparuk wells drilled. As such, we are having to make a few changes to the drilling schedule. Right now, we are likely to only be batch setting the surface casings for the ODSK -36i through ODSN -321 and deferring the ODSN -31 surface casing to later in the program. Also, due to the end of the unrestricted season, we not be able to drill the ODSN- 321 to TD this winter and will need to turn in a 407 to suspend and then a sundry to re- enter. I am attaching a snapshot of the schedule to illustrate the first few months of the plan — of course this could change at any moment... and probably willC. Thanks for your time, James Spud date: 12/15/2007 S = Surface, I = Intermediate P = Production, C = Completion 3 row switches - No Pulse Test Wells Drill Start Drill End Date Days Date Disposal Well DW1-44 12/15/2007 30.9 1/14/2008 ODSK -36i - Batch Drill Surface Kup Di 1/14/2008 5.6 1/20/2008 ODSK -35 - Batch Drill Surface Kup B 1/20/2008 4.6 1/25/2008 ODSN -34i - Batch Drill Surface IN9 1/25/2008 4.5 1/29/2008 ODSK -33 - Batch Drill Surface Kup A 1/29/2008 4.3 2/2/2008 ODSN -32i - Batch Drill Surface IN7 2/2/2008 4.1 2/7/2008 ODSK -33 - Kup A - (K 1) I,P,C 2/7 /2008 23.8 3/1/2008 ODSK -35 - Kup B - (K 2) I,P,C 3/1/2008 21.5 3/23/2008 ODSK -36i - Kup Di - (K 3) I,P,C , 3/23/2008 17.8 4/10/2008 ODSN -40 - Batch Drill Surface PN12 4/10/2008 4.3 4/14/2008 1/10/2008 i 0 Page 2 of 2 ODSN -39i - Batch Drill Surface IN11 4/14/2008 3 7 e� r ODSN -38 - Batch Drill Surface PN10 4fl €,, 3 6 l �'[ ODSN -40 - PN12 - I,P,C .: 412�� 23.1 _:- fi ° ODSN -39i - IN11 - I P C x /1 . ` 0 20 9 .= u . -7 r ODSN-37 - Batch Drill Surface PN8 3 :x ., 3 6 r. ODSN -31 - Batch D Surface PN6 . 4 . ° � f ODSN -30 - Batch Drill Surface PN5 3 9 ' o ODSN -29i - Batch Drill Surface IN4 ' - . 4 F ODSN -30- PN5 -IPC Att:!'!` 204 -' ODSN-43i - IN13 - S I P C V1/ 1 270' 'a ODSN -45 - PN14 - S,I,P,C 31.7 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 08, 2008 12:01 PM To: Polya, Joe; Franks, James; Lewis, Steve Cc: Hazzard, Vance Subject: Information Needs Ooo Permit Packages, et al Gentlemen, I am reviewing the permit applications for ODSK -36, ODSK -35, ODSN -34 and ODSK -33. As I understand, these 4 wells as well as -32 and -31 will have the surface sections batch drilled and then as many K wells as possible will have the remainder of the wells drilled prior to -May 1( ?). The drilling order for the initial 4 wells will be -36, -35, -34 and -33 with the remainder likely -32 and -31. I would expect that the remaining permits will be submitted soon. In the directional portion of the permit applications, I am requesting that the traveling cylinder plot and anti - collision information be included. I realize that most of the well sections are still to be drilled, however planned or designed information for proximity is acceptable. Where a given well is an injector, wells within a %4 mile radius at the top of the hydrocarbon formation(s) should be identified with the planer distance between wellbores calculated. I note for ODSN -34 that it is stated that it is likely to be a year before the rig would return to drill the remainder of the well. For that well and any Kuparuk well where it is not possible to drill the deeper sections ' to the conclusion of the winter season, a 407 with all the necessary operations information should be submitted with the well status noted as suspended. A sundry notice will then be needed when operations are resumed. It is not necessary to file any formal paperwork on these wells after the surface casing is set and the rig has moved on. When the rig begins drilling the deeper sections on the wells, I'd appreciate an email with the projected forward schedule provided. Congratulations on beginning the drilling operations. Call or message with any questions. Tom Maunder, PE AOGCC 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. 1/10/2008 Alaska Department of Natural Resources Land Administration System Page 1 of • 411 jd RecordsfStatus Plats Recorder's Search State Cabins Nature! Resources Alaska DNR Case Summary File Type: Pr" File Number: f 355036 at Printable Case File Summary See Township, Range, Section and Acreage? New Search Yes No LAS Menu Case Abstract 1 Case Detail 1 Land Abstract File: ADL 355036 .• f'4T,_ Search for Status Plat Updates As of 01/08/2008 Customer: 000041707 PIONEER NATURAL RESOURCES ALASKA, INC 700 G STREET SUITE 600 ANCHORAGE AK 99501 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 07/19/1983 Total Acres: 5760.000 Date Initiated: 03/24/1983 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 03/21/2007 Case Subtype: BS BEAUFORT SEA Last Transaction: U AXN1 UNIT AREA EXPANDED Meridian: U Township: 013N Range: 007E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 013N Range: 007E Section: 02 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 03 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 10 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 11 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 12 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 13 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 14 Section Acres: 640 Meridian: U Township: 013N Range: 007E Section: 15 Section Acres: 640 Legal Description 03-24-1983 *** SALE LEGAL DESCRIPTION *** TRACT 39-36 T. 13 N., R. 7 E., UMIAT MERIDIAN, ALASKA SECTION 1, PROTRACTED, ALL, 640.00 ACRES; SECTION 2, PROTRACTED, ALL, 640.00 ACRES; http : //www. dnr. state . ak.us/las/C ase Summary .cfm?FileType=ADL&FileNumber=355036&... 1/8/2008 Alaska Department of Natural Resources Land Administration System Page 2 of 2- . . SECTION 3, PROTRACTED, ALL, 640.00 ACRES; SECTION 10, PROTRACTED, ALL, 640.00 ACRES; SECTION 11, PROTRACTED, ALL, 640.00 ACRES; SECTION 12, PROTRACTED, ALL, 640.00 ACRES; SECTION 13, PROTRACTED, ALL, 640.00 ACRES; SECTION 14, PROTRACTED, ALL, 640.00 ACRES; SECTION 15, PROTRACTED, ALL, 640.00 ACRES. THIS TRACT CONTAINS 5760.00 ACRES MORE OR LESS. *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** 9 -11 -92 ***UNITIZED LEGAL * * * KUUKPIK UNIT, TRACT 6 SAME AS SALE LEGAL OF 3 -24 -83 9/17/92 ** *NEW SEGMENT * ** SEGMENT 1 THE SAME ACREAGE AND LAND AS IN THE KUUKPIK UNIT LEGAL DESCRIPTION. SAID INTEREST EXTENDS FROM THE SURFACE DOWN TO A DEPTH OF 8,373 FEET. SEGMENT A THE SAME ACREAGE AND LAND AS IN THE KUUKPIK UNIT LEGAL DESCRIPTION. SAID INTEREST EXTENDS BELOW A DEPTH OF 8,373 FEET BENEATH THE SURFACE. 6/1/2001 * * * * * * * * * * * * * *KUUKPIK UNIT TERMINATED * * * * * * * * * * * * ** 03 -07 -2007 *Oooguruk Unit expanded, lease committed to unit* 000GURUK UNIT TRACT 13 T. 13 N., R. 7 E., UMIAT MERIDIAN, ALASKA SECTION 01: PROTRACTED, ALL, 640.00 ACRES; SECTION 02: PROTRACTED, ALL,640.00 ACRES; SECTION 03: PROTRACTED, ALL, 640.00 ACRES; SECTION 10: PROTRACTED, ALL, 640.00 ACRES; SECTION 11: PROTRACTED, ALL, 640.00 ACRES; SECTION 12: PROTRACTED, ALL, 640.00 ACRES; SECTION 13: PROTRACTED, ALL, 640.00 ACRES; SECTION 14: PROTRACTED, ALL, 640.00 ACRES; SECTION 15: PROTRACTED, ALL, 640.00 ACRES; TRACT 13 CONTAINS 5,760.00 ACRES, MORE OR LESS. http://www.dnr.state.ak.us/las/Case Summary.cfm?FileType=ADL&FileNumber=3 55036 &... 1/8/2008 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 0d� <-?3 PTD# „.P0 9 /,3 Development Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- API number are between 60-69) Production should continue to be reported as a fitnction of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, 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. Please note the following special condition of this permit: Non - Conventional production or production testing of coal bed methane is not allowed Well for ()tame 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: 7/13t2007 WELL PERMIT CHECKLIST Field & Pool 000GURUK, KUPARUK UNDEF OIL - 576100 Well Name: 000GURUK KUP ODSK -33 Program DEV Well bore seg ❑ PTD #: 2071830 Company PIONEER NATURAL RESOURCES ALASKA INC. Initial Class/Type DEV / PEND GeoArea 973 Unit 11550 On /Off Shore .9T Annular Disposal ❑ Administration 11 Permit fee attached NA 2 Lease number appropriate Yes 13 Unique well_ name and number Yes , 14 Well located in a defined pool No Kuparuk- Undefined 5 Welilocated proper distance from drilling unit boundary Yes 16 Well located pr distance from other wells NA 17 Sufficient acreage_available in_driiling unit Yes 18 lf_deviated, is_ wellbore plet_included Yes 19 Operator only affected party Yes 110 Operator has_appropriate bond in force Yes Blanket Bond # 193655283 1 11 Permit can be issued without conservation order Yes Appr Date 112 Permit can be issued without administrative_approval Yes ACS 1/8/2008 113 Can permit be approved before 15- day_wait Yes 1 14 Welllocated within area and stretaauthorized by Injection Order# (put IO# in_cornments).(For NA 115 All weils_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_conforrnsto A$31 ,05,03Q(j-.1.A),(j.2.A -D) NA Engineering 118 Conductor string provided Yes 119 Surface casing protects all known USDWS Yes Surface loc ation is offshore. No known USDWs. 120 CMT_vol adequate_ to circulate_on conductor & surf csg Yes 121 CMT vol adequate to tie- inlQng string to surf csg No Planned TOC 590' above disposal zone. 22 CMTwill cover all known_produQti_ve horizons No Slotted liner completion planned. 123 Casing designs adequate for C, 7 B & permafrost Yes 24 Adequate tankege_or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well. 125 lf_a_ re- drill, has_a 10403 for abandonment been approved NA 126 Adequate_wellbore separationproposed Yes Traveling cylinder path calculated._ Gyros and magnetic ranging planned in surface section. 127 if diverter required, does it meet regulations Yes Appr Date 128 Drilling fluid program schematic_& equip iist adequate Yes Maximum expected formation pressure 9.8 EMW. Mud wieght planned up to 11.0 ppg. TEM 1/11/2008 1 29 BOPEs,_dotheymeetregulation Yes V 30 BOPE_press rat appropriate; test to_(put prig in comments) Yes MA$P calculated at 2408 psi 350_0psiBOP testp lanned. 131 Choke_manifold complies w /APIRP -53 May 8 4) Yes 132 Work will occur without operation shutdown No Surface section will be batch drilled. Plan is to drill remainder of well this winter season. 33 is presence of H2S gas probable No H2S has not been reported in any offset wells. 134 Mechanicel_condltion of wells within AOR verified (For service well only) NA Geology 135 Permit can be issued w/o hydrogen sulfide me asures Yes 136 Data_presented on potential overpressuresones Yes Appr Date 137 Seismic analysis of shallow gas zones Yes ACS 1/8/2008 1 38 Seabed condition survey_(if off - s hore) NA 139 Contact name /phone for weekly_prog_ress reports (exploratory only] Yes Joe Polya - 343 -2111 Geologic Engineering `�'� Commissioner: Date: C. fission= : Date •. !�,°ion =r Date ,01 1/ F4J1 0 • 44— •Of I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. 1 " ( CONFIUFNPIAL � PIONEER NATURAL RESOURCES ALASKA, Surface Data Logging END OF WELL REPORT ' PIONEER Natural Resources ODSK -33PB1 & ODSK -33 � i'c6 ao 1 " ORIGINAL � HALLIBURTON 1 Sperry Drilling Services 1 1 1 PIONEER 1 TABLE OF CONTENTS ' 1. General Information 2. Daily Summary ' 3. Daily Operations (I.A.D.C.) 4. Morning Reports 5. Bit Record ' 6. Mud Reports 7. Show Reports 8. Survey Report ' 9. Days vs Depth 10. Data CD HALLIBURTON Sperry Drilling Services I I I 1 1 GENERAL WELL INFORMATION I Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSK -33PB1 and ODSK -33 1 Field: Oooguruk Borough: North Slope Borough State: Alaska I Country: United States API Number: 50- 703 - 20562 -70 & 50- 703 - 20562 -00 Sperry -Sun Job Number: AK -AM- 0005556443 I Job Start Date: 18 Feb 2008 Spud Date: 18 Feb 2008 Total Depth ODSK- 33PB1: 05 Mar 2008 @ MD 9730.0'; TVD 6072.0' I Total Depth ODSK -33: 21 Apr 2008 @ MD 12055.0'; TVD 6053.9' Rig Release Date: 28 April 2008 North Reference: True I Declination: 22.669° Dip Angle: 80.879° I Total Field Strength: 57618 nT Date Of Magnetic Data: 18 Feb 2008 Wellhead Coordinates N: North 70° 29' 45.55" I Wellhead Coordinates W: West 150° 14' 46.16" Drill Floor Elevation 57.50' Ground Elevation: 13.5' I Permanent Dataum: Mean Sea Level SDL Engineers: Colby Marks, Eugene Payne, Boyd Piercey, Wayne Hermanson 1 Company Geologist: Jaque Ledbetter, Paul Cozma, John Pruit, Jim Stewart 1 Company Representatives: Rod Klepzig, Jim Brown, Jeff Clarke, Herb Hupperich I SSDS Unit Number: 123 This report covers ODSK -33PB1 and ODSK -33. The BHA from clean out run at 9730' I and part of the fishing assembly was left in original hole, designated ODSK- 33PB1. Pipe was severed at 6920'. The well was plugged back and sidetracked from 6527' to a final total depth of 12055'. 1 HALLIBURTON i Sperry Drilling Services ' DAILY SUMMARY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' 2_ DAILY S UMMARY ' Oooguruk ODSK -33PB1 17 Feb 2008 Secure well. Raise Beaver slide, walk ways steps, utility lines, shim stomper beams in preparation for move 111 from ODSN -34i to ODSK -33. Shim beams to level rig and re -route supply hoses. 18 Feb 2008 Continue to prepare for move to ODSK -33 well center. Move rig from ODSK -34i, over to ODSK -33. Had to level pad with gravel in front right hand corner. Rig was leveled and pits moved in line with rig. Rig up lines in Hutz and Putz. Install starting head on well conductor per Vetco Gray Representative. Nipple up 21- 1/4" diverter system on Vetco Gray risers. Connect 16" diverter line and knife valve. Install environmental seal below well cellar area. Tranfer mud from RSC to pits. Ensure all pit and flow alarms calibrated and set. Rig up Sperry Gyro and MGT sheaves and hang in derrick/cellar. String lines and make up rope sockets on both lines. Pick up and bring necessary BHA tools to floor. Inspect rig for pre -spud compliance and post signs for diverter line /well ID signage. Hook air heaters back to pipe rack alley way and inspect line for leaks. Function test diverter system per AOGCC requirements. Perform accumulator test per requirements. ' All systems passed test without incidents. Made up 12 -1/4" bit, 8" Sperry Drill, float sub, pony collar, fill riser and check for leaks. Ream and wash from 58 - 110' with 400 gpm and 40 rpm. Pull back to surface, drain motor, install MWD probe and orient motor. Ream and wash from 110' to 153' at 467 gpm and 42 rpm. ' Drill 12 -1/4" hole from 153' to 199'. Note: Base of 16" Conductor at 153'. Halliburton CCU lines plugged, clear same. ' 19 Feb 2008 Clear CCU cuttings Line - backed up. Drill 12 -1/4" hole from 199 to 292'. POOH from 292' to 92'. Pick up the rest of BHA #1 components, add MWD, scribe and load EM probe. RIH to 292' without incidents. Drill 12 -1/4" hole from 292 to 463'. Run gyro survey and directional drill 12 1/4" from 463' to 1745'. 20 Feb 2008 Directional drill 12 -1/4" hole from 1,745' to 3090'. Maintain sweep program per Bariod recommendations. ' Trouble shoot MWD tools while circulating. Reset MWD tool and run MAD pass from 3,090' to 3,121' at 150 ft/hr. Directional drill 12 -1/4" from 3,121' to 3,183'. Circulate and condition mud, pumped 60 bbls weighted HiVis sweep with 20 sacks medium nut plug surface to surface at 750 gpm and 90 rpm. No visual t indication of nut plug returns to shaker. Short trip from 3,183' to 2,860'. Note: Tight spots at 3005' — 30 klbs, 2,948' — 25 klbs, 2,940' — 30 klbs, 2,925' —15 klbs and 2,860' — 25 klbs. Encountered problems with trip tank not functioning properly due to plugged lines. 21 Feb 2008 Pull out of hole from 2,860' - 218' — top of jars. A number of tight spots were encountered on the trip out ' ranging from 15 to 30 klbs overpull. All tight spots were worked through and usually cleaned up after being worked once. Run in hole from 218' - 3,136'. Work through tight spots at 1,687' - 1,985' with 250 gpm flow and 1 - 5 klbs WOB, 560 psi and 40 - 50 rpm. At 1,985' appeared to break up clay ball and enabled trip to ' continue from 1,985' - 3,136' without further incidents. Stage up pumps to 740 gpm and 3,211 psi - no losses. Reciprocate pipe at 90 rpm, rotating hook weight of 120 ldbs. Pump 50 bbl weighted walnut sweep surface to surface — hole appeared clean. Check flow — static. Blow down top drive and trip out from 3,183' to ' 2,880'. Pull 30 klbs over at 2,944' and slight swabbing — worked through area to clear tight hole. Continue trip out of hole. Lay down 12 -1/4" directional BHA #1. Note: stabilizers and bit balled up with clay. Clear all 8" handling tools and clean rig floor. Rig up 9 5/8" casing running tools. Made up 9 5/8" shoe joint and intermediate joint, Baker locked threads and circulated through float shoe. 1 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' 22 Feb 2008 Run 9 5/8" 40 #, L -80 casing from 85' to 2,920' with no problems. Run casing and work through tight spot from 2,920' to 2,925'. Wash down at 1 bbls /min and 350 psi, continue to trip in to 3,179'. Work through tight ' spots at 2,972', 2,985'. Pick up landing joint and hanger, land casing at 3,172'. Lay down Franks fill up tool and make up Halliburton cement head. Stage pumps up to 10 bbls /min and 2,650 psi with no losses. Circulate one casing volume. Rig up cement lines and cement as per program. Bump plug with 500 psi over 1150 psi at 12:05 hrs. Bled off at 12:08 hrs and checked floats - OK. Rig down cementing equipment. Make up jetting sub, flush diverter and riser with water and cement inhibitor. Nipple down diverter system, riser and knife valve. Remove starter head. 23 Feb 2008 Install Vetco Gray M -233 well head. Encountered problem achieving test. Remove well head and change out pinched bottom "0" ring. Steam inside area and re- install well head with fresh "0" ring - test to 5,000 psi without incidents. Nipple up BOP's and test as per program. Slip and cut drill line. Pick up BHA #2. Down load MWD tools. Perform shallow test at 450 gpm, 600 psi, check Geo Span - OK. ' 24 Feb 2008 Make up BHA including Nucke sources and run in hole to 765'. Pick up 60 joints of drill pipe while running in hole to 2,616' and fill pipe. Service top drive and change out saver sub. Run in hole and tag float collar at ' 3,087'. Pick up and break in seals on Geo Pilot. Drill out cement plugs and float collar to 3,088' and displace fluid to 8.8ppg water based mud. Drill cement from 3,088 to 3,092' at 540gpm, 1,900 psi, 80 rpm and 5 to 25 klbs wob. Change top drive gripper dies and continue drilling out cement to 3,161' with 540gpm, 1,900 psi, ' 80 rpm and 3 to 5 klbs wob. Circulate bottoms up prior to casing test and prepare test equipment for same. Rig up and test caing. Test failed. Surface equipment was tested and all tested good. Halliburton equipment was used to perform second test while watching mud pump discharge valves with same results. Mix and pump slug and pull out of hole and rack back heavy weight drill pipe, flex collars, lay down 2 ghost reamers and Geo Pilot. 25 Feb 2008 Recover and lay down nuclear sources from rig floor. Lay down stabilizers, float shoe and bit. Rack back MWD and Geo Pilot. Pick up RTTS packer and CV. Run in hole with BHA #3 to 3078'. Break circulation and set RTTS packer. Shut in top pipe rams and open kill line. Test casing as per program with 3500 psi with 1.47% change in 30 minutes. Pressure bled off and packer was unseated. Pull 3 stands out of hole and pump dry job before pulling packer out of hole. Make up BHA #4 and Geo Pilot. Pick up TM HOC stabs and float sub. Pick up BHA, install battery and upload MWD tools. Perform shallow test at 450 gpm and 800 psi. Load sources, pick up one stand of flex collars, five stands of heavy weight drill pipe and jars. Run in hole with 4" drill pipe to 3160'. Drill cement and float shoe from 3,163' to 3,173'. Ream and wash rat hole from 3,173' to 3,183'. Directional drill 8 -3/4" hole from 3,183' to 3,196'. Ream and work pipe to clear ' obstruction, well was packing off in rat hole area with cement chunks. 26 Feb 2008 Directional drill 8 -3/4" hole from 3,196' to 3,203' and circulate prior to leak off test and rig up test equipment. Perform leak off test wuth 8.8 ppg MW = to 1060 psi break over point = 15.45 ppg EMW. Rig down test equipment. Directional drill 8 -3/4" hole from 3,203' to 4,064'. Geo Pilot experiencing roll and hooking up issues until 3,900' to 4,000' MD. Trouble shoot mode switch on MWD tools. Shaker screens were changed. Continue drilling to 4,821' with continued roll and hooking issues through softer formations. Experienced pack off with large shale samples to surface from this zone at approximately 4,809'. An increase of gas was detected up to 585 units correlating with the disposal well at the same TVD. 2 1 ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' 27 Feb 2008 Directional drill 8 -3/4" hole from 4,821' to 6,500'. Build hole angle from 58° to 66° and azimuth of + -280° to 5,670', and maintain hole angle at + -67 °. Observed a gas peak of 746 units in the Torok sand from 6,478 to 6,482' 28 Feb 2008 Directional drill 8 -3/4" hole from 6,500' to 8,034'. Maintain hole angle at + -67° and modify direction from 67° to 194 °. Gas peaks in the Torok sands were observed between 6,650- 6,720' = 593 units, 6,720- 6,840' = 779 units and 6,910- 6,940' = 1190 units. 1 29 Feb 2008 Change swab and liner in #1 pump. Directional drill 8-3/4" hole from 8,034' to 8,491' and start weighting up mud from 9.8 to 10.6 ppg at 8,200'. Work tight spot from 8,491' to 8,461' after pump #1 blower failed. Circulate off bottom 20 feet, rotary stalled out and well packed off. Work pipe for 6 hours from 8,477' to 8,461' and finally jar free. Cirulate and condition mud. MWD performed a check shot at 8,377' to verify tool was still operational. Eqivelent circulating density increases to 12.0 ppg were observed on that stand. Back ' ream from 8,377' to 7,814' with steady flow of cutting returns to shakers with some large clay balls. Occasional torque spikes were seen in the tight spots at 8,240' and 7,830'. ' 01 Mar 2008 Finished short trip to 6,640' and work through tight sections at 7,729', 7,660' and 7,565' using 30 klbs over pull without pumping. Trip in hole from 6,640' to 8,113'. Ream and wash from 8,313' to 8,491'. Ream ' obstructions from 8,474' to 8,484' with 0 - 10 klbs wob, 150 rpm and 470 gpm. Circulate and condition hole at 8491' with high gas peak of 758 units. A 30 bbl, 13.0 ppg high viscosity pill with 10 ppb walnut was pumped surface to surface. MWD experienced communication problems and a 30 bbl fresh water pill was ' pumped to clear possible debris without success. Pull out of hole from 8,491' to 8,023', pump slug and pull to 6,478'. Circulate and condition hole while trouble shooting MWD tools again without gaining communication. Pull out of hole from 6,478' to 6,37' and lay down ghost reamers. Lay down BHA, rack back heavy weight drill pipe, lay down jars, remove nuclear sources, down load MWD tools and clean up balled up stabilizers. The remaining BHA, subs, MWD tools, bit and Geo Pilot were layed down. Three rocks were found in the pulser poppit of the MWD tool, which was determined to be the source of the tool ' communication failure. 02 Mar 2008 Finish laying down BHA. Test BOP's per program. Slip and cut drill line, service top drive and perform post 1 jarring inspection. Run in hole with BHA #5. Trip in hole on drill pipe and pick up ghost reamers. 03 Mar 2008 Trip in hole from 5995' to 8400'. Wash and ream from 8,400' to 8,491' with no fill. Circulate and condition hole. - maximum trip gas 1,440 units. Directional drill 8-3/4" hole from 8,491' to 9,029'. Build hole angle from 68° to 75 °, starting at 8,859'. Turn well from an azimuth of 176° to 155 °. 04 Mar 2008 Directional drill 8-3/4" hole from 9,029' to 9,199'. Circulate and condition hole and run check trip from 9199' to 8,990' - pull 160 klbs over and 50 klbs down. Maximum trip gas 1055 /241 units. Directional drill 8-3/4" hole from 9,199' to 9,471'. Connection gas ranged from 500 to 800 units above an average background of 330 units. Hole angle was built to 80° at 9,245' and maintained, with direction going from 150° to 135 °. 1 3 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 I 05 Mar 2008 Directional drill 8 -3/4" hole from 9,471' to 9,682'. Circulate bottoms up and work pipe. Directional drill 8- 3/4" hole from 9,682' to 9,705'. Circulate bottoms up and work pipe. Directional drill 8 -3/4" hole from 9,705' to 9,730' - section TD. Circulate and condition hole. Back ream from 9,730' to 9,374', change I parameters as hole dictates. Pack offs and mechanical sticking were main problem since leaving bottom. Maximum gas while reaming 2488 units 1 06 Mar 2008 Back ream from 9,374' to 7,926', stopping to circulate and condition hole at 8,312' and 7,926'. Continue pulling out of hole and backreaming when problem sections are encountered. Most significant sticking I occurred when the top ghost reamer was exiting the turn at 7,200'. Maximum gas while reaming ranged from 700 to 1500 units. I 07 Mar 2008 Back ream and pull out of hole as hole dictates from 6,960' to 5,899'. Pull into a tight section at 5,899' pulling 60 klbs over and jar both up and down while maintaining full circulation. Maximum overpull of 250 I klbs over, work pipe free at 5,839'. Continue backreaming from 5,839' to 5,250'. An attempt to pull a single stand without backreaming failed when a tight section was encountered at 5,250', pull 60 klbs over and start jarring pipe both up and down with a maximum overpull of 175 klbs. Maintain full circulation and work pipe I free at 5,190'. Backreaming resumed from 5,190' to 4,800' and the decision was made to ream back to the shoe. Background gas ranged from 40 to occasionally 200 units. I 08 Mar 2008 Back ream from 4,800' to 3,165' with tight hole sections. Note: background gas ranged from an average of 100 units occasionally peaking at 400 -500 units. Circulate and rotate back up to the shoe, observed increased cuttings load over the shakers at bottoms up. Continue to pull out of hole from 3,165' to 670'. Rack back, I download MWD tools and lay down Geo Pilot, neutron tools and sources, 3 each, stabilizers and bit. Conduct full derrick inspection after jarring. Remove broken link tilt limit switch from the derrick. Tighten I bolts on draw works, cement lines and grating. Check dead man bolts and hookload sensor gap. Service top drive, change out gripper dies and oil filter. Follow up with changing out the saver sub. I 09 Mar 2008 Finish servicing rig post jarring operations. Pick up new BHA and MWD tools. Encounter problem inserting programming cable into the MWD tools. Make up 1 stand of flex collars, welded blade stabilizers, cross over sub and 1 stand of heavy weight drill pipe. Continue to run in hole with remaining BHA to 1295'. I Adjust back up wrench on pipe handler and continue to run in hole to 3,104'. Circulate at the shoe with 250 gpm at 600 psi. Run in hole on elevators from 3,104' to 8,424', washing down every 10 stand. Wash and ream from 8,424' to 8,850' with 435 gpm at 120 rpm. Working through tight sections from 8850' to 8884'. 1 Maximum overpull observed was 120 klbs and jarring was not necessary. Continue to work pipe free and work through tight section several times. Pick up new stand and wash and ream to 8919' when it torqued up. Jarring commenced through the tight section from 8,900' to 8,919'. Maximum overpull observed was 270 I klbs. Pipe came free and one stand was stood back followed by pulling a single and an attempt to work through 8,900' to 8,919'. High torque and packing off continued causing problems in this section. Gas ranged from 400 to 1700 units while reaming. 1 10 Mar 2008 Back ream from 8,900' to 8,696', circulate and build mud weight from 11.0 ppg to 11.5 ppg. Work on frozen I mud lines from HOC — RSC. Circulate and reciprocate pipe while building mud weight. Wash and ream from 8607' to 8903'. Jar through tight sections at 8,930' with 350 klbs overpull. Different combinations were tried to free the pipe from 8,920' to 8,867' with maximum pick up weights of 350 klbs. Pipe came free and pulled up to 8805'. A consultation was made with the office and the decision was made to raise the pump 4 1 ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' rate to 500 gpm with 150 rpm and slowly wash and ream from 8,805' to 8,836' whith a maximum gas peak of 8,060 units. ' 11 Mar 2008 Wash and ream from 8,830' to 8,861' hitting high torque spikes at 8,835' and 8,839'. Mud weight in 11.5 ppg, 500 gpm and 150 rpm observed. Stalling and packing off occurred at 8,861'. Circulation was regained and the pipe was jarred free with 350 klbs over pull. Back ream to 8835' while working through tight hole sections. Continued back reaming from 8,835' to 8,704'. Lay down 2 singles, circulate and weight up mud from 11.5 to 12.0 ppg. Wash and ream from 8,704' to 9,008'. Ream at 2' per minute for 32', then back ream the same 32' section and log any changes in parameters and continue with another 32' section using 500gpm, 150 rpm and a mud weight of 12.0 ppg. Note: tight sections were observed at ,8811', 8,952' and 9,001'. 12 Mar 2008 Wash and ream from 9,008' to 9,038' with tight sections encountered at 9,012', 9,017' and 9,029'. Pipe stalled out and packed off at 9,038'. The pipe was worked free and the section was reworked. Washing and reaming continued through to 9,220' while increasing reaming speed to 3' per minute with good hole conditions. Wash and ream from 9,220' to 9,383' working tight sections from 9,345' to 9,330'. Continue reaming at 2' per minute for 32', back ream the same 32' and log any change in parameters. Ream the next 32' section using 500 gpm and 150 rpm. 13 Mar 2008 Wash and ream from 9,348' to 9,453'. Tight hole at 9,388', 9,398' and 9,409'. Wash and ream at 9,453'. Start ' taking weight, pick up and work pipe at 9438' and pipe stalled out and packed off. Pulled pipe free and rework section down to 9,440'. Re -ream section from 9440' to 9,453'. Wash and ream from 9,453' to 9,707'. Hit refusal at 9,707'. Contact office about drilling back to 9,730' - desision made to stop and not expose lower zones to the 12.5 mud weight. 14 Mar 2008 ' Ream and wash to 9,707'. Circulate two bottoms up while reciprocating drill string from 9,707' to 9,669'. Shakers were clean and hole appeared to be in good shape. Pull out of hole from 9,707 to 8,250' on elevators with no problems. Trip in hole from 8,250' to 9,280' where hole took 2 -3 bbl loss due to surged formation. Wash from 9,280' to 9,707'. Circulate and displace hole to fresh 12.5 ppg mud. Pull out of hole wet from 9,707' to 5,130' - no tight spots encountered. 15 Mar 2008 Pull out of hole with BHA #6 from 5,132' to surface. Found last joint of DP had missing bottom tool joint and 15" of tube, along with remainder of assembly components left down hole, (BHA = 595'). Lay down last joint of DP out of hole with missing bottom tool joint and 2x DP from stand. Lay down 7" casing running equipment. Test BOP's as per program. Make up 320' fishing BHA as per Baker. 16 Mar 2008 ' Run in hole with BHA #7 at controlled rate of 120 -130 fpm, to avoid surging and plugging pack off on overshot, 324 - 6,826'. Fill pipe every 4 -10 stands. At 6,826', assembly saw 20 -30 klbs down weight. Work tight hole from 6,826 to 6,890' with 200 gpm flow rate and 590 psi. Had to jar up twice with 250 klbs and ' 325 klbs. Establish rotation with 10 rpm (3 -6 ft -klbs troque), but can not go down. Pull up from 6,890' to 6,788'. Appered something had fallen in beside assembly. Pull 30 -70 klbs over without jarring and pipe pulled free. Run in hole from 6,788- 7,000' where differential sticking problems occurred. Work through ' sticking problem to 7,094'. Run in hole from 7,094' to 7,566'. Spot lost circulation material across BHA to top of Torok formation. Run in hole from 7,566' to 8,435'. Note: no differential sticking seen after 7,900'. Fill pipe every 3-4 stands. Wash from 8,435' to 8,842'. Note: top of fish at 8842 and bottom of fish at 9,438'. Swallow fish from 8,842' to 8,844' with 10 rpm and 4 -6 ft -klbs rotary torque and 20 -30 klbs down weight. 5 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 See pressure increase with 1.25 bbls /min flow rate to 1450 psi, shut off pump, but pressure bleeding slightly. Establish circulation with 2.5 bbls /min and 480 psi. Pull to 235 klbs and bleed off hydraulic jar. Pull to 250 klbs with 4.2 bbls/min and 600 psi and weight bled off 10 — 15 klbs with slight movement observed. Continue to pull 250 — 325 klbs and allow to bleed off weight with movement seen 8,844' to 8,770'. Pull steady from 8,777' to 8,727' (180- 275 -325 klbs pulled, without jarring). Pump out of hole from 8,727' to 8,546'. Pump at 175 gpm with 500 psi. Pipe pulling good. Hole looking good screw into pipe with top drive /no circulation and pull from 8,546' to 8,258' - no problems. Hole looking good, trip out on elevators from 8,258' to 7,985'. At 7,980' pipe was pulled into a tight spot. Work tight spot at 7,980. Circulation good with no pack -offs, jars not firing on fishing assembly. Note: Fishing assembly may be differentially stuck not allowing jars to function. Work pipe pulling up to 400 klbs and slacking off to 40 klbs. 17 Mar 2008 Work differentially stuck pipe at 7,976' and unable to fire jar up or down. Circ at 280 gpm and 1,640 psi. Mix lube pill in pits and attempt to fire jar pulling 475 klbs. Continue to experience differential sticking problem. Spot 3x lube pills around BHA's and continue to slump down to 45 klbs and pull at 475 klbs. Decision made by Town ODE /Rig team to mix Black Magic pill per Baroid Mud Man. Continue to torque and slump down with 5 -12 ft -klbs torque and slump down to 45 klbs string weight. Criculate at 120 gpm and 440 psi. Spot 40 bbls diesel pill around BHA while holding 12 ft -klbs torque and slump with 45 klbs string weight. Hold 12 ft -klbs torque and slump with 45 klbs string weight. Pump 4 bbls /15 min to keep from ' freezing top drive. Unable to see any movement or indication of pipe coming free. Continue to pull up to 200 -225 klbs and torque of 12.5 ft -klbs torque and down to 45 klbs string weight, while circulating bottoms up to clear 40 bbl diesel pill in well bore. Take on 48 bbls diesel in pits, along with 80 bbls Black Magic Pill from RSC. Capture diesel spacer from well bore in trip tank. Pump 48 bbls diesel spacer, 80 bbls Black Magic Pill, 5 bbls diesel and displace with 62 bbls mud. Torque with 15 ft -klbs and slump with 45 klbs string weight. Let pipe sit still and soak with Black Magic. Move 1 bbl every hour with 40 klbs down weight ' and 15 ft -klbs torque, observe pipe for any movement down. 18 Mar 2008 ' Let Black Magic pill soak and sit with 41 klbs string weight and 15 ft -klbs rotary torque. Work pipe every 1- 2 hrs with torque slump down with 15 -20 ft -klbs torque. Pump 1 bbl pill per hr, per procedure. Unable to achieve any indication of movement. Attempt to circulate at 1 bbl/hr spotting and discovered stand pipe froze up and unable to circulate. Unthawing stand pipe and kelly hose, (had to remove Kelly hose thaw and ' re- install same. Work stuck pipe from 250 to 565 klbs pull with 15 ft -klbs torque applied. Establish circulation at 3 bbl /min - no movement. Start working torque in pipe and work pipe as per schedule of 20 ft- klbs torque and 428 klbs pull, 15 ft -klbs torque /467 klbs pull, 5 ft -klbs torque /506 klbs pull. At 23:15 hours jars started working. Jar pipe with 20 ft -klbs torque and 428 klbs pull. 19 Mar 2008 1 Continue working pipe as per schedule. Unable to activate jars, Daily or Bowen , to fire in either direction. Circulate bottoms up at 10 spm and 102 psi. Continue various torque and slump, slacking off to top drive weight of 41 klbs and 5 -20 ft -klbs torque. Follow schedule for upward attempts, all without success. ' Decision made by Town ODE to run cement plug back, per agreement with AOGCC. Unable to cement due to Solar Turbines shutting down. Switch rig to Gen -set while down. RSC unable to power HES pumps. Sort out issues, after Solar Turbines unable to load share with two Turbines on line. Switch rig back to Solar ' Turbine power. RSC re- booted and ensure water lines, sea water and potable in operation. Pump 2 -4 bbls 12.5 ppg spacer and test cement lines to 4,500 psi. Continue to pump spacer with HES pump for total of 25 bbls, followed by 39 bbls 12.5 ppg cement (Neat) and 5 bbls spacer. Chase with 65 bbls mud at average 4.0 - 1 4.5 bbls /min and 960 psi, (1250 psi when cement went thru tools). Blow down cement lines from rig to RSC. Rig down cement head pin and valve. Perform zonal derrick inspection, due to all the jarring/tight hole experienced — OK. Pick up collar locator and free point tools. Run freepoint tool with Schlumberger. Pipe 85% free at 6,960- 6,940'. Collar locator showed tool joint at 6,920'. Pull out and lay down free point tool. 6 1 ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' 20 Mar 2008 No chemical cutter available, severing tool arrived on location at 05:03 am. Unload and re -head wire line with correct rope socket. Piece together severing tool per Schlumberger Operator on location. Rig up and ' run severing tool, sever pipe at 6,920'. Retrieve severing tool. Pull four stands. Circulate bottoms up with maximum gas of 247 units. Pull out of hole breaking, cleaning, inspecting each break with Tuboscope personnel. Re -dope and torque each connection. Attempt to repair lifting cylinder on iron rough neck — no. success. Continue to trip out as before and again install new lifting cylinder for Iron Roughneck. 1 1 1 r 1 7 1 ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Oooguruk ODSK -33 21 Mar 2008 Pull out of hole, break each connection, clean and inspect by Tuboscope personnel. Re -dope and torque to 22.4 k ft#s per Nabors policy. Lay down total of 9 joints for tool marks on face. Found 7 gallons hydraulic spill in BOP area from air hoist. Shut down, clean up spill and replace hoist. Pull out of hole as before. Note: joint #217 had galled threads from being broken off during back off attempt and joint #218 damaged due to pin being severed with 1 7/8" explosive charge. Make up cement diverter sub and trip in to 2,900'. Cut and slip drill line and repair Iron Rough Neck. Run in hole fom 2,900' to 6,920'. Spot 12 bbls 17.0 ppg, HiVis mud at 6,920' - top of fish. Rack back one stand and lay down 1 single to put pipe at 6,820'. Circulate and condition mud to balanced mud weight in and out. 22 Mar 2008 Finish circulating balanced mud. Rig up and pump cement plug. Pull out of hole slowly from 6,820' to +/- 6,100'. Note: Encountered tight spot at 6,678' with 25 klbs over pull and 6,345' with 50 klbs over pull. Circulate bottoms up at 500 gpm and 2,700 psi. Rotate 120 rpm on top drive and reciprocate pipe constantly. Shut down pump and check for flow - static. Pull out of hole with cement string and lay down same. Note: Pulled 100 klbs over at 5,470'. Test BOP's per program. Make up 8 -3/4 ", 1 1/2° bent housing motor side track assembly, load MWD /LWD equipment and pick up BHA #8. Pick up 14 joints HWDP and drilling jars. Pick up 15 joints 4" S -135 drill pipe from pipe shed andrun in hole to 2,570'. 03/23/2008 Run in hole from 2,570' to 5,380'. Encountered slight bridge at 5,380'. Ream/wash from 5,380 to 6,232' and tag cement. Abundant filter cake based material observed at shaker from 5,380' to 5,490'. At 5,490', 20' of solid ream with 15 klbs on bit and wash down from 5,510 to 6,232', where initial cement tagged. Wash/ream cement from 6,232 to 6,480' where very hard cement encountered. Polish cement to 6,527', where side track well bore kicked off. Time drill 8 -3/4" hole from 6,527 to 6,532' at 1.5 min/in 10 -15% cuttings. Continue to time drill from 6,532 to 6,539' at 1 min/inch and sample indicated 50 -60% formation. Appeared to be kicked off from cement plug. Directional drill 8-3/4" hole from 6,539 to 6,575' - all indications showed assembly off plug. Directional drill 8 -3/4" hole from 6,575 to 7,002'. Note: intermittent pump problems, therefore circulate while repairing pumps. 03/24/2008 Continue to repair wash in middle module discharge port #1 mud pump. Circulate with #2 mud pump 115 spm, 2,800 psi, 400 gpm and reciprocate pipe. Directional drill 8 -3/4" hole from 7,002 to 7,299'. Note: Experienced 2.0 hrs mud pump trouble while drilling ahead. Directional drill 8-3/4" hole from 7,299' to i 7,560'. 03/25/2008 Directional drill 8-3/4" hole from 7,560' to 7,782'. Encountered hard streak at 7,680' and performed a 200 bbl ' dilution at 7,742'. Directional drill 8 -3/4" hole from 7,782' to 7,933'. Note: drill with 1 pump intermitantly. 03/26/2008 Directional drill 8 -3/4" hole from 7,933' to 8,190'. Enountered a hard streak/bit balling at 8,190' and decision made to stop drilling and circulate bottoms up for BHA change. Circulated three bottoms up. Pump High Vis/Nut plug sweep that showed little indication of cutting increase. Blow down top drive and monitor well ' for 10 mins - static. Dress side track area from 6,575 to 6,527' - wash and ream through while pumping out. Make attempt to pull out of hole on elevators from 6,427 to 6,381' with 40 -80 klbs over and swabbing, (this was to see if previous pump out section was due to dog legs and/or cutting bed buildup at side track), but indications showed formation. Unable to trip on elevators. Decision was made to continue pumping out, and 8 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 back ream as necessary. Pull out of hole with BHA #8, pumping out of the hole and back reaming as necessary from 6,427' to 5,837'. Multiple tight spots with some stalling. Steady cuttings and wall cake returns at shale shaker. Pulled into tight spot at 23:50 hrs at 5,837' with 50 kbs over and 15 kbs down. Work 1 to free pipe with full returns. 03/27/2008 Continue to work tight hole at 5837' with 5 -22 k ft #s torque and slumping with 60 klbs down. Finally able to fire jar down and free up, (had full returns). Continue to pump and back ream out of well bore, but unable to pull without reaming from 5,838 to 3,236'. Pull out of hole without rotation into casing shoe at 3,173'. Once inside casing at 3,138' switched rig back to Sola power. Circulate 2 bottoms up to clean up inside casing, (unloaded large amount of clays and some cement). Once hole appeared clean, pumped dry job and monitor well — static. Pull out of hole and rack back 4" DP, HWDP, jars and flex collars. Down load MWD. Break and lay down bit. Install pad eyes at skate area to tail BHA components into rotary area safely. Pick up BHA #9 per Sperry directional driller and MWD. Pick up and load MWD. Break and install gasket in leaking rig mud line. Test MWD - good test. Run in hole with HWDP and jars. Run in hole on 4" DP to 2050'. 03/28/2008 Trip in hole from 2,050' to 3,152'. Circulate bottoms up, break in Geo- Pilot. Trip in hole from 3152' to 7012'. Fill pipe every 30 stands. Tagged obstruction at 7012'. Wash and ream from 7,012' to 8,190'. Attempted to trip in hole at 7,200', tagged second obstruction in hole previously tripped on elevators on trip out of hole. Directional drill 8 -3/4" hole with Geo -Pilot per Sperry Directional Driller from 8,190' to 8,617'. 03/29/2008 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry Directional Driller from 8,617' to 9,265'. 03/30/2008 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry Directional Driller from 9,265' to 9,535'. 03/31/2008 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry Directional Driller from 9,718' to 9,808' MD. Circulate and condition mud. Observed 10 barrels loss, flow check, well static. Balance mud weight in and out to 12.5 ppg. Circulate four bottoms up. Pull out of hole on elevators from 9,808' to 9,711', 30 kis over pull. Pump out from 9,715' to 9,614'. Had 75 klbs over pull, therefore ream back to 9,715'. Back ream from 9,711' to 9,425'. Ream in hole from 9,425' to 9,808'. Check surface equipment for wash out, surface equipment OK, pressure loss down hole. Back ream from 9,808' to 8,653'. Attempt to pull each stand without circulating, then pump with 1000 psi and 77 spm, 275 gpm, then add 60 prm. Pull out of hole on elevators from 8,653' to 7,818'. Tight hole at 8,200'. Work to pass tight spot at 7,818' and work up to 7,814'. Make up top drive, break connection and wash through to 7,810'. 04/01/2008 Wash and back ream as necessary to pull out of hole from 7,822' to 7,784'. Pull on elevators from 7,784' to ' 6,855'. Numerous tight hole between 7,746' to 7,592'. Normal pick up weight 175 — 200 klbs from 7,494' to 6,855'. Tight spot at 6,855' - work free. Wash and ream from 6,855' to 6,815'. Pull on elevators from 6815' to 6,750'. Up weight 200k - well swabbing. Pump out from 6,769' to 6,690'. Tight spot at 6690', therefore wash and ream from 6,690' to 6,225'. Stalled top drive at 6,225' with 15 k ftlbs torq, work free, when working down and ratating at 100 rpm hookload was 25 klbs less than normal with 100 psi pressure drop. Pull out of hole on elevators and noted that 2,025.96' of drill pipe and BHA left in hole. Drill pipe left in hole 14 stands and 1 single. Estimated top of fish at 4199'. Test BOPs.. Slip and cut drill line. 9 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 04/02/2008 Service top drive and crown. Pick up fishing BHA. Pick up new 4" drill pipe from 327' to 4,187'. Drift each joint to 2.36 ". Wash Down from 4,187' to 4,216'. Tag fish at 4,216' and set 25 klbs down weight. Observed 500 psi increase when fish engaged. Pull 95 klbs over and start working and jarring. Jarred fish from 4,216' to 4,163'. Pump from 121 to 500 gpm. Hole packing off. Lost fish when Grapple slipped. Attempt to re- engage fish, no luck pull out of hole from 4,163' to 326'. Break down grapple and inspect. Grapple showed no unusual wear other than outside diameter of fish may be smaller due to wear. Change out pack -off due to wear. Conduct a post jarring inspection of Derrick. 04/03/2008 1 Make up fishing BHA and run in hole to 357'. Run in hole from 367' to 4,121'. Found leak on Standpipe hammer union, repair and test to 2500 psi. Start washing down from 4,121' to 4,163' where fish was tagged. Chase fish from 4,163' to 4,266' where pump pressure increased 400 psi. Circulate at 266 gpm with 1350 psi pump pressure. Jar Down with no success, jar up and pull to 315 klbs - fish came free. Pump out of hole with fish from 6,189' to 4,603'. Trip out of hole on elevators from 4,603' to 3,154'. Circulate bottoms up at the shoe. Pull out of hole from 3,154' to top of fish at 2,382'. Lay out fishing BHA from 2,382' to 1,993'. Lay out drill pipe from 1,993' to 642'. Lay out BHA and rack back 5 stands of HWDP and jars. Down load MWD. ' 04/04/2008 Lay down BHA #9, take pictures of Geo Pilot, clean off and check oil. Run in hole with three stands of 6- 1/4" spiral drill collars and lay out same. Lay down 4" drill pipe. Note check torque on random connections. 1 04/05/2008 Pick up rabbit and measure new 4" drill pipe and run in hole to 3,090'. Circulate one drill pipe volume. Pull out of hole and rack back 32 stands of 4" drill pipe. Pick up new BHA and run in hole picking up 4" drill pipe to a depth of 1,560'. Lay out 28 joints of 4" drill pipe. Pump one drill pipe volume. Run in hole on elevators from 2,912' to 8,505' and started to take weight. Several tight spots were encountered, but picked up up pipe and worked back through. Tight spots encountered at 4,784', 5,319', 6,865', 7,200' through to 7,360' and 8,241' to 8,478'. Circulate and condition mud at 355 gpm with 2200 psi pump pressure. Wash and ream from 8,505' to 8,600' with 80 rpm, 6 ft -klbs torque, 290 gpm and 1350 psi pump pressure.. 1 04/06/2008 Run in hole on elevators from 8,600' to 8,700'. Pump from 8,700' to 8,800', 8,800' to 8,993'. Run in hole on elevators. Wash and ream from 8,993' to 9,210' and encountered pack off problems and high torque. Back ream up to 9,090' and stage pump up to 425 gpm with 3050 psi. Fighting tight hole and stage pumps as hole allows. Wash and ream from 9,090' to 9,270' at 415 gpm with 2,780 psi pump pressure. Wash and ream from 9,270 to 9,275, torqued up and packed off. Pick up single and work pipe free - max pull 350 klbs. Circulate and rotate from 9,275' to 9,238'. Stage pumps to 415 gpm and 3030 psi. Wash and ream from 9,238' to 9,764'. Hit hard spots at 9,535 and 9,540'. Note: Prepare to dilute old mud with 500 bbls of new mud prior to wiper trip. 1 04/07/2008 Wash and ream from 9,669' to 9,808'. Stage pumps up to 520 gpm andt 4450 psi. Start mud dilution with 500 bbls of new 12.5 ppg mud. Circulate and condition mud. Work pipe from 9,808' to 9,725'. Rotate at 160 rpm and circulate at 520 gpm. Work pipe from 9,765' to 9,669'. Slow pump to 175 gpm and change shaker screens due to mud losses over the shakers. Circulate and condition mud from 9,765 to 9,669' at 500 gpm and rotating at 130 rpm. Pull short trip from 9,669 to 8,525'. Tight spots at 9,390 and 8,868' with 65 klbs overpull. Run in hole from 8,525' to 9,808'. Wash tight hole at 9,115'. Circulate and condition mud at 500 gpm with 160 rpm. Dilute mud with second 500 bbls of new mud. Stand back one stand every hour to prevent undercutting hole. Spot 35 bbl LCM pill on bottom. Pull out of hole from 9,808 to 6,050'. Hit tight 10 ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 spots at 9,570', 8,450', 7,943' (pumped at 213 gpm to get by this spot) and 6,650. Pull out of hole to 6,050' where pipe very tight with maximum over pull 60 klbs. Wash and ream from 6,050' to 6,029'. Swab on #1 mud pump out. Circulate with 1 mud pump. 04/08/2008 Wash and ream tight spot at 6,004' to 5,942' at 390 gpm, 2011 psi and 120 rpm. Try pulling with no pumps at 5,942 pull 60 klbs over. Back ream from 5,904' to 4,553' pumping at 550 gpm, 3,490 psi and 120 rpm. Pump r out of hole with no rotation from 4,553 to 4,264' using 550 gpm & 3,350 psi pump pressure. Pull out of hole on elevators from 4,264 to 598'. Stand back 4 stands of heavy weight drill pipe, lay down 2 heavy weight drill pipe and jars, flex drill collar and MWD. Change rams from 4" to 7 ". Test BOP's. 04/09/2008 Finish testing BOP's. Rig up to run 7" casing. Run in hole with 7" casing to 9741'. ' 04/10/2008 Run in hole and land casing in wellhead, with shoe at 9,793'. Stage pumps up to 4 bbls /min, 690 psi and circulate bottoms up. Rig down Franks fill up tool and rig up HES cementing head. Run cement job as per program. Line up rig pumps and displace with 363 bbls of mud. Plug did not bump but float holding. Estimated 2 bbls of cement on top of plug. Lay down casing equipment and rig down cement lines. Test 7" ' wellhead packoff to 5000 psi and held for 10 min. Change upper rams from 7" to 4 ". Test BOP's. Work on Iron roughneck, repair broken plate. Re- arrange pipe shed by moving MWD tools to rear and continue trouble shooting MWD tools. Move 4" DP to front in order to start picking up same. Lay down three joints of heavy weight drill pipe from derrick. 04/11/2008 Pull out of hole and lay down heavy weight drill pipe. Pick up 180 joints of 4" drill pipe from pipe shed and single in hole to +1- 5,800'. Circulate drill pipe volume plus 60 bbls. Pull out of hole with 4" drill pipe and rack back on Drillers side of derrick. Pick up BHA # 13 and all related pieces. Test MWD /LWD and Geo- I Pilot at 300 gpm with 1,900 psi - tools tested OK. Pick up remaining tools of BHA # 13 and load nuke sources. 04/12/2008 Continue to load nuke sources into LWD tool. Shallow pulse test MWD — OK. Found wash pipe on top drive was leaking. Repair crossover swivel wash pipe assembly on Can Rig top drive. Perform Sim -Op's while working on wash pipe unit and freeze protect 7" x 9 -5/8" casing annulus. Tested lines to 1,000 psi and pumped 10 bbls of 12.5 ppg mud with 300 psi pressure increase. Switched to diesel and pumped a total of 85 bbls, with initial injection pressure of 350 psi and final injection pressure of 850 psi. Final reading on casing annulus when shut in 1,150 psi. Rig down injection lines and equipment. Continue to run in hole with BHA #13. Assembly started to encounter some drag down of 5 -10 klbs at 9,436' and the decision was made to wash down to top of plug rubber. Wash and ream from 9,436' to 9,682' where plug rubber was encountered. Note: slight cement across shakers seen at bottoms up. Rig to and attempt to get 3,500 psi casing test. Unable to maintain satisfactory decline. Surface check both stand pipe system/kill line system, which confirm both were not leaking or suspect of possible pressure loss. Rig up ported sub to drill pipe stump and install TIW valve on top. Pressure up again to 3,500psi, close TIW valve and 4" valve on standpipe line. Again, unable to get satisfactory results. Consult with town ODE and make final attempt with stacking 75 klbs weight on bit and staging up pressure to 3,500psi, (again unsatisfactory results). Float equipment appears to be suspect and decision made to do leak off test. Rig to and perform leak off test with 11.4 ppg mud weight. Achieve 675 psi final leak off pressure equivelent to 14.4 ppg mud weight. Record casing annulus pressure of 1,080 psi at start/end. Rig down testing equipment. Tag up on cement at 9,682' and drill cement from 9,682' to 9,704'. Drill plugs and float from 9,704' to 9,709'. Broke through float, wash and ream from 9,709' to 9,735' - no cement. Work back through float several times to ensure clear passage. Wash and 11 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 I ream from 9,735' to 9,793', tag up on shoe - no cement. Start dropping fluid level in pits for mud swap. Contact office about findings. I 04/13/2008 Continue to wash/ream from 9,785' to 9,793' (barrel shoe depth), with no evidence of cement in casing below float collar at 9,707'. Continue to circulate and circulate out mud to fresh 10.6 ppg KCL / Polymer type at 165gpm and 1,440 psi. Shut down, clean out pits and trasnfer mud from RSC to rig. Drill out barrel shoe I without incidents or problems. Work exit four times to ensure clear for tools and saw slight bobble of 7 -10 ft -klbs torque on second pass up. Continue to clean out rat hole from 9,793' to 9,808' with out incidents. Directional drill 6-1/8" hole with Geo -Pilot per Sperry Directional Driller from 9,808' to 9,828' with 2 -5 klbs I WOB, 60 -80 rpm, 5 -6 ft -klbs off / 6 -8 k -ftlbs on torque, 270 gpm and 2,210psi. Pull back into casing at 9,763' and circulate bottoms up prior to leak off test. Initiate leak off test with 10.5 ppg mud = 13.8 ppg EMW (0.6 ppg from LOT #1). Break over point was 1,050 psi. Rig down test equipment and consult town 1 ODE. Slip and cut drilling line. Pull out of hole with BHA #13 for RTTS. Rack back heavy weight drill pipe, flex drill collar, remove source and shut MWD tool down and rack back. I 04/14/2008 Handle BHA #13 tools, lay down rest of unnecessary MWD /LWD components after being down loaded. Pick up and make up BHA #14 with RTTS packer. Run in hole with RTTS at lmin/stand to 9,650'. Set I RTTS per HES procedure, after breaking circulate for 5 min's. Pressure up to 3,650 psi without issues and chart same, with 3,550psi final pressure. Note: 0.5 hour test = 2.7% differnce — good test. Unseat RTTS packer and retrieve to surface. Pick up Geo - Pilot, bit, and smart tool. Circulate to warm tool up. Pick up I and plug into Smart Tool, turn it on and load same. Shallow hole test MWD /LWD at 242 gpm and 1500 psi. Pick up remainder of BHA and run in hole from 415' to 2,826'. I 04/15/2008 Run in hole with BHA #15 from 2,826' to 9,667' without incidents. Wash from 9,667' to 9,828', while circulating bottoms up, prior to drilling. Maximum trip gas 525 units. No fill was observed on bottom and I hole appeared to be good shape. Trouble shoot down linking problems with MWD /LWD and Geo - pilot. Change out choke 4 jets without effect. Work on surface software issues, again without success. Mobilize crane and change out Geo span unit on floor without success. Continue to sort out surface software issues, with no success. Finally able to get manual setting to Geo - Pilot. MWD /LWD tools working and the decision I was made to drill 30' for Modified Salt exit strategy. Circulate with various rates to assist wash down linking problem. Commence drilling 6 -1/8" hole, after being able to manually set Geo -Pilot to desired setting. Directional drill 6-1/8" hole with Geo -Pilot per Sperry Directional Driller from 9,828' to 9,845' where a 3-4' I drilling break was encountered. Lost circulation at 120 bbls/hr. Pulled up and monitored well bore in static condition and noted 82 bbls/hr losses. The decision was made to continue drilling ahead and have cuttings aid in sealing fracture. Mix 15 bbls of 75 ppb calcium carbonate 50 pill, with N -vis added for viscosity, until 1 gnarly looking. Drilled to 9,871' using caution when bit was at 9,795', Geo -Pilot reference housing /cutters were at 9,806' and Smart Stab at 9,833', coming through barrel shoe, slowed rotary to 40- 50rpm's. Spot calcium carbonate pill with 1,100 strokes and shut down. Pull out slowly to 9,787' and wait on pill to settle 1 into fracture for 10 minutes. Start pump, and go in hole slowly to apply ECD pressure to help force pill into fracture. Shut down and monitor loss with a loss rate of 16 bbls/hr. Run in hole and drill from 9,871' to 9,967 using 230 gpm, 1325 psi, 6 -10 klbs WOB, 110 to 120 rpm and 10 ft -klbs torque. Losing at a rate of I 120 bbls/hr. Hit a possible fracture at 9,958' indicated by higher torque, bit bounce and return flow which had been at 70% stopped for about 4 minute and then slowly came back. I 04/16/2008 Rig crew, RSC, Dead Horse plant all building volume. Dead Horse plant sending 300 bbls to be followed with another 300 bbls. Circulate over hole to ensure full with 9 -10 bbls/hr losses recorded. Attempt to stage I pumps up from 35 to 170 gpm with 60 -80 bbls/hr losses and 170 -230 gpm with 120 bbls/hr losses. Mix & 12 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 spot 25 bbls Ca carbonate pill and allow to soak while building volume — 7 to 8 bbls/hr loss rate. Pits on rig built back to 750 bbls, 200 bbls in RSC, 150 bbls in upright storage and 600 bbls in Super Vac's on location . Make up top drive. Wash from 9,766' to 9,967' at 250 gpm and 1260 psi, with 80 bbls/hr losses. Directional drill 6-1/8" hole 9967' to 10,488'. Lost total returns, +/ -120 bbls/hr to 10,422' and 100% losses of +324 bbls/hr rate from 10,421- 10488'. Monitor well while spotting 30 bbls of 75 ppb Ca carbonate LCM pill. Spotted with 1,250 strokes, with 100% Losses= 140+ bbls. Pulled slowly to shoe with light swab. Rotate pipe to alleviate swab from 10,448' to 9763'. Fill across top of annulus to maintain hole full with bit at 9,763'. Wait on Form -A -Plug material and personnel to arrive. Clean mix pit & slug pit thoroughly. 04/17/2008 Inspect tanks per MI Representative and fill with 40 bbls fresh water. Mix spacer, pump Form -A -Plug pill from vac truck to slug pit. Run in hole to 10448' from 9773'. Tight spots at: 9,812', 9,973, 1,0165' and 10,448' with 10 -25 klbs overpull. Pump 15 bbls 10.0 ppg spacer while adding 40 saks MI accelerator to Form -A -Plug. Pumped 40 bbls Form -A -Plug. Displace with 110 bbls 9.9 ppg mud. Pill in place. Pull out of hole to 9,280'. Well attempting swab when pulling on elevators. Make up top drive and rotate each stand out to alleviate swabbing. Total of 22 bbls gained while tripping ou. Attempt to establish circulation through drill string - unsuccessful with 3,000, 4,000 or 4,700 psi. Rotate with 80 -100 rpm to attempt clearing around bottom of the assembly. Surge pipe with pressure and wait on pressure - unsuccessful in attempts to regain circulation. Close annular preventer. Open kill line and perform Hesitation Squeeeze with 2.2 bbls and 180 psi - bled to 120 psi. Continue to bump with 5 -10 strokes every 5 minutes with 280 -300 psi showing, which bled off to 100 -120 psi, (total= 13.89 bbls). Open bleeder and bleed 5 bbls total fluid to strapped trip tank - flow not slowing down. Shut in bleeder and monitor pressures, (ISIP= 140 psi FSIP = 155 psi after 1 hr). Mud weight required to handle pressure was 10.2 -10.3 ppg. Consult Town ODE and decision made to bull head 40 bbls fluid. Pump 40 bbls 9.9 ppg mud down back side to ensure well pressures stabilize at 53 gpm and 380 -400 psi. (ISP= 140 psi and flow back 2 bbls at 2.0 - 2.5 min/bbl, FSIP = 115 -120 psi and build to 150 psi in 15 min). Attempt to pump down drill string - unsuccessful despite all attempts. Bleed off annulus and open annular preventer. Flow back 8 bbls at 2.0 - 3.5 min/bbl for 5 bbls and 1.5 - 2.0 min/bbl for 3 bbls. Shut in with annular prevention. (ISIP= 150 psi and FSIP 190 psi at 20 min). Continue to monitor pressure and consult Town ODE. Attempt to bleed off with another 5 bbls. Open annular after bleeding through choke, but flow increasing, ie oil /gas migration to surface. Shut in with ISIP of 105 psi and continue to monitor pressures, 234 psi at 20 minutes. Consult with Town ODE and mix 300 bbls of 10.5 ppg heavy mud. Pump 110 bbls of 10.5 ppg mud down back side, with 1420 strokes total at 243 gpm / 1380 psi. Monitor well for 10 min with FSIP of 81 psi. Open bleeder and bled off pressure. Open annular preventer with no fluid visible in stack. Fill stack with 11 bbls 10.5 ppg mud. Losses 16 -18 bbls/hr after 45 min. Broke out TIW valve, pulled one stand and monitored well for 15 minutes. Well took 2 bbls to fill. Actual loss due to steel displacement 0.5 bbls. Pull out of hole from 9,280' to 7,863'. Used constant hole fill while pulling pipe. Stopped and verified well still taking fluid with pipe static at multiple areas and when hole fill not following calculated volumes. Hole showed slower loss rate when pipe was being moved up than when pipe static. 111 Each time well was checked for static losses they varied from 8 -12 bbls/hr. 04/18/2008 Pull out of hole with BHA #15 from 7,843' to 5,528' - pull 5 stands and fill annulus with 10.5 ppg mud. Monitor well every 5 stands with 12 -16 bbls/hr losses. Pull out of hole from 5,528' to 3,695', but back reaming at 100 rpm to alleviate filling problems due to hole not taking proper fill. Note: At stand #51= 5,432' started seeing cottage cheese type material - later found to be Ca carbonate mud with Polymer coming out, due to exposure to high pH of Forma -plug operation. This continued to 4,563' where rabbit was found. Hooked up air to the mud line and blew air through each stand with top drive, prior to racking back. Total losses at noon was 69 bbls. Stand #43 was full of Forma -plug material, which continued to be blown out and bagged for disposal. At 3,695' unable to blow through drill pipe. Consult town ODE and the decision was made to lay down 102 joints. Losses continued to increase as more drill string pulled, therefore at +/- 3,800' fill back side with 50 bbls of 10.2 ppg, 40 ppb Ca carbonate mud - losses at 18 bbls/hr. Begin to lay down a 13 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 I total of 102 joints of plugged drill pipe from 3,695' to 2,100'. Back ream while flow checking to get proper fluid down back side. Cap both pin and box ends to contain any loose material inside pipe (pretty much solid plug of Forma -plug with consistency of dried silicone). Back ream every 5th single to help with hole filling - 1 8 -12 bbls/hr losses. At 2,100' losses quit and unable to pull pipe without swabbing. Close ram and bull headed 15 bbls of 10.0 ppg mud at 40 spm and 450 psi. Checked for pressure, opened rams and mud fell 6 -8' in annulus, well static. Closed ram and bull headed 10 bbls of 10.0 ppg mud for at total of 25 bbls at 450 psi. I Checked for pressure and opened ram. Fluid 6 -8' down in annulus, rotated pipe in attempt to have mud go down. Pull 5 joints, rotating each - well swabbed 1.5 bbls. Closed ram bull head 15 bbls of 10.0 ppg mud at 50 spm and 525 psi. Fluid 3' down in annulus. Pulled to 1,920' observed slight swab, observed well and showed slight flow on flow line. Shut in well - no pressure. Bull head 40 bbls of 10.5 ppg mud at 50 spm and I 450 psi ( +1 -29 bbls annulus volume from surface to bit). Checked pressure - zero, opened ram, well static, pulled 1 joint and fluid lowered 2' in annulus. Lay down 10 joints drill pipe to 1511' with close to normal fill up. Close ram, bull head 15 bbls of 10.5 ppg mud at 50 spm and 400 psi. Checked pressure and opened ram 1 - well static. 04/19/2008 I Continue to pull out of hole, filling the hole every 5 joints. Flow check revealed the well was flowing and 30 bbls of 10.0 ppg mud was bullheaded, resulting in 2 to 4 bbl per hour losses. BHA #15 was pulled and laid down. The well continued to flow slightly and another 40 bbls was bullheaded followed by opening the I bleeder to check the pressure, losses at 2 -3 bbls per hour. Flow checks were performed and preparations made for testing BOPs. Test BOPs. Run in hole to 1,632' to spot nutplug /SAPP pill and run wiper plug to clean drill pipe. While circulating bottoms up gas values climbed to 3500 units, pumping continued until gas I values fell below 500 units. Check for flow, with slight flow observed. Continue circulating and pump 50 bbls of 10.5 ppg mud. Continue to monitor well while picking up BHA #16 with 247 bbl loss for 24 hours. I 04/20/2008 Finish picking up BHA and run in hole to 3,362' testing tools and breaking in Geo Pilot on the way in. Losses continued and gas amounts of 3500 plus units were observed. A 10.5 ppg pill was spotted to control I the slight flow observed. Form A Plug was observed coming across the shakers and good oil shows were seen coming out of solution. Continued to run in hole monitoring losses and or flow. Gas values climbed again to 1050 units and 13.8% loss ratio observed on circulating bottoms up. Continue to run in hole with losses of 2.5 bbls per 5 stands observed and gas values dropped to 287 units. Wash and ream from 9780' to I 9815' and losses of 100% were observed. Continue to run in hole and again weight on bit increased to 10 -12 klbs and losses were between 18 and 24 bbls per hour. Drilling started with 100% losses when rig crew rigged up for mud cap operations. A 50 bbl sweep of 75 ppb, 150/50 calcium carbonate was pumped down I hole with no change to losses or returns. Mud cap drilling started at approximately 10,655' with seawater pumped through the drillstring and 10.5 ppg mud pumped down the backside. A deflection point at 10,800 forced the drillstring upwards and several attempts to go back down failed. Drilling continued to 11,042' I using sea water down drill string. Total losses for the day 2326 bbls. 04/21/2008 I Continue drilling mud cap style from 11,042' to 12,055'while using different parameters to change hole inclination with no results. The hole was drilled to 12,055', when all attempts failed to change the inclination, the decision was made to pull back and sidetrack at 10,780 into the lower Kuparuk formation. I Time drilling commenced, drilling one tenth of a foot per 3 minutes from 10,780' to 10,784.6'. MWD tools failed and attempts to restore connection also failed. The decision was made to continue time drilling due to indications that it was indeed sidetracking. I 1 04/22/2008 Attempt to sidetrack 10,784' to 10,820'and try to feel a ledge but drillstring fell off. Consultation with town 1 made the decision to pull out of the hole for completions. Sea water in drill pipe was displaced and the trip 14 1 DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 out started, pumping on the way out, monitoring losses and being careful not to swab the hole. Total losses pumping out were 263 bbls of mud including the 110 bbl displacement. Attempts to circulate inside casing failed and losses equaled 48 bbls. Pull and pump out of hole to 5,262' with losses of 550 bbls of mud. Flow 1 checks were held every 10 stands pulled. The well was observed to be static when pipe movement stopped. 04/23/2008 Continue pumping and pulling out of hole with some swabbing up to 2,930'. Flow was checked every 1,000' for 15 minutes. Circulate bottoms up with gas peaking at 1630 units while circulating. Attempts to keep the well from flowing with 10.0 ppg mud failed and the annular preventer was shut in and the pressure monitored. Bull heading 10.5 ppg mud commenced to try and control flow. Pressures were monitored and bull heading continued until the well became static. Pull out of hole from 2,930' to 1,778' and monitor every 5 stands with the hole static but not taking the right amount of fluid per stand. Continue to monitor well on trip out from 1,778' to 1,298' while bull heading, then shut in the well to work on the top drive. After opening the preventer flow was observed at 2 — 3 bbls per hour and bull heading commenced. Shut in and monitor well then open to find the wellbore static. Pump and pull out from 1,298' to 579' with 100% losses of 71 bbls per hour. 04/24/2008 Make up and run in hole with scraper run while performiong rig maintenance. Fill pipe and monitoring losses of 2 — 3 bbls per 5 stands. Shut in preventer and bullhead fluid down the backside, 575 bbls of fresh 10.5 ppg mud. Complete bull heading and monitor well with no flow apparent, wellbore was static. Commence pumping out of hole with 100% losses, monitoring well every 10 stands. Continue out of the hole performing choke manifold tests on the way out. Total losses for the day observed to be 1270 bbls. 04/25/2008 Continue to pull out of hole from scraper run pumping out to surface monitoring on the way out. Lay down the scraper assembly, perform rig maintenance, prepare for and test BOPs. Rig up to run completion tubing and equipment to run downhole pumps, tools and units. Rig up to run completion tubing. Bull head 375 bbls of 10.5 ppg brine at 1500 psi. Rig down hoses to internal annulus. Losses increased to170 bbls/hr with 10.5 ppg brine. Lined up on sea water after brine reserves exhausted. Pumped 77 bbls sea water and losses slowed to 1.5 bbls/hr. Finish making up motors for ESP and install control lines. 1 04/26/2008 Make up and test connections on downhole pumps. Run 2 7/8" completion string attaching power supply cord every other joint. Splice and test control lines for correct operation and continue running in. Test operation every 1000'. Change over equipment to run 3 -1/2" tubing and continue running in the hole. 04/27/2008 Run completion assembly, down hole pumps with control lines from 6704' to 8794'. Test ESP cable every 1000'. Install Canon clamps every other joint. Pick up ScSSSV assembly, make up control lines and test same to 5000 psi for 15 min. Rill with completion assembly, down hole pumps and ScSSSV. Install Canon ' clamps every other joint from 8794 to 9517'. Make up hanger assembly, cut ESP cable, made splice to penetrator. Rig down ESP sheave and running equipment. Splice control lines, test ESP cable for 10 min. Set TWC and land tubing . Test hanger to 5000 psi upper and lower for 10 minues. Change upper and lower rams in BOP back to 4 ". Observed flow at inner annulus. Shut in and monitored pressures, built to 10 psi. Finish changing rams to 4 ". Nipple down BOP. Prepare cellar and well head, move valves, cap, ball and rod assembly to well bay. Nipple up tree, install valves, head and Ball -rod assembly. Test tree to 250/5000 psi for 5 min each and chart same. Rig up high pressure lines to bull head diesel down annulus and tubing. 1 15 r ' DAILY SUMMAY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 ' 04/28/2008 Bull head 20 bbls viscosified sea water, followed by 285 bbls diesel down inner annulus at 2.5 bbls /min, 550 start psi with final of 1100 psi. Bull head 20 bbls viscosified sea water down tubing, followed by 64 bbls diesel at 2.5 bbls /min. Drop ball and ball rod assembly. Set packer with 1000 psi over initial of 1100 psi. ' Test packer to 3500 psi for 30 min. Test inner annulus to 3500 psi for 30 min. Rig up slick line lubricator and sheaves. Rig down circulating hoses and manifold. Run #1 to 3480', unable to pass gas lift mandrel. Pull out with slick line, made second run and pulled rod and ball. Ran back in hole for X -RHCM plug and retrieve same. Rig down wire line and remove completion equipment from rig floor. Well released from ODSK -33 at 16:00 hrs. 1 1 1 1 1 1 1 1 16 1 DAILY ACTIVITY Pioneer Oooguruk ODSK -33PB1 and ODSK -33 3_ DAILY ACTIVITY (I_A_D_C_) I Time Elapsed Operations Breakdown (hrs) Time I Oooguruk ODSK -33PB1 I 02/17/2008 12:00 -13:30 1.50 Secure well. 13:30 -19:00 5.50 Raise Beaver slide, walk ways steps, utility lines, shim stomper beams. 19:00 -24:00 5.00 Move rig from ODSN -34i to ODSK -33. Shim beams to level rig & re -route supply hoses to allow for I skid over ODSK -33 well bay. 02/18/2008 00:00 -02:00 2.00 Continue to prepare for move to ODSK -33 well center. Blow down lines in Hutz & disconnect, as U reached limit for moving, (only able to get 3 -wells per hook up, before re- connect on next section of pipe racks). 02:00 -06:00 4.00 Move rig from ODSK -34i, over to ODSK -33. Had to level pad with gravel in front right hand corner. Rig was leveled & pits moved in line with rig, (ensured rig squared over Well Bay modules). Rig up lines in Hutz & Putz. I 06:00 -07:00 1.00 Install starting head of Vetco Gray on well conductor per Vetco Gray Representative, (RKB = 39.5' to landing load shoulder). 07:00 -10:30 3.50 Nipple up 21 -1/4" diverter system on Vetco Gray risers. Connect 16" diverter line & knife valve & hook up lines to same. Install environmental seal below well cellar area. Tranfer mud from RSC to pits. I Test gas detectors, Rig accepted: 07:00hrs Feb. 18, 2008. 10:30 -4:30 4.00 Service rig & top drive system. Grease crown & blocks. Ensure all pit & flow alarms calibrated & set. Pick up & rig up SSDS Gyro & MGT sheaves & hang in derrick/cellar. String lines & make up rope sockets on both lines. Pick up & bring necessary BHA tools to floor. Inspect rig for pre -spud compliance & post signs for diverter line /well ID signage. Hook air heaters back to pipe rack alley way I & inspect line for leaks - OK. 14:30 -15:30 1.00 Function test diverter system per AOGCC requirements, (State waived witness of test. Perform accumulator test per requirements, (1:58 sec re- charge - 5 x N2 Bottles = 1,810psi). All systems passed without incidents. Record data & forward test results to AOGCC. I 15:30 -16:30 1.00 Held pre -spud safety meeting with all related services. All action items discovered were addressed & remedied. All hazards with wire line operations identified & area's of concern taped off. All communications with each Wireline unit checked. Shakers screens finished being dressed out. 16:30 -18:30 2.00 Made up 12 1/4" bit, 8" Sperry Drill, float sub, pony collar, fill riser & check for leaks. 18:30 -20:30 2.00 Ream & wash from 58 - 110' with 400 gpm & 40 rpm. I 20:30 -22:00 1.50 Pull back to surface, drain motor, install MWD probe & orient motor. 22:00 -22:30 0.50 Ream & wash from 110' to 153' at 467 gpm & 42 rpm. 22:30 -23:00 0.50 Drill 12 -1/4" hole from 153' to 199'. Note: Base of 16" Conductor at 153'. 23:00 -24:00 1.00 Halliburton CCU lines plugged clear same. 1 02/19/2008 00:00 -00:30 0.50 Clear CCU cuttings Line - backed up. 00:30 -01:30 1.00 Drill 12 -1/4" hole from 199 to 292'. 01:30 -03:00 1.50 POOH from 292' to 92'. Pick up the rest of BHA #1 components, add MWD, scribe & load EM probe. I RIH to 292' without incidents. 03:00 -04:30 1.50 Drill 12 -1/4" hole from 292 to 463'. 04:30 -05:00 0.50 Service rig & top drive & run gyro survey. 05:00 -12:00 7.00 Directional drill 12 1/4" from 463' to 920'. I 12:00 -24:00 12.00 Directional drill 12 1/4" from 920' to 1745'. 02/20/08 00:00 -12:00 12.00 Directional drill 12 1/4" from 1,745' to 2,830'. Maintain sweep program per Bariod recommendations. 12:00 -18:00 6.00 Directional drill 12 1/4" from 2,830' to 3,090'. Maintain sweep program per Baroid recommendation. I 18:00 -19:00 1.00 Trouble shoot MWD tools while circulating. Reset tool & run MAD pass from 3,090' to 3,121' at 150 ft/hr. 19:00 -20:00 1.00 Directional drill 12 1/4" from 3,121' to 3,183'. 20:00 -23:00 3.00 Circulate & condition mud, pumped 60 bbls weighted HiVis sweep with 20 sxs med nut plug surface to I surface at 750 gpm & 90 rpm. No visual indication of nut plug returns to shaker. Jetted flow line & possum belly to prepare for trip. Blow down top drive. 23:00 -23:30 0.50 Short trip from 3,183' to 2,860'. Tight spots 3005' - 30 klbs, 2948' - 25 klbs, 2,940' - 30 klbs, 2,925' -15 klbs, 2,860' - 25 klbs. 23:30 -24:00 0.50 Trip tank not functioning properly. Lines plugged, blow down same. I 02/21/2008 00:00 -04:00 4.00 POOH from 2,860' - 218' - top of Jars. Tight spot recorded at 2,769' = 30 klbs, 2,551'= 15 - 20 klbs, 1,650 - 1,635' = 20 klbs, 1,578' = 30 klbs, 1,265' = 20 klbs, 645' = 15 klbs, & 540' = 15 klbs. All spots were worked through & usually cleaned up after being worked once. 1 1 1 DAILY ACTIVITY (LA.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 04:00 -09:00 5.00 RIH from 218' - 3,136'. Work through tight spots at 1,687' - 1,985' at 250 gpm flow & 1 - 5 klbs WOB, 560 psi & 40 - 50 rpm. At 1,985' appeared break up clay ball & able to RIH from 1,985' to 3,136' without I further incidents. 09:00 -11:00 2.00 Stage up pumps to 740 gpm & 3,211 psi - no losses. Reciprocate pipe at 90 rpm, rotatingweight = 120 klbs. Pump 50 bbl weighted Walnut sweep surface to surface - hole appeared clean. Check flow - static. 11:00 -15:30 4.50 Blow down top drive & POOH from 3,183' to 2,880'. Pull 30 klbs over at 2,944' & slight swabbing - ' worked thru area to clear tight hole. Continue trip out of hole. Rack back 5 stands of HWDP. 15:30 -21:30 6.00 Lay down 8 -1/2" directional BHA #1, stabilizers & bit balled up with clay. Clear all 8" handling tools & clean rig floor. 21:30 -23:00 1.50 Rig up 9 5/8" casing running tools. 1 23:00 -24:00 1.00 Held PJSM with all personnel, made up 9 5/8" shoe joint & intermediate joint, baker locked threads & circulated through float shoe. 02/22/2008 00:00 -06:00 6.00 Run 9 5/8" 40 #, L -80 casing from 85' to 2,920' with no problems. I 06:00 -07:00 1.00 Run casing & work through tight spot from 2,920' to 2,925'. Wash down at 1 bbls /min & 350 psi, continue to RIH to 3,179'. Work thru tight spots at 2,972', 2,985'. Pick up landing joint & hanger, land casing at 3,172'. 07:00 -08:00 1.00 Lay down Franks fill up tool & make up Halliburton cement head. I 08:00 -09:00 1.00 Circ & cond mud. Stage pumps up to 10 bbls /min & 2650 psi with no losses. 09:00 -09:30 0.50 Held PJSM with personnel & HES cement while circulating at 10 bbls /min 2650 psi for 235 bbls =1 casing volume. 09:30 -10:00 0.50 Change lines to HES cement. Pressure test lines to 3500 psi. Pump 2 bbls sea water, Drop bottom plug. I 10:00 -12:00 2.00 Reciprocate casing 20' during lead cement job. Pump 40 bbls 10.0 ppg dual spacer, mix & pump 240 bbls lead, (1347 cu /ft) Type L Permafrost, mixed at 10.9 ppg, with 20 GPS sea water, with 4.15 yield, pumped 235 bbls at 4 -5 bbls /min & land casing. Mix & pump 45 bbls tail: (253 cu /ft) Premium "G" + 2% CaCl2 + .2% CFR -3, 1.19 yield, mixed at 15.9 ppg with 5.23 GPS sea water. Drop top plug, pump 10 I bbls sea water. Displace with 9.5 ppg WBM with rig pumps at 8.0 bbls /min & 1580 psi. Slowed pump rate to 1 -2 bbls /min & 650 psi, at 214 bbls away, bump plug with 500 psi over 1150 psi at 12:05 hrs. Bled off at 12:08 hrs & checked floats - OK. Cement in place at 12:05 Hrs. 12:00 -15:30 3.50 Rig down casing cement head & lines. Blow down lines. Pull & lay down landing joint, short bails & elevators. Clear rig floor. I 15:30 -17:30 2.00 Make up jetting sub, flush diverter & riser with water & cement inhibitor. 17:30 -24:00 6.50 Nipple down diverter system, riser & knife valve. Remove starter head. 02/23/2008 I 00:00 -03:00 3.00 Install Vetco Gray M -233 well head, per Representative. Problem achieving test. 03:00 -04:00 1.00 Remove well head & change out pinched "0" ring in bottom. Steam inside area & re- install well head with fresh "0" ring - test to 5,000 psi without incidents. 04:00 -07:00 3.00 Nipple up BOP stack & install choke /kill lines & accumulator lines. Install risers & turnbuckles. 07:00 -09:30 2.50 Pick up test joint & test plug. Set in place & fill stack. I 09:30 -16:00 6.50 Test BOPE per AOGCC requirements, (State waived witness - Mr. Chuck Sheve). Test with 250 psi low & 3,500 psi high, on all rRams, annular preventer & valves per Nabors testing order. Check H2S & LEL gas equipment - OK. Perform accumulator test with 1:35min recharge on system. Rig down test equipment. Lay down test joint & plug. Install wear ring & lock down. Test kill line to 250/5000 psi to I test broken connection. 16:00 -18:00 2.00 Held PJSM, slip & cut drill line. 18:00 -18:30 0.50 Held PJSM with Drill Crew & Sperry DD/ MWD on picking up BHA. 18:30 -24:00 5.50 Pick up BHA #2. Down load MWD tools. Perform shallow test at 450 gpm, 600 psi, check Geo Span - OK. 1 02/24/2008 00:00 -02:30 2.50 Make up BHA, loaded nuk sources & RIH to 765'. 02:30 -06:30 4.00 Pick up 60 joints 4" XT -39 DP while RIH to 2,616', fill pipe. I 06:30 -08:00 1.50 Service top drive & change saver sub. 08:00 -09:00 1.00 RIH & tag float collar at 3087'. Pick up & break in seals on Geo -Pilot per Sperry Directional Driller. 09:00 -12:00 3.00 Drill out plugs & float collar to 3,088'. Displace fluid to 8.8 ppg water based mud. 12:00 -14:30 2.50 Drill float collar & cement from 3,088' to 3,092' at 540 gpm, 1900 psi, 80 rpm & 5 - 25 klbs wob. 14:30 -16:00 1.50 Change top drive gripper dies. I 16:00 -16:30 0.50 Drill out cement from 3,092' - 3,161' at 540 gpm, 1900 psi, 80 rpm & 3 - 5 klbs wob. 16:30 -17:00 0.50 Circulate bottoms up prior to casing test. Prepare test equipment for same. 17:00 -20:30 3.50 Rig up & attempt to test casing to 3500 psi. Test failed, test surface equipment - all equipment showed good pressure integrity. Attempted test with Halliburton cement pump with same results, I while checking mud pump discharge valves. 20:30 -24:00 3.50 Mix & pump slug. POOH, rack back HWDP, flex collars, lay down 2 ghost reamers & Geo - Pilot. 02/25/2008 00:00 -03:00 3.00 PJSM. Recover & lay down nuke sources from rig floor. Lay down stab., F /S, & Bit. Rack back MWD & Geo Pilot. I 03:00 -04:00 1.00 Pick up RTTS packer & CV per HES Representative. 2 1 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 04:00 -07:00 3.00 RIH with BHA #3, (RTTS), to 3,078'. 07:00 -08:30 1.50 Break circ & set RTTS per HES Representative. Shut in top pipe rams & open kill line. Test casing per I program with 3,500psi. Note: 1.47% change in 30 min's -good. Bleed off pressure & unseat RTTS. 08:30 -10:30 2.00 POOH 3 stands. Pump dry job & POOH to RTTS. 10:30 -11:00 0.50 Recover RTTS & lay down. 11:00 -12:00 1.00 Make up Geo -Pilot & bit for BHA #4. 12:00 -13:30 1.50 Make up BHA #4. Pick up TM HOC, stabs & float sub. I 13:30 -16:30 3.00 Pick up BHA, install battery & upload MWD. Perform shallow test per Sperry at 450 gpm & 800 psi. 16:30 -18:00 1.50 Held PJSM. Load nukes, pick up 1 stand of flex collars, 5 stands HWDP & jars. 18:00 -20:00 2.00 RIH with 4" DP to 3,160'. 20:00 -21:30 1.50 Drill cement & float shoe from 3,163' to 3,173'. Ream & wash rat hole from 3173' to 3183'. I 21:30 -22:00 0.50 Directional drill 8 -1/2" hole from 3,183' to 3,196'. 22:00 -24:00 2.00 Ream & work pipe to clear obstruction, well packing off in rat hole area with cement chunks. 02/26/2008 00:00 -0:30 0.50 Directional drill 8 -3/4" hole from 3,196 to 3,203'. I 00:30 -00:45 0.25 Circulate prior to LOT & rig up test equipment. 00:45 -01:00 0.25 Perform LOT with 8.8 ppg MW = 1,060 psi break over point = 15.45 ppg EMW. Rig down test equipment. 01:00 -02:00 1.00 Service top drive, grease crown & blow down kill line. I 02:00 -12:00 10.00 Directional drill 8 -3/4" hole from 3,203 to 4,064'. Geo Pilot experiencing some roll & hooking up issues, up until 3,900 - 4,000' MD. 12:00 -13:00 1.00 Directional drill 8 -3/4" hole from 3,969' to 4,065'. 13:00 -14:30 1.50 Trouble shoot mode switch on MWD tools as per Sperry. Change shaker screens. 14:30 -24:00 9.50 Directional drill 8 -3/4" hole from 4,065' to 4,821'. Still experiencing hook up problems with Sperry I Geo -Pilot thru soft formation. Experienced pack off & large shale to surface from this pack off at 4809' with increase of gas up to 585 units. Identified as correlating with disposal well same TVD. 02/27/2008 I 00:00 -12:00 12.00 Directional drill 8 -3/4" hole from 4,821' to 5,610'. 12:00 -20:30 8.50 Directional drill 8 -3/4" hole from 5,610' to 6,340'. 20:30 -21:00 0.50 Change #1 pump center suction cap gasket. 21:00 -24:00 3.00 Directional drill 8 -3/4" hole from 6,340' to 6,500'. I 02/28/2008 00:00 -12:00 12.00 Directional drill 8 -3/4" hole from 6,500' to 7,347'. 12:00 -23:30 11.50 Directional drill 8 -3/4" hole from 7,347' to 8,034'. 23:30 -24:00 0.50 Service top drive & traveling block while change swab & liner on #2 pump. I 02/29/2008 00:00 -00:30 0.50 Change swab & liner in #1 pump 00:30 -10:30 10.00 Directional drill 8 -3/4" hole from 8,034' to 8,491'. Start weight up to 10.6 pg at8,200'. 10:30 -12:00 1.50 Work tight spot from 8,491'to 8,461. Mud pump #1 blower down. Pick up off bottom 20'. Rotary I stalled out & well packed off. Work from 8,477' up to 8,461'. Attempt to work free. Pull 230 klbs over & work pipe down. 12:00 -18:00 6.00 Work pipe to free same at 8,461' to 8,477', string weight 135 klbs. Jar up 350 klbs & jar down 50 klbs - pipe came free, after jarring on up stroke. I 18:00 -20:00 2.00 Circulate & condition mud. 20:00 -24:00 4.00 MWD check shot at 8,377' to verify tool still operational. Had some ECD increase on that stand. Back ream from 8377' to 7814', had steady cuttings returns at shaker with some larger balls of clay. Tight spots encountered between 8240' & 7830'. I 03/01/2008 00:00 -02:30 2.50 Finish short trip to 6,640', work thru tight spots at 7,729', 7,660', 7565' -30 klbs over - no pump. 02:30 -04:00 1.50 RIH from 6,640' to 8,313'. 04:00 -05:00 1.00 Ream & wash from 8,313' to 8,491'. Ream out obstruction from 8474 to 8,484'. I 05:00 -08:00 3.00 Circ & cond mud at 8,491'. High gas 758 units. Pump 30 bbls, 13.0 ppg HiVis sweep with 10 ppb walnut surface to surface. Trouble shoot MWD communication loss. Pump 30 bbls fresh water pill - no success. 08:00 -10:00 2.00 POOH from 8,491' to 8,023'. Pump slug & continue to POOH to 6478'. 10:00 -11:30 1.50 Circ & cond mud while trouble shooting MWD - no success. Pump slug. I 11:30 -17:00 5.50 POOH from 6,478' to 637'. Lay down ghost reamers. 17:00 -22:00 5.00 Lay down BHA, rack HWDP in derrick, lay down jars, remove Nuke source, down load MWD &clean balled up stabs. 22:00 -22:30 0.50 Service rig. I 22:30 -24:00 1.50 Lay down BHA, subs, MWD, bit & Geo - Pilot. Found 3 small rocks in pulser poppet for MWD. 03/02/2008 00:00 -00:30 050 Finish BHA & clean up floor. 00:30 -02:30 2.00 Make up test joint, pull wear ring, set test plug & fill hole with water. I 02:30 -06:00 3.50 Test BOPE, annular 250/2500 psi, rams, TDS valves, choke manifold valves & blind rams 250/3500 psi. 3 DAILY ACTIVITY (LA.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown ' (hrs) Time 06:00 -07:30 1.50 Pull test plug, set wear ring, rig down test equipment. Blow down choke & kill lines. 07:30 -09:30 2.00 Slip & cut drill line. ' 09:30 -10:30 1.00 Service top drive & perform post jarring inspection. 10:30 -17:00 6.50 Make up BHA #5, up load MWD, load Nukes.RIH with jars & HWDP. 17:00 -24:00 7.00 RIH on DP & pick up ghost reamers. ' 03/03/2008 00:00 -01:30 1.50 RIH from 5995' to 8400'. 01:30 -02:00 0.50 Wash & ream from 8400' to 8491' - no fill. 02:00 -03:30 1.50 Circ & cond mud. 03:30 -12:00 8.50 Directional drill 8 -3/4" hole from 8,491' to 8,631'. ' 12:00 -24:00 12.00 Directional drill 8 -3/4" hole from 8,631' to 9,029'. 03/04/2008 00:00 -09:30 9.50 Directional drill 8 -3/4" hole from 9,029' to 9,199'. 09:30 -10:00 0.50 Circ & cond mud. 10:00 -11 :00 1.00 Check trip from 9,199' to 8,990'. Up wt 180 klbs, slack off wt 112 klbs. 11:00 -24:00 13.0 Directional drill 8 -3/4" hole from 9,199' to 9,471'. 03/05/2008 ' 00:00 -09:30 9.50 Directional drill 8 -3/4" hole from 9,471' to 9,682'. 09:30 -10:30 1.00 Circ bottoms up. 10:30 -11:30 1.00 Directional drill 8 -3/4" hole from 9,682' to 9,705'. 11:30 -13:00 1.50 Circ bottoms up. 13:00 -13:30 0.50 Directional drill 8 -3/4" hole from 9,705' to 9,730' - section TD. 13:30 -14:30 1.00 Circ & cond hole. 14:30 -24:00 9.50 Back ream from 9,730' to 9,374', change parameters as hole dictates. Pack offs & mechanical sticking main problem since leaving bottom. ' 03/06/2008 00:00 -15:00 15.0 Back ream from 9,374' to 8,312'. 15:00 -16:30 1.50 Circ & cond mud. 16:30 -17:00 0.50 Back ream from 8,312' to 7,926'. 17:00 -18:00 1.00 Circ & cond mud. 18:00 -24:00 6.00 POOH & back ream when hole problems exist. Biggest problem came when top ghost reamer exiting the turn at 7200'. 03/07/2008 00:00 -10:00 10.00 Back ream & POOH as hole dictates from 6,960' to 5,899'. 10:00 -18:00 8.00 Pull into tight spot at 5,899'. Pull 60 klbs over & jar both up & down while maintaining full Circ. Max over pull of 250 klbs over. Work pipe free at 5839'. 18:00 -21:30 3.50 Back ream from 5,839' to 5,250'. 21:30 -23:00 1.50 Attempt to pull one stand without back reaming, pulled into tight spot at 5,250'. Pull 60 klbs over & ' start jarring pipe both up & down with a max over pull of 175 klbs. Maintained full circ & worked pipe free at 5,190'. 23:00 -24:00 1.00 Resume Back Reaming from 5,190' to 4,800'. Decision made to back ream to shoe. ' 03/08/2008 00:00 -09:00 9.00 Back Ream from 4,800' to 3,165'. Tight hole. 09:00 -09:30 0.50 Observe well & conduct safety meeting on removing radioactive source. 09:30 -10:00 0.50 Circulate & rotate bottoms up at shoe. Observed increased cutting load over the shakers at bottoms ' up. 10:00 -12:30 2.50 POOH from 3165' to 670'. 12:30 -18:30 6.00 Rack back, down load MWD tool & lay out Geo- Pilot, Neutron tool & sources, stabilizers & Bit. 18:30 -24:00 5.50 Conduct full derrick inspection after jarring. Remove broken link tilt limit switch from derrick. Tighten bolts on draw works, cement lines, gating. Check dead man bolts & weight sensor gap. Service top drive, change out gripper dies & lube oil filter. Change out saver sub. 03/09/2008 00:00 -02:00 2.00 Finish servicing rig post jarring. 02:00 -03:00 1.00 Pick up bit, near bit stabilizer, pony collar & MWD tools. 03:00 -03:30 0.50 Problem inserting programming cable into MWD. 03:30 -05:00 1.50 Make up 1 stand of flex collars, welded blade stabilizer, cross over & 1 stand Of HWDP. 05:00 -05:30 0.50 Shallow hole test MWD with 450 gpm at 670 psi. 05:30 -06:00 0.50 RIH to with remaining BHA to 595'. ' 06:00 -07:00 1.00 RIH from 595 to 1,295'. 07:00 -07:30 0.50 Adjust back -up wrench on pipe handler. 07:30 -08:30 1.00 RIH from 1295' to 3104'. 08:30 -09:00 0.50 Circ at shoe with 250 gpm at 600 psi. 09:00 -14:30 5.50 RIH on elevators from 3,104' to 8,424'. Wash down every 10 stand. 14:30 -20:00 5.50 Wash & ream from 8,424' to 8,850' with 435 gpm at 120 rpm. 4 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown (hrs) Time 20:00 -22:30 2.50 Work thru tight spot at 8850' to 8884'. Max pull at 120 klbs - did not have to jar. Work pipe free & work thru spot several times. Pick up new stand & wash /ream to 8919' - torqued up. ' 22:30 -24:00 1.50 Jar thru tight spot from 8,900' to 8,919'. Max over pull 270 klbs - came free. Stand back 1 stand & pick up single & attempt to work thru tight spot between 8,900' to 8,919'. Torque & packing off - still causing problems. ' 03/10/2008 00:00 -01:00 1.00 Back Ream from 8,900' to 8,696'. 01:00 -04:30 3.50 Circ & build mud weight from 11.0 ppg to 11.5 ppg. Work on froze up mud line from HOC -RSC. 04:30 08:00 3.50 Circ & reciprocate pipe & finish building mud weight to 11.5 ppg. 08:00 -09:00 1.00 Wash & ream from 860T to 8930'. 09:00 -12:00 3.00 Jar thru tight spot at 8930'. Pull up to 350 klbs & pull to 8920'. Try different combinations to free pipe up. 12:00 -19:00 7.00 Work different combinations in an attempt to work pipe free, work from 8,920' to 8,86T. Max pick up weight 350 klbs. Free pipe up & pull to 8805'. 19:00 -24:00 5.00 Consult with office & decision made to raise pump rate to 500 gpm with 150 rpm & slowly wash down ' in an effort to clean hole of cuttings beds. Slowly wash & ream from 8805' to 8836'. Max gas 8060 units. Flow check. 03/11/2008 ' 00:00 -03:00 3.00 Wash & ream from 8,830' to 8,861'. Hit high torque spikes at 8835' & 8,839'. Mud weight 11.5ppg, 500gpm, 150 rpm. 03:00 -03:30 0.50 Stalled out & packed off at 8861'. Regain circ & jarred free with max over pull of 350 klbs. Back ream to 8,835', work thru tight hole. 03:30 -05:00 1.50 Back ream from 8,835' to 8,704'. Lay out two singles. ' 05:00 -09:30 4.50 Circulate & weight up mud from 11.5 to 12.0 ppg. 09:30 -24:00 14.50 Wash & ream from 8,704' to 9,008'. Ream at 2 ft/min for 32'. Backream same 32' section & log any change in parameters. Continue with next 32' section at 500 gpm, 150 rpm & mud weight of 12.0 ppg. Tight spots at 8811', 8,952' & 9,001'. 03/12/2008 00:00 -07:30 7.50 Wash & Ream from 9,008' to 9,038'. Tight spots at 9,012', 9,017' & 9,029'. 07:30 -08:00 0.50 Pipe stalled out & packed off at 9038'. Work pipe free & rework section. 08:00 -12:00 4.00 Wash & Ream from 9,038' to 9,220'. Increased reaming speed to 3 ft/min due to good hole conditions. 12:00 -24:00 12.00 Wash & Ream from 9,220' to 9,383'. Work thru tight spot from 9,345' to 9,330'. Ream at 2' ft/min for 32'. Backream same 32' section & log any change in parameters, continue with next 32' section with. 500 gpm & 150 rpm. 03/13/2008 00:00 -10:00 10.00 Wash & ream from 9,348' to 9,453'. Tight hole at 9388', 9398' & 9409'. 10:00 -2:00 2.00 Wash & ream at 9,453'. Start taking weight, pick up & work pipe at 9,438' & pipe stalled out & packed off. Pulled pipe free & rework section down to 9,440'. 12:00 -24:00 2.00 Re -ream section from 9,440' to 9,453'. Wash & ream from 9,453' to 9,707'. Hit refusal at 9,707'. Contact ' office about drilling back to 9,730' - desision made to stop & not expose lower zones to the 12.5 mud weight. 03/14/2008 00:00 -01:00 1.00 Ream & wash to 9,707'. 01:00 -04:00 3.00 Circ 2 bottoms up while reciprocating drill string from 9,707' to 9,669'. Shakers were clean & hole appeared to be in good shape. 04:00 -06:00 2.00 POOH from 9,707 to 8,250' (15 std's), on elevators with no problems. 06:00 -8:00 2.00 RIH from 8,250' to 9,280' where hole took 2 -3 bbl loss — surged formation. Wash from 9,280' to 9,707'. ' 08:00 -18:00 10.00 Circulate at 500 gpm, 3,250 psi & displace to fresh 12.5 ppg mud. 18:00 -20:30 2.50 POOH wet from 9,707' to 8,250'. 20:30 -22:00 1.50 Pump Slug & install wiper rubber. 22:00 -24:00 2.00 POOH from 8,250' to 5,130' - no tight spots. 03/15/2008 00:00 -06:00 6.00 Continue to POOH with BHA #6 (clean out assembly), 5,132' to surface. Found last joint of DP had missing bottom TJ & 15" of tube, along with remainder of assembly components left down hole, (BHA = 595'). Consult with Town ODE. Had tested choke manifold while tripping out, per AOGCC requirements, (250psi low /3,500psi high - 5min each test. 06:00 -06:30 0.50 Lay down last joint of DP out of hole with missing bottom tool joint & 2x DP from stand. 06:30 -09:30 3.00 Lay down 7" casing running equipment & prepare to test BOPE per AOGCC regulations. Monitor well. 09:30 -15:00 5.50 Pull wear ring & set test plug with Vetco Gray. Test BOPE per AOGCC requirements, (Annular preventer at 250 psi low /2,500 psi high - 5 min each), with all tests at 250 psi low /3,500 psi high - 5 min each & chart same. Function test accumulator system with 3,000 psi initial & 2,000 psi draw down. Recharge for 200 psi= 18 sec, with full charge at 1:38 min. 5x N2 bottles at 1,850 psi average pressure. 15:00 -16:30 1.50 Rig down BOP test equipment & blow down lines. 16:30 -7:30 1.00 Install wear bushing as per Vetco. 5 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 17:30 -0:00 2.50 Make up fishing BHA as per Baker. Pick up Bowen overshot with upper extention dressed with 4 -7/8" basket grapple & MCP & 4 -1/4" stop ring. Bowen bumper sub, Bowen oil jars & pump -out sub. I 20:00 -21:00 1.00 Service top drive, crown section, drawworks, Iron Rough Neck. 21:00 -22:00 1.00 Wait on 2 ea 4 -1/2" XH cross over subs. 22:00 -24:00 2.00 Pick up 9 joints of 6 -3/8" DC cleaning threads, Bowen acc jars & cross -over to a depth of 320'. 0 I :0 -01:00 00:00 -01:00 1.00 Make up BHA #7, (Fishing assembly with DC's & accelerator), per Baker Rep, to 324'. 01:00 -09:30 8.50 RIH with BHA #7 at controlled rate of 120 -130 fpm, to avoid surging & plugging pack off on overshot, 324 - 6,826'. Fill pipe every 4 -10 stands. 09:30 -11:00 1.50 At 6,826', assembly saw 20 -30 klbs down weight. Work tight hole from 6,826 to 6,890' with 200 gpm I flow rate & 590 psi. Had to jar up twice with 250 klbs & 325 klbs. Establish rotation with 10 rpm (3 -6 k ft#'s troque), but can not go down. 11:00 -12:00 1.00 Pull up from 6,890' to 6,788', (seemed something had fell in beside assembly). Pull 30 -70 klbs over without jarring & pipe pulled free. 12:00 -14:30 2.50 RIH from 6,788- 7,000' where experiencing differential sticking in slips. Unable to set slips & make up I stand without sticking. Make up stand, couldn't break over & had to rack back same. Would then latch on stump & able to free pipe with 50 -70 klbs over pull (no jarring) & continue to move without sticking. Pick up 3 singles DP from shed & RIH to 7,094' where able to make up stand. Pick up to break over & RIH from 7,094' to 7,566'. I 14:30 -15:00 0.50 Spot LCM across BHA to top of Torok fm. 15:00 -17:00 2.00 RIH with BHA #6 from 7,566' to 8,435'. Note: no differential sticking seen after 7,900'. Fill pipe every 3- 4 stands. 17:00 -17:30 0.50 Wash from 8,435' to 8,842', (Top of Fish - bottom of fish at 9,438'). Swallow fish from 8,842' to 8,844' with 10 rpm= 4 -6 k ft#,s rotary torque & 20 -30 klbs down weight. See pressure increase with 1.25 I bbls /min flow rate to 1450 psi, shut off pump, but pressure bleeding slightly. Establish circ with 2.5 bbls /min= 480 psi. Pull to 235 klbs & bleed off Hydraulic jar. Pull to 250 klbs with 4.2 bbls /min= 600 psi & weight bleeding off 10 — 15 klbs - slight movement observed. Continue to pull 250 — 325 klbs & allow to bleed off weight with movement seen 8,844' to 8,770'. Pull steady from 8,777' to 8,727' (180- , 275 -325 klbs pulled, without jarring). 17:30 -20:30 3.00 Pump out of hole from 8,727' to 8,546'. Pump at 175 gpm with 500 psi. Pipe pulling good. 2 0:30 -21:30 1.00 Hole looking good screw into pipe with top drive /no circ & pull from 8,546' to 8,258' - no problems. 21:30 -22:30 1.00 Hole looking good, POOH on elevators from 8,258' to 7,985'. At 7,980' pipe was pulled into a tight spot. I 22:30 -24:00 1.50 Work tight spot at 7,980. Circ good with no pack -offs, jars not firing on fishing assembly. Note: Fishing assembly may be differentially stuck not allowing jars to function. Work pipe pulling up to 400 klbs & slacking off to 40 klbs. I 03/17/2008 00:00 -03:00 3.00 Work differentially stuck pipe at 7,976' & unable to fire jar up or down. Circ at 280 gpm & 1,640 psi. Mix lube pill in pits & attempt to fire jar pulling 475 klbs. 03:00 -07:00 4.00 Continue to experience differential sticking problem. Spot 3x lube pills around BHA's & continue to slump down to 45 klbs & pull at 475 klbs. I 07:00 -11:30 4.50 Decision made by Town ODE /Rig team to mix Black Magic pill per Baroid Mud Man. Continue to torque & slump down with 5 -12 k ft#'s torque & slump down to 45 klbs string wt. Criculate at 120 gpm & 440 psi. 11:30 -12:00 0.50 Spot 40 bbls diesel pill around BHA while holding 12 k ft#'s torque & slump with 45 klbs string wt. I 12:00 -16:00 4.00 Hold 12 k ft#'s torque & slump with 45 klbs string wt. Pump .4 bbls /15 min to keep from freezing top drive. Unable to see any movement or indication of pipe coming free. 16:00 -17:00 1.00 Continue to pull up to 200 -225 klbs & torque of 12.5 k ft#'s torque & down to 45 klbs string wt, while circ bottoms up to clear 40 bbl diesel pill in well bore. Take on 48 bbls diesel in pits, along with 80 bbls Black Magic Pill from RSC. Capture diesel spacer from well bore in trip tank Note: able to I achieve 330 gpm at 2,200 psi. 17:00 -18:00 1 PJSM / pump & spot Black Magic pill, per procedure. Pump 48 bbls diesel spacer, 80 bbls Black Magic Pill, 5 bbls diesel & displace with 62 bbls mud. Torque with 15 k ft#'s & slump with 45 klbs string weight. I 18:00 -24:00 6.00 Let pipe sit still & soak with Black Magic. Move 1 bbl every hour with 40 klbs down weight & 15 k ft#'s torque, observe for any movement down. 03/18/2008 00:00 -09:00 9.00 Let Black Magic pill soak & sit with 41 klbs string wt & 15 k ft#'s rotary torque. Work every 1 -2 hrs I with torque slump down with 15 -20 k ft#'s torque. Pump 1 bbl pill per hr, per procedure. Unable to achieve any indication of movement. Perform stretch calculations based on calculated 174 k string wt= 9.65' down /4.38' up, at approx 6,700' stuck point (pull 100 klbs over). 09:00 -20:00 11.00 Attempt to circ for 1 bbl /hr spotting, (19.2 bbls since spotting). Found stand pipe froze up & unable to I circ. Break off top single DP & lay down same. Attempt to blow down with air & steam - unable. Install TIW valve to prevent diesel migration on floor from pipe. Work on unthawing stand pipe & kelly hose, (had to remove thaw & re- install same. Sim -op's: switch to gen set power to shut down Solars & re- install DSC computer program at 17:00hrs. Switch rig & RSC complex back to Solar power once completed. 1 6 1 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 20:00 -21:00 1.00 Working stuck pipe to 90% from 250 to 565 klbs pull with 15 k ft#'s torque applied. Establish circ at 3 bbl /min - no movement. I 21:00 -22:30 1.50 Schlumberger arrived & established the connection on the gooseneck for wireline work was a 2 7/8" Bowen single thread start connection. This connection available for wireline work thru Schlumberger. Replace cap & make back up to string. 22:30 -24:00 1.50 Start working torque in pipe & work pipe as per schedule of 20 k ft#'s torque & 428 klbs pull, 15 k ft#'s torque /467 klbs pull, 5 k ft#'s torque /506 klbs pull. At 23:15 hours jars started working. Jar pipe with I 20 k ft#'s torque & 428 klbs pull. 03/19/2008 00:00 -04:00 4.00 Continue working pipe as per schedule. 20K Torque & 428K Pull, 15K Torque 467K pull, 5K Torque 1 506K Pull. Fire jar, mainly mechanical Daily's downward w /20K Torque & 41K string wt., (seemed to have to fire up, before being able to get to off down). 04:00 -10:30 6.50 Unable to activate jars,Daily or Bowen to fire, in either direction. Circ bottoms up at 10 spm & 102 psi. Continue various torque & slump, slacking off to top drive wt of 41 klbs & 5 -20 k ft#'s torque. Follow schedule for upward attempts, all without success. Decision made by Town ODE to run cement plug I back, per agreement with AOGCC. 10:30 -11:00 0.50 Lay down top single DP & blow down top drive. Hold PJSM with all related services on up coming cement plug back procedures, per recommendations from Town ODE. 11:00 -12:00 1.00 Unable to cement due to Solar Turbines shutting down. Switch rig to Gen -set while down. RSC I unable to power HES pumps. Sort out issues, after Solar Turbines unable to load share with 2 Turbines on line. Switch rig back to Solar Turbine power. RSC re- booted & ensure water lines, sea water & potable in operation. Blow air through mud return line. 12:00 -13:00 1.00 Pump 2-4 bbls 12.5 ppg spacer & test cement lines to 4,500 psi - OK. Continue to pump spacer with HES pump for total of 25 bbls, followed by 39 bbls 12.5 ppg cement (Neat) & 5 bbls spacer. Chase I with 65 bbls mud at average 4.0 -4.5 bbls /min & 960 psi, (1250 psi when cement went thru tools). 13:00 -14:30 1.50 Blow down cement lines from rig to RSC. Rig down cement head pin & valve. Perform zonal derrick inspection, due to all the jarring /tight hole experienced - OK. Rig service & grease crown. 14:30 -15:00 0.50 PJSM with Schlumberger Wire Line & rig personnel on rigging up wire line equipment. I 15:00 -17:00 2.00 Pick up collar locator & free point tools. Install lubricator cap. 17:00 -20:30 3.50 RIH with SLB Free Point. Sat down at 6962', work pipe to identify free pipe. Pipe 85% free at 6,960- 6,940'. Collar locator showed tool joint at 6,920'. POOH & lay down free point tool. 03/20/2008 00:00 -05:00 5.00 No chemical cutter available, severing tool coming out of Schlumberger Deadhorse. Sim -op's: misc rig maintainence. 05:00 -07:00 2.00 Tool arrived on location at 05:03am. Unload & re head wire line with correct rope socket. Piece together severing tool per Schlumberger Operator on location. Lift tool to floor after clearing all I unnecessary personnel. 07:00 -08:30 1.50 Install through access on top drive & make up pack off. RIH with same. RIH with tool to 6,960'. Pull back to 6,788' checking previous recorded tool joint indications. RIH to 6,940' & pull up to 6,910.5', (shot depth at 6,920'). Make announcement & fire when all clear. Note: assembly saw 25 klbs drop to expected 125 klbs neutral weight. Indications from CCL indicated 2' gap from previous recorded shot 1 depth. 08:30 -10:30 2.00 POOH on wire line with Sever running tools & lay down same, (missing bottom 2'- expected). Rig down cross overs on top drive access & install blanking plug. Rack wire line off to one side of derrick. I 10:30 -11:00 0.50 Rigged down wire line tools. 11:00 -12:00 1.00 Lay down pup, change saver sub & rack back 4 stands on driller side of derrick. 12:00 -13:00 1.00 Circ bottoms up at 6566'. 13:00 -14:00 1.00 Check flow, well static, pump slug. 14:00 -17:00 3.00 POOH breaking, cleaning, inspecting each break with Tuboscope personnel. Re -dope & torque each I connection. 17:00 -18:00 1.00 Attempt to repair lifting cylinder on iron rough neck - no success. 18:00 -23:30 5.50 POOH breaking, cleaning, inspecting each break with Tuboscope personnel. Re -dope & torque each I connection. 23:30 -24:00 0.50 Install new lifting cylinder for Iron roughneck. 1 1 1 7 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time I Oooguruk ODSK -33 03/21/2008 00:00 -10:00 10.00 POOH, break each connection, clean & inspect by Tuboscope personnel. Re -dope & torque to 22.4 ft- I klbs per Nabors policy. Lay down total of 9 joints for tool marks on face. 10:00 -11:00 1.00 Found 7 gallons hydraulic spill in BOP area from air hoist. Shut down, clean up spill & replace hoist. 11:00 -12:00 1.00 POOH, break each connection, clean & inspect by Tuboscope personnel. Re -dope & torque to 22.4 ft- klbs per Nabors policy. Found joint #217 with galled threads from being broken during back off attempt. Joint #218 due to pin being severed with 1 7/8" explosive charge. I 12:00 -13:00 1.00 Clean rig floor & remove exess equipment. 13:00 -16:00 3.00 Make up cement diverter sub & RIH to 2900'. 16:00 -17:30 1.50 Held PJSM, slip & cut drill line. 17:30 -8:00 0.50 Service rig, grease top drive, crown & traveling block. I 18:00 -19:30 1.50 Repair Iron Rough Neck. 19:30 -22:00 2.50 RIH, from 2,900' to 6,920'. SLM. 22:00 -23:00 1.00 PJSM, spot 12 bbls 17.0 ppg, HiVis mud at 6,920' - top of fish. Rack back one stand & lay down 1 single to put EOP at 6,820'. 23:00 -24:00 1.00 Circ & cond mud to balance mud weight in & out. 1 03/22/2008 00:00 -00:30 0.50 Circ bottoms up at +/- 6,100', after spotting 17.0 ppg HiVis pill at 6,920' to balance mud weight in & out. 00:30 -02:30 2.00 Make up cement head pin & hose. Ensure valves on rig lined up & pump 5 bbls sea water. Shut in I cement valve & pressure test lines to 3,000psi - OK. Pump 20 bbls sea water, followed by 13.5 ppg spacer, 54 bbls 17.0 ppg cement per HES recommendations. Pump 5 bbls 13.5 ppg spacer 7 5 bbls Sea Water. The sde track plug was displaced with 55 bbls 12.2 ppg mud, after dropping wiper plug. Cement in place at 02:30. 02:30 -03:30 1.00 POOH slowly from 6,820' to +1- 6,100'. Encountered tight spot at 6,678' with 25 klbs over pull & 6,345' I with 50 klbs over pull. 03:30 -04:30 1.00 Circ bottoms up at 500 gpm & 2,700 psi. Rotate 120 rpm on top drive & reciprocate pipe constantly. Shut down pump & check for flow - static. Pump Dry Job & blow down top drive. 04:30 -09:00 4.50 POOH with cement string & lay down same. Pulled 100 klbs over at 5,470', (between Confining zone - I Torok top). Had to pump & pipe broke over with 15 ft -klbs rotary torque, but once free, no further problems. 09:00 -10:00 1.00 Pick up handling tool & pull wear ring per Vetco Gray rep. Pump out stack & install test plug in lower shoulder. Fill stack with water. Open kill line & prepare to test BOPE. 10:00 -15:00 5.00 Test BOPE per AOGCC requirements, with Mr. Lou Grimaldi as witness. Test all rams, (250psi I low /3,500 psi high), annular preventer, 250 psi low /2,500 psi high) & valves to 250 psi low /3,500 psi high. All tests 5 min's each & charted. All tests passed with no fails. Accumulator was 2,950 psi operating & 1,950 psi shut in after functioned. Took 29 sec's for initial 200 psi recharge & full system charge in 1 min & 55 sec's - OK. N2 bottles = 5x 1,800 psi average. Gas detection & LEL tested & all I passed. Inspector very satisfied with performance & results. 15:00 -17:00 2.00 Blow down choke manifold & line up valves to drill. Pull test plug with Vetco Gray Representative & install wear ring. Pick up & clean unnecessary tools /equipment. 17:00 -19:30 2.50 Make up 8 -3/4 ", 1 1/2° bent housing motor side track assembly per Sperry DD. 19:30 -20:00 0.50 Load MWD per HES. I 20:00 -21:00 1.00 Pick up BHA #8. 21:00 -21:30 0.50 Shallow test MWD at 460 gpm, 950 psi - good test. 21:30 -22:30 1.00 Pick up 14 joints HWDP & drilling jars. 22:30 -23:30 1.00 Pick up 15 joints 4" S -135 DP from pipe shed. I 23:30 -24:00 0.50 RIH on 4" S -135 to 2570'. 03/23/2008 00:00 -02:00 2.00 RIH with BHA #8, (Steerable Type), from 2,570' to 5,380'. Encountered slight bridge at 5,380'. 02:00 -04:00 2.00 Ream /wash from 5,380 to 6,232' & tag cement. Abundant filter cake based material from 5,380' to I 5,490'. At 5,490', 20' of solid ream with 15 klbs wob, with 460 gpm & 3,400 psi. Continue to Wash down from 5,510 to 6,232', where initial cement tagged, although stringy. Wash /ream cement from 6,232 to 6,480' where very hard cement encountered, (10 -15 klbs wob). Polish cement to 6,527', where side track well bore kicked off. 1 I 04:00 -06:30 2.50 Time drill 8 -3/4" hole from 6,527 to 6,532' at 1.5 min /in 10 -15% cuttings. Continue to time drill from 6,532 to 6,539' at 1 min /inch & sample indicated 50 -60% fm. Appeared to be kicked off from cement plug. Directional drill 8 -3/4" hole from 6,539 to 6,575' - all indications showed assembly off plug. 06:30 -14:00 7.50 Directional drill 8 -3/4" hole from 6,575 to 6,718'. 14:00 -14:30 0.50 Change swab in #1 pump. Circulate with #2 pump. I 14:30 -23:30 9.00 Directional drill 8 -3/4" hole from 6,718' to 7,002'. 23:30 -24:00 0.50 Repair wash in middle module discharge port #1 mud pump. Circulate with #2 mud pump. 1 8 I ' DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown ' (hrs) Time 03/24/2008 00:00 -01:30 1.50 Continue to repair wash in middle module discharge port #1 mud pump. circulate with #2 mud pump ' 115 spm, 2,800 psi, 400 gpm & reciprocate pipe 01:30 -12:00 10.50 Directional drill 8 -3/4" hole from 7,002 to 7,299'. Note: Experienced 2.0 hrs mud pump trouble while drilling ahead. 12:00 -24:00 12.00 Directional drill 8 -3/4" hole from 7,299' to 7,560'. ' 03/25/2008 00:00 -12:00 12.00 Directional drill 8 -3/4" hole from 7,560' to 7,782'. Encountered hard streak at 7,680' & performed a 200 bbl dilution at 7,742'. 12:00 -24:00 12.00 Directional drill 8 -3/4" hole from 7,782' to 7,933'. Note drill with 1 pump intermittently. ' 03/26/2008 00:00 -11:30 11.50 Directional drill 8 -3/4" hole from 7,933' to 8,190'. Encountered a hard streak/bit balling at 8,190' & decision made to stop drilling & circ bottoms up for trip out & BHA change. 11:30 -13:30 2.00 Circ 3 bottoms up. Pump HiVis /Nut plug sweep - showed little indication of cutting increase. Blow down top drive & monitor well 10 mins - static. 13:30 -18:30 5.00 POOH with BHA #8. Swab & tight hole record: 7,454- 7,408'= 50 -100 klbs over & slight swabbing. 7,408- 7,299'= 25 -50 klbs over & slight swabbing. 7,299- 7,106'= 30 -50 klbs over & no swabbing. 7,106- 6,700'= 10 -30 klbs over & no swabbing. 6,700 - 6,610'= 10 -50 klbs & some swabbing. 6,610' - unable to pull through section without swabbing & tight hole = 100+ klbs over pull. 6,610- 6,427'= pump out & back ream. ' Dress side track area from 6,575- 6,527' - wash & ream through while pumping out. Make attempt to pull out of hole on elevators from 6,427 - 6,381' with 40 -80 klbs over & swabbing, (this was to see if previous pump out section was due to dog legs &/or cutting bed buildup at side track), but indications showed formation. Unable to trip on elevators. Decision made to continue pumping out, & back ream as necessary. 18:30 -24:00 5.50 POOH with BHA #8 pumping out of the hole, & back reaming as necessary, from 6,427' to 5,837'. Multiple tight spots with some stalling. Steady cuttings & wall cake returns at shale shaker. Pulled into tight spot at 23:50 hrs at 5837' with 50 klbs over & 15 ft -klbs torq stalled on top drive. Work to free same. Full returns. 03/27/2008 00:00 -01:30 1.50 Continue to work tight hole at 5,837' with 5 -22 ft-klbs torque & slumping with 60 klbs down. Finally able to fire jar down & free up at 01:30, (had Full returns). 01:30 -10:30 9.00 Continue to pump & back ream out of well bore as unable to pull without reaming from 5,838- 3,236'. POOH without rotation into casing shoe at 3,173'. Once inside casing at 3,138' switched rig back to Solar power. 10:30 11:30 1.00 Circulate 2 bottoms up to clean up inside casing, (unloaded large amount of clays & some cement). Once hole appeared clean, pumped dry job & monitor well - static, blow down top drive & prepare to pull out of hole. 11:30 -13:00 1.50 POOH & rack back 4" DP. Well took proper fill up. 13:00 -17:30 4.50 Rack back HWDP, jars & flex collars. Lay down BHA per SSDS. Down load MWD. Break & Lay down bit. 17:30 -19:00 1.50 Service rig, grease crown, traveling blocks, swivel packing & tighten hose on top drive !BOP control. 19:00 -19:30 0.50 Install pad eyes at skate area to tail BHA components into rotary area safely. 19:30 -20:30 1.00 Pick up BHA #9 per Sperry DD & MWD. 20:30 -22:00 1.50 Pick up & load MWD. 22:00 -22:30 0.50 Break & install gasket in leaking rig mud line. 22:30 -23:30 1.00 Shallow test MWD - good test. RIH with HWDP & jars. 23:30 -24:00 0.50 RIH on 4" DP to 2050'. 03/28/2008 00:00 -01:00 1.00 RIH from 2,050' to 3,152'. 01:00 -01:30 0.50 Circulate bottoms up, break in Geo- Pilot. 01:30 -04:30 3.00 RIH from 3,152' to 7,012'. Fill pipe every 30 stands. Tag obstruction at 7,012'. 04:30 -10:00 5.50 Wash & ream from 7,012' to 8,190'. Attempt to RIH at 7,200', tagged second obstruction in hole previously tripped on elevators on trip out of hole. ' 10:00 -12:00 2.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 8,190' to 8,231' at 154 spm, 550 gpm, 4600 psi on bottom & 4500 psi off bottom, 6 -8 ft -klbs torq. 12:00 -24:00 12.00 Rotary Drill with Geo -Pilot per SSDD from 8,231' to 8,617' MD, 5,763' TVD. 03/29/2008 00:00 -12:00 12.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 8,617' to 9,080'. SPM =140, GPM =515, PSI -ON =4550, OFF =4400, TQ ON =7 -8K, TQ- OFF =6K, P /U =170K, S/0 =117K, ROT =138K, WOB =20K, ECD =13.06 PPG, ADT =10.11 HRS, TDT =21.46 HRS, JAR HRS= 76.30. 9 1 DAILY ACTIVITY (LA.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown ' (hrs) Time 12:00 -24:00 12.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 9,080' to 9,265' MD, TVD 5970'. SPM =142, GPM =500, 4450 PSI ON, WOB= 5 -25K, 6 -10K TQ ON, SPR at 9,136' #1 20 SPM =445, 40 I SPM650, #2 20 SPM =450, 40 SPM 675/ ADT =9.48. 00:00 -12:00 12.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 9,265' to 9,535'. 138 SPM, 500 GPM, 4500 PSI -ON, 4400 PSI -OFF, 8 -11K TQ -ON, 7K TQ -OFF, P /U =177K, S /0 =110K, ROT =138K, ECD =13.2 ' PPG, WOB =15 -25K, ADT =9.38 HRS, TDT =40.68 HRS, JAR HRS= 95.52. 12:00 -24:00 12.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 9,535' to 9,718'. 500 GPM, 4450 PSI -ON, 4400 PSI - OFF,TQ -ON 8 -10K, TQ -OFF 8K, 80 -150 RPM, 10 -30K WOB, P /U =190K, S /0 =100K, change out liner & swab #1 mud pump. ' 03/31/2008 00:00 -07:00 7.00 Directional drill 8 -3/4" hole with Geo -Pilot per Sperry DD from 9,718' to 9,808' MD, 6072.0' TVD. SPM =142, GPM =515, PSI ON =4450, OFF =4350 PSI, TQ- ON= 8 -10K, OFF- 7K, P /U =190K, S /0 =100K, ROT =138K, ECD =12.9 PPG, WOB =15 -25K, ADT =6.48 HRS, TDT =56.64 HRS, JAR HRS = 111.48. ' 07:00 -10:30 3.50 Circ & cond mud, observed 10 bbl loss, flow check, well static. Balance mud weight in & out to 12.5 ppg, add LCM 2 lbs/Bra-fiber & 2 lbs/steel-seal per bbl. Circ bottoms up X 4. 10:30 -12:00 1.50 POOH on elevators from 9,808' to 9711', 30 klbs over pull, pump out from 9,715' to 9,614'. Had 75 klbs over pull, ream back to 9715'. P /U =200k, S /0 =90K, ROT =140K. ' 12:00 -15:00 3.00 Back ream from 9,711' to 9,425', SPM =142, GPM =500, PSI =3350, TQ =6 -10, RPM =150. 15:00 -16:30 1.50 Ream in hole from 9,425' to 9,808'. RPM =150, GPM =500, PSI =3350, TQ =8K, check surface equipment for wash out, surface equipment OK, pressure loss down hole. 16:30 -20:00 3.50 Back ream from 9,808' to 8,653', attempt to pull each stand without circulating, then pump with 1000 psi & 77 spm, GPM =275, then add 60 RPM. ' 20:00 -22:30 2.50 POOH on elevators from 8,653' to 7,818'. Tight hole at 8,200' -225k, 8,032' -225k, 7,900' -240k, 7,818' - 250k. P /U -175K, S /0 =110K, ROT =125K. 22:30 -24:00 1.50 Work to pass tight spot at 7,818', work up to 7,814' make up top drive, break connection & wash thru to 7810'. P /U =250K, S /0 =110K, 75 SPM W/ 940 PSI. 04/01/2008 00:00 -02:30 2.50 Wash & back ream as necessary to POOH from 7,822' to 7,784'. 76 SPM, GPM =270, 930 PSI, 60 -RPM, TQ- 6 -12K. Pull on elevators from 7,784' to 6,855'. Tight at 7,746' -225k, 7,710' -235k, 7,659' -245k, 7,687' - 240k, 7,592' -240k, Normal P/U wt 175 -200k from 7,494' to 6,855'. 1 02:30 -03:00 0.50 Tight spot at 6,855', work free. Wash & ream from 6,855' to 6,815'. 03:00 -09:00 6.00 Pull on elevators from 6,815' to 6,750'. Up wt 200k, well swabbing. Pump out from 6,769' to 6,690'. Tight spot at 6690', wash & ream from 6,690' to 6,225', Stalled top drive at 6,225' with 15k, work free, when working down Rot =100, 25k less than normal, 100 psi pressure drop, TQ -3k. 09:00 -12:00 3.00 POOH on elevators - 2,025.96' of DP & BHA left in hole. DP left in hole 14 stands & 1 single. Estimated TOF= 4199', EBOF= 6,223'. 12:00 -12:30 0.50 Lay down 2 singles & clear rig floor. 12:30 -14:30 2.00 Change out saver sub & gripper dies in Can -Rig top drive. 14:30 -15:30 1.00 Rig up equipment, make up WBRT & pull wear bushing. ' 15:30 -17:00 1.50 Make up test plug, dart, floor safety valve & pump sub. 17:00 -19:30 2.50 Test BOPE per AOGCC, Pioneer & Nabors procedure. Annular 250/2500 psi, HCR's & manual wing valves, dart sub, floor safety valve, 2 top drive IBOP valves, upper & lower 4" rams, blind rams 250/3500 psi. 19:30 -20:00 0.50 Pull test plug & lay down valves. 20:00 -21:30 1.50 Make up WBRT & set wear bushing. 21:30 -24:00 2.50 Pre job safety meeting, slip & cut drill line. 04/02/2008 00:00 -01:30 1.50 Service top drive & crown. 01:30 -04:30 3.00 Pick up fishing BHA consisting of cut lip guide, series 150 over -shot with 4.875 grapple, bumper jars, oil jars, pump out sub, 9 6 -1/4" DC's & Bowen accelerator jars. 04:30 -10:30 6.00 Pick up new 4" DP from 327' to 4,187'. Drift each joint to 2.36 ". Work on pipe skate sensor (30 min). 10:30 -12:00 1.50 Wash down from 4,187' to 4,216'. Up Wt - 130K, Down Wt 100K, rot Wt 115K. 60 spm at 460 psi Torgue 5K. Tag fish at 4,216', set 25 klbs down weight. Observed 500 psi increase when engage fish. Pull 95 klbs over & start working & jarring. 12:00 -16:00 4.00 Jar fish from 4,216' to 4,163'. Max down weight 50 klbs, max up weight 325 klbs. Pumping from 121 to 500 gpm. Hole packing off. Lost fish when grapple slipped, attempt to re- engage fish, no luck. ' 16:00 -20:00 4.00 POOH from 4,163' to 326'. Monitor well at shoe. 20:00 -23:00 3.00 Rack back 3 stands of DC's, lay out jars, break down grapple & inspect - grapple showed no unusual wear other than OD of fish may be smaller due to wear. Plan to replace the 4.875" grapple with a 4.75" grapple. Change out pack -off due to wear. 23:00 -24:00 1.00 Conduct a post jarring inspection of derrick. Service rig as well during inspection. 04/03/2008 00:00 -00:30 0.50 Clean rig floor & make ready to pick up fishing BHA. 00:30 -02:30 2.00 Make up fishing BHA & run in hole to 357'. 02:30 -05:00 2.50 RIH from 367' to 4121'. 10 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown (hrs) Time 05:00 -05:30 0.50 Found leak on standpipe hammer union, repair & test to 2500 psi. 05:30 -06:00 0.50 Start washing from 4,121' to 4,163' where we tagged fish, chase fish from 4,163' to 4,266' where we noticed a 400 psi increase in pump pressure. Circulate at 266 gpm with 1350 psi. Up weight 130 klbs, down weight 100 klbs & rotating weight 118 klbs. 06:00 -07:00 1.00 Increase circ rate to 397 gpm with 2,450 psi. Jar down with no success, jar up & pull to 315 klbs & fish came free. 07:00 10:30 3.50 Pump out of hole with fish from 6,189' to 4,603', 355 gpm with 1700 psi, 25 to 95 klbs over pull. 10:30 -11:30 1.00 POOH on elevators from 4,603' to 3,154'. Up weight 135 klbs. 11:30 -12:00 0.50 Circ bottoms up at the shoe. 12:00 -13:00 1.00 POOH from 3,154' to top of fish at 2,382'. 13:00 -17:00 4.00 Lay out fishing BHA from 2,382' to 1,993'. Rack back 3 stands of DP. Lay out 3 jars, over shot & 1 joint of DP. Secure fish. 17:00 -19:30 2.50 Lay out DP from 1,993' to 642'. (42 Joints) 19:30 -22:00 2.50 Lay down BHA & rack back 5 stands of HWDP & jars. 22:00 -23:30 1.50 Down load MWD. 23:30 -24:00 0.50 Remove guts from TM hang off collar. 04/04/2008 00:00 -02:00 2.00 Lay down BHA #9, take pictures of Geo Pilot, clean off & check oil. 02:00 -04:30 2.50 RIH with 3 stands of 6 1/4" spiral drill collars & lay out same. 04:30 -05:00 0.50 Clear rig floor & prepare to pick up 4" used DP. 05:00 -07:00 2.00 RIH with used 4" DP to 3100' with clean out sub on bottom of DP. 07:00 -08:30 1.50 Lay down 4" DP from 3,100' to 2,280', pipe not coming dry, pump slug. 08:30 10:00 1.50 Lay down 4" Dp from 2,280' to 1,160' (57 jts). 10:00 -12:00 2.00 Lay down 4" DP. Check torque on connections 60 =23K, 75 =32K, 90=41K. Joints laid down - 36. 12:00 -14:00 2.00 RIH with 30 stands & clean out sub. 14:00 -14:30 0.50 Pump slug. 14:30 -18:30 4.00 Lay down used 4" DP & check torque on connections 105 =19K, 106 =32K, 107 =32K, 120 =29K, 121 =38K. Total DP laid down (90 Jts). U 18:30 -19:30 1.00 RIH with 22 stands of 4" used DP. 19:30 -20:00 0.50 Pump slug. 20:00 -23:30 3.50 Lay down used 4" DP. Total pipe laid down (66 Jts). Check torque on various connections. 23:30 -24:00 0.50 Pick up 3 joints of new 4" DP & run in hole. 04/05/2008 00:00 -04:00 4.00 Pick up rabbit & measure new 4" DP & run in hole to 3,090' 04:00 -04:30 0.50 Circulate one DP volume. 04:30 -06:30 2.00 POOH & rack back 32 stands of 4" DP. 06:30 -10:30 4.00 Pit up bit, NBS, PWD, MWD, TM & down load same. Make up one flex collar, IB Stab, 2 flex collars & 1 joint of HWDP & jars. Shallow test MWD at 225' with 420 gpm at 590 psi. 10:30 -12:00 1.50 RIH with BVHA, picking up 4" DP to a depth of 1,560'. 12:00 -13:30 1.50 Lay out 28 joints of 4" DP. 13:30 -16:30 0.50 Pump one DP volume. 17:00 -23:00 6.00 RIH on elevators from 2,912' to 8,505' where we hit refusal. Several tight spots were encountered but were able to pick up & work back thru them. Tight spots were at 4,784, 5,319, 6,865, 7,200 thru 7,360 & 8,241 thru 8,478. 23:00 -23:30 0.50 Circ & cond mud at 355 gpm with 2200 psi. 23:30 -24:00 0.50 Wash & ream from 8,505' to 8,600' with 80 rpm, 6 ft-klbs torq, 290 gpm with 1350 psi. No problems. 04/06/2008 00:00 -01:00 1.00 RIH on elevators from 8,600 to 8,700', pump from 8,700' to 8,800', 8,800' to 8,993'. RIH on elevators. Pick up 190K, slack off 95K. 01:00 -05:30 4.50 Make up top drive & wash / ream from 8,993' to 9,210', pack off problems & high torque. Pick up 200K, slack off 95K, rotary weight 135K. Torque 5K RPM 130. 05:30 -08:30 3.00 Back ream up to 9,090' & stage pump up to 425 gpm with 3050 psi. Fighting hole & stage pumps as hole allows. 08:30 -09:30 1.00 Wash & ream from 9,090' to 9,270' at 415 gpm with 2,780 psi. 09:30 -11:00 1.50 Wash & ream from 9,270 to 9,275, torqued up & packed off. Pick up single & work pipe free. Max pull 350 klbs. Circ & rotate from 9,275' to 9,238'. Stage pumps to 415 gpm at 3030 psi. 11:00 -12:00 1.00 Wash & ream from 9,238' to 9,275' at 415 gpm with 150 rpm. 12:00 -24:00 12.00 Wash & ream from 9,275 to 9,764'. Hit hard spots at 9,535' & 9,540'. Note: Prepare to dilute old mud with 500 bbls of new mud prior to wiper trip. RSC to build 200 bbls of new mud & Deadhorse plant building 300 bbls of new mud. 04/07/2008 00:00 -02:00 2.00 Wash & ream from 9,669' to 9,808'. Stage pumps up to 520 gpm at 4450 Psi. Start mud dilution with 500 bbls of new 12.5 ppg mud. 02:00 -04:00 2.00 Circ & cond mud. Work pipe from 9,808' to 9,725'. Rotate at 160 rpm & circ at 520 gpm. 04:00 -06:00 2.00 Circ & cond mud. Work pipe from 9,765' to 9,669. Rotate at 160 rpm & circ at 500 gpm. Losing mud over the shakers. Slow pump to 175 gpm & change shaker screens. 06:00 -07:00 1.00 Circ & cond mud from 9,765' to 9,669'. Circ with 500 gpm & rotate at 130 rpm. 11 I DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 07:00 -09:30 2.50 Pull short trip from 9,669' to 8,525'. Tight spots at 9,390' & 8,868'. Pulled 65 klbs over. 09:30 -10:30 1.00 RIH from 8,525' to 9,808'. Wash tight hole at 9,115'. I 10:30 -16:30 6.00 Circ & cond mud at 500 gpm with 160 rpm. Dilute mud with second 500 bbls of new mud. Stand back 1 stand every hour to prevent undercutting hole. 16:30 -17:00 0.50 Spot 35 bbl LCM pill on bottom. 17:00 -23:30 6.50 POOH from 9,808' to 6,050'. Hit tight spots at 9,570', 8,450', 7,943' (pumped at 213 gpm to get by this spot) & 6,650'. POOH to 6,050' where tight spot encountered with max pull 60 klbs over. 23:30 -24:00 0.50 Wash & ream from 6,050' to 6,029' using 390 gpm & 110 rpm. Swab on #1 mud pump out. Circ with 1 mud pump. 04/08/2008 1 00:00 -03:00 3.00 Wash & ream tight spot at 6,004' to 5,942' using 390 gpm at 2011 psi & 120 rpm. Try pulling with no pumps at 5,942' pull 60 klbs over. 03:00 -10:30 7.50 Back ream from 5,904' to 4,553'. Pump at 550 gpm with 3,490 psi & 120 rpm. 10:30 -11:30 1.00 Pump out of hole, no rotation from 4,553' to 4,264' using 550 gpm at 3,350 psi. 11:30 -15:00 3.50 POOH on elevators from 4,264' to 598'. 1 15:00 -18:30 3.50 Stand back 4 Stands of HWDP. Lay down 2 HWDP, jars, flex drill collar & MWD. 18:30 -20:00 1.50 Pull wear bushing. 20:00 -22:30 2.50 Change rams from 4" to 7 ". 22:30 -23:30 1.00 Make up 7" test tool, RIH & set. 23:30 -24:00 0.50 Test 7" rams & upper floor safety valve, test annnular & lower floor safety valve, all tests at 250 low t 3500 high & held for 5 min. as per AOGCC. Waver on complete BOP test given by Lou Grimaldi. Choke manifold tested on trip out of hole. All valves tested to 250 low & 3500 high & held for 5 min. 1 04/09/2008 00:00 -01:00 1.00 Finish testing 7" rams & floor valves as per AOGCC, Lou Grimaldi. g 01:00 -03:30 2.50 Rig up to run 7" casing. I 03:30 -04:00 0.50 Conduct safety meeting on running 7" casing. 04:00 -12:00 8.00 Make up Baker Lock, Weatherford reaming shoe, remove collars on shoe track & baker lock. Make up float & Backer Lock, fill shoe track with mud & verify shoe & float are circ. RIH with 76 joints of 7" 26# L -80 Butt to a depth of 3,121'. 12:00 -24:00 12.00 RIH with 7" 26# L -80 Butt casing from 3,121' to 9,741'. 04/10/2008 I 00:00 -00:30 0.50 RIH & land casing in wellhead - shoe at 9,793'. 00:30 -02:00 1.50 Stage pumps up to 4 bbls /min at 690 psi. 02:00 -03 :30 1.50 Circ bottoms up at 4 bbls /min. 03:30 -04:30 1.00 Rig down Franks fill up tool & rig up HES cementing head. Pump 10 bbls sea water & test lines to 1 3,500 psi. 04:30 -05:30 1.00 Drop bottom plug, mix & pump 40 dual bbl spacer mixed at 13.0 ppg, followed by 38.0 bbls (181 sks) premium cement + 0.55% Halad -344 + 0.2% CFR -3 + 0.25 Ibs /SK Super CBL + 0.25% SCR -100, mixed at 15.8 ppg, yield 1.18 with 5.18 Gal /Sx requirement. 05:30 -07:00 1.50 Drop top plug & pump 10 bbls seawater. Line up rig pumps & displace with 363 bbls of mud. Plug I did not bump. Cement in place at 06:30. Float holding. Estimated 2 bbls of cement on top of plug. 07:00 -10:00 3.00 Lay down casing equipment & rig down cement lines. Test 7" wellhead pack -off to 5000 psi & held for 10 min. 10:00 -18:30 8.50 Change upper rams from 7" to 4 ". Rig up to test BOP's & start testing as per AOGCC requirements. I Test all rams, all surface valves including Koomey draw down. Test to 250 low 3500 high & hold for 5 min. Chuck Scheeve of AOGCC waved witness. 18:30 -20:00 1.50 Pull test plug & lay down. 20:00 -22:00 2.00 Install wear bushing & break down tool. Work on Iron Roughneck, repair broken plate. 22:00 -23:30 1.50 Re- arrange pipe shed. Move MWD tools to rear so they can continue trouble shooting operation & I move 4" DP to front so it can be picked up. 23:30 -24:00 0.50 Lay down 3 joints of HWDP from derrick. 04/11/2008 00:00 -00:30 0.50 POOH & lay down HWDP (3x jts & Mule shoe). 00:30 -10:30 10.00 Pick up 180 joints of 4" DP from pipe shed & single in hole to +/- 5,800'. 10:30 -11:00 0.50 Circulate DP volume plus 60 bbls at 250 gpm = 450 psi. Move 5 stands over to Driller side of derrick. 11:00 -15:30 4.50 Blow down top drive & POOH with 4" DP & rack back on Driller side of derrick. 15:30 -16:00 0.50 Clean & clear floor of unnecessary tools. PJSM on picking up BHA #13. 1 16:00 -21:00 5.00 Pick up BHA # 13 & all related pieces. 21:00 -22:00 1.00 Test MWD & Geo -Pilot at 300 gpm with 1,900 psi. Tools working good. 22:00 -24:00 2.00 Blow down top drive & continue to pick up remaining tools of BHA # 13 & load sources. 1 04/12/2008 00:00 -02:00 2.00 Continue to load Nuke sources into MWD tool. Lay down sources carrier & get all clear sign from HES MWD Reps. Finish making up required tools for assembly while running in hole with BHA #13 to 415'. 02:00 -02:30 0.50 Shallow pulse test MWD with 275 gpm & 1804 psi (ok). Found wash pipe on top drive was leaking. 02:30 -06:00 3.50 Repair crossover swivel wash pipe assembly on Can Rig top drive. Perform Sim -Op's while working 1 on wash pipe unit & freeze protect 7" x 9 -5/8" casing annulus. Tested lines to 1,000 psi & pumped 10 12 ' DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown ' (hrs) Time bbls of 12.5 ppg mud, ( received 300 psi pressure increase). Switch to diesel & pump a total of 85 bbls, (strapped from operations storage tank), with initial injection pressure at 350 psi & final injection ' pressure at 850 psi. Final reading on casing annulus when shut in = 1,150 psi. Rig down injection lines & equipment. 06:00 -14:00 8.00 RIH with BHA #13, (RTSS type), 415' to 9,436', filling pipe as required by HES MWD, every 25 stands, (PuWt= 155K/SoWt= 105K, flow rate= 270 gpm at 2,775 psi). Assembly started to encounter some drag down (5 -10 klbs at 9,436' & decision made to wash down to top of plug rubber. ' 14:00 -15:00 1.00 Wash /ream from 9,436' to 9,682' where plug rubber was encountered, (approx 25' from float collar top), with PuWt= 135 klbs, SoWt = 105 klbs, RotWt = 115 klbs. Flow rate = 200 gpm at 2,280 psi & 238 gpm = 3,200 psi, rotary = 40 rpm on top drive at 3.5 ft -klbs torque off bottom, (slight cement across shakers seen at bottoms up). ' 15:00 -18:30 3.50 Rig to & attempt to get 3,500 psi casing test. Unable to maintain satisfactory decline. Surface check both stand pipe system /kill line system, which confirm both were not leaking, or suspect possible pressure loss. Rig up ported sub to DP stump & install TIW valve on top. Pressure up again to 3,500 psi, close TIW valve & 4" on stand pipe line, (again unable to get satisfactory results). Consult with town ODE & make final attempt with stacking weight on bit, (75K down) & staging up to 3,500psi, ' (again unsatisfactory results). Float equipment appears to be suspect & decision made to do leak off test. 18:30 -19:00 0.50 Rig to & perform leak off test with 11.4 ppg MW. Achieve 675 psi final leak off pressure = 14.4 ppg EMW. Record casing annulus pressure, (1,080psi at start/end). Rig down testing equipment. ' 19:00 -23:00 4.00 Tag up on cement at 9,682'. Drill cement from 9,682' to 9,704'. Drill plugs & float from 9,704' to 9,709'. Broke thru float, wash & ream from 9,709' to 9,735'. No cement, work back thru float, several times to ensure clear passage. 23:00 -24:00 1.00 Wash & ream from 9,735' to 9,793', tag up on shoe. No cement. Start dropping fluid level in pits for mud swap. Contact office about findings. ' 04/13/2008 00:00 -00:30 0.50 Continue to wash / ream from 9,785' to 9,793', (BBL shoe depth), with no evidence of cement in casing below float collar at 9,707'. PuWt= 185 klbs, SoWt= 107 klbs, RotWt =133 klbs, with 165 gpm = 1,440 ' psi, 20 rpm = 6 ft -klbs torq off bottom. 00:30 -04:30 4.00 Circ out mud to fresh 10.6 ppg KCL/Polymer type at 165gpm = 1,440psi. Shut down, clean out pits & trasnfer mud from RSC to rig. 04:30 -05:00 0.50 Service rig & top drive system. 05:00 -07:00 2.00 Drill out barrel shoe with 40 rpm = 6 ft -klbs off /6 -8 ft -klbs torq on, 2 -5 klbs WOB, 270 gpm = 2,210 psi. ' Able to drill out without incidents or problems, work pipe 4x to ensure clear for tools, (saw slight bobble of torque 7 -9.8 ft -klbs on second pass up). Continue to clean out rat hole, from 9,793' to 9,808' with out incidents. 07:00 -07:30 0.50 Drill 6 -1/8" hole from 9,808' to 9,828' with 2 -5 klbs WOB, 60 -80 rpms on = 5 -6 ft -klbs off /6 -8 k -ftlbs on ' torque, 270 gpm = 2,210 psi. 07:30 -08:00 0.50 POOH into casing at 9,763' & circulate bottoms up prior to leak off test. 08:00 -09:30 1.50 Rig up to perform leak off test. Position tool joint inside BOP & close top pipe rams & open kill line. Line up to pump down both sides & initiate leak off test with 10.5 ppg MW = 13.8 ppg EMW (0.6# from LOT #1). Break over point was 1,050 psi, (Casing Annulus = 1,000 psi start/end). Rig down test ' equipment & consult town ODE. 09:30 -12:30 3.00 Pre job safety meeting / slip & cut 10 wraps off drum of line per Nabors Ton Mile schedule. 12:30 -13:00 0.50 Service rig & top drive, (mix dry job). 13:00 -23:00 10.00 Pump dry job & blow down top drive, (hole static). POOH with BHA #13 for RTTS. 23:00 -24:00 1.00 Rack back heavy weight DP, flex drill collar, remove source & shut MWD Tool Down & Rack Back. 04/14/2008 00:00 -01:30 1.50 Handle BHA #13 tools, lay down rest of unnecessary MWD components after being down loaded, break off bit, (Graded: 0- 0- NO- A- X -I -NO -BHA), & lay down Geo Pilot. 01:30 -02:00 0.50 Pick up & make up BHA #14, (RTTS), per HES Rep, (DP only). 02:00 -08:30 6.50 RIH with RTTS at 1 min /std, per HES Rep's request to 9,650'. 08:30 -10:00 1.50 Set RTTS per HES procedure. Break circ for 5 min's, (Wash area elements setting at). Proceed with 3 wraps to right & set with 20 klbs extra down from 115 klbs SoWt. Pressure up to 3,650 psi without ' issues & chart same, with 3,550 psi final pressure, (1/2 hr test = 2.7% diff - good). Unseat RTTS per HES Rep & prepare to POOH with same. 10:00 -17:30 7.50 POOH 2 stands to ensure no problems swabbing with RTTS. Pump dry job & blow down top drive - flow check static. POOH with RTTS without incidents. 17:30 -18:00 0.50 Pick up Geo - Pilot, bit & smart tool. Circulate to warm tool up. ' 18:00 -20:00 2.00 Break off Smart Tool, service same & blow down top drive. 20:00 -21:00 1.00 Pick up & plug into Smart Tool, turn it on & load same. 21:00 -21:30 0.50 Shallow test MWD at 242 gpm & 1500 psi. 21:30 -22:00 0.50 Hold pre -job meeting on handling sources, remove hands from floor & load sources. ' 22:00 -23:00 1.00 Pick up flex collars, HWDP & jars. 23:00 -24:00 1.00 RIH from 415' to 2,826', filling DP every 25 stands. 1 13 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown (hrs) Time 04/15/2008 00:00 -04:00 4.00 Continue to RIH with BHA #15 from 2,826' to 7,651' without incidents. Fill pipe every 25 stands as requested & made several attempts to down link to Geo- Pilot, (unsuccessful). 04:00 -04:30 0.50 Service rig & top drive — change out saver sub. 04:30 -06:30 2.00 Continue to RIH with BHA #15, from 7,651' to 9,667' without incidents. 06:30 -07:00 0.50 Wash from 9,667' to 9,828', while circ bottoms up — max 525 units trip gas. No fill observed. 07:00 -14:00 7.00 Trouble shoot down linking problems with MWD & Geo - pilot. Change out 4 choke without any effect. Work on surface software issues, again without success. Mobilize crane & change out Geo span unit on floor without success. Continue to sort out surface software issues. Finally able to get manual setting to Geo - Pilot. MWD logging tools working & decision made to drill 30' for Modified Salt exit strategy. Circulate with various rates to assist with down linking problem: 230gpm / 1,550psi, 250gpm / 1.920psi, 275gpm / 2,210psi. Rotate with 40 rpm on & 4 -5 ft -klbs off bottom torque. 14:00 -16:00 2.00 Directional drill 6 -1/8" hole, after being able to manually set Geo -Pilot to desire setting, (although set at default setting of 80% deflection). Drill from 9,828' to 9,845'. Encountered drilling break of 3-4'. Bit took no weight & losses occurred at 120 bbls /hr. Pulled up & monitored well bore in static condition, (82 bbls /hr loss rate). Decision made to continue drilling ahead, to have cuttings aid in sealing fracture & mix 15 bbls of 75 ppb Ca carbonate 50 pill, with N -vis added for viscosity, until gnarly looking. Drill from 9,845' to 9,871' with 6 -10 klbs WOB, 60 -80 rpms & 4 -5 ft-klbs off / 5 -6 ft -klbs on bottom rotary torque. Used caution when bit at 9,795', Geo -Pilot Referrence Housing /Cutters at 9,806', Smart Stab at 9,833', coming through BBL shoe, (slowed to 40 -50 rpm's). Plan to do same at 9,925' when IBS Stab also coming through BBL shoe. 16:00 -16:30 0.50 Spot Ca carbonate pill with 1,100 strokes & shut down. POOH slowly to 9,787' & wait on pill to settle into fracture for 10 min's. Start pump & go in hole slowly to apply ECD pressure to help force pill into fracture. Shut down & monitor loss = 16 bbls /hr. Decsion made to continue drilling. RIH to bottom. 16:30 -18:30 2.00 Directional drill 6 -1/8" hole from 9,871' to 9,967 at 230 gpm, 1325 psi, 6 to 10 klbs WOB, 110 to 120 rpm & 10 ft-klbs torque. Losing at a rate of 120 bbls/ hr. Hit a possible fracture at 9,958' & saw higher torque & bit bounce. Return flow which had been at 70% stopped for about 4 min & slowly came back. 18:30 -21:00 2.50 Spot Ca Carbonate pill with1,100 strokes at 9,964' & shut down down. Pull out slowly to 9,787' & wait on pill to settle into fracture for 20 min'. Losing mud at 60 bbls /hr. Move all available mud to active system - volume down to 225 bbls. Call office & decision made to spot another pill, monitor well & build more volume. Rig crews, RSC & Dead Horse plant building volume. 21:00 -24:00 3.00 Spot Ca Carbonate pill with 1,100 strokes at 9785' & shut down down. Lost 53 bbls while spotting pill. Volume down to 165 bbls. Monitor well - initall losses at 60 bbls /hr static are down to 20 bbls /hr. Build Volume in pits. Rig crew, RSC, Dead Horse plant all building volume. Storm died down & Dead Horse plant sending 300 bbls to be followed with another 300 bbls - arrival time estimated at 02:00 hrs. 04/16/2008 00:00 -08:00 8.00 Rig crew, RSC, Dead Horse plant all building volume. Dead Horse plant sending 300 bbls to be followed with another 300 bbls. arrival time estimated at 04:00- 08:00. Circ over top of hole to ensure full with 9 -10 bbls /hr losses recorded. Attempt to stage pumps up at 04:00, with 35 -170 gpm / 60 -80 bbls /hr losses & 170 -230 gpm / 120 bbls /hr losses. Mix & spot 25 bbl's Ca carbonate pill & allow to soak while building volume - 7 -8 bbls /hr loss rate. Pits on rig built back to 750 bbls, 200 bbls in RSC, 150 bbls in upright storage & 600 bbls in Super Vac's on location . 08:00 -08:30 0.50 Make up top drive. Wash From 9,766' to 9,967' at 250 gpm & 1260 psi, with 80 bbls /hr losses. 08:30 -12:00 3.50 Directional drill 6 -1/8" hole 9967' to 10159'. Total losses this tours 414 bbls. Losses= 80 -120 bbls /hr. 12:00 -14:00 2.00 Directional drill 6 -1/8" hole 10,159 to 10,422'. Lost total returns, +/ -120 bbls /hr rate to 10422' & 100% losses = +324 bbls /hr rate from 10,421 to 10448' . 14:00 -16:00 2.00 Monitor well while, spotting 30 bbls of 75 ppb Ca carbonate LCM pill, (25 ppb of 25- 150 -50 each & N- Vis. Spotted with 1,250 strokes, with 100% Losses = 140+ bbls. Pulled slowly to shoe with light swab. Rotate pipe to alleviate swab, 10,448' to 9763'. 16:00 -24:00 8.00 Fill across top of annulus to maintain hole full with bit at 9763'. Wait on Form -A -Plug material & personnel to arrive. Clean mix pit & slug pit thoroughly. 04/17/2008 00:00 -03:30 3.50 Inspect tanks per MI Representative, fill with 40 bbls fresh water, Mix spacer, pump Form -A -Plug pill from vac truck to slug pit. Held PJSM. 03:30 -04:00 0.50 TIH to 10448' from 9,773'. Tight spots at 9812'= 20k, 9,973= 10 -15k, 10,165'= 10 -25k, 10,448' over pull off bottom 25k. 04:00 -04:30 0.50 Pump 15 bbls 10.0 ppg spacer while adding 40 sxs MI accelerator to Form -A -Plug. 04:30 -05:00 0.50 Pumped 40 bbls Form -A -Plug. Displace with 110 bbls 9.9 ppg mud. 05:00 -07:30 2.50 Pill in place. POOH to 9,280'. Well attempting swab when pulling on elevators. Make up top drive & rotate each stand out to alleviate swabbing. Total of 22 bbls gained for POOH. 07:30 -10:00 2.50 Attempt to establish circ through drill string - unsuccessful with 3,000, 4,000 or 4,700 psi. Rotate with 80 -100 rpm to attempt clearing around bottom of the assembly. Surge pipe with pressure & wait on pressure - unsuccessful in attempts to regain circ. 10:00 -11:30 1.50 Close annular preventer. Open kill line & perform Hesitation Squeeeze with 2.2 bbls & 180 psi, (bled to 120 psi). Continue to bump with 5 -10 strokes every 5 min with 280 -300 psi showing, which bled off to 100 -120 psi, (total= 13.89 bbls). 14 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown I (hrs) Time 11:30 -13:00 1.50 Open bleeder & bleed 5 bbls total fluid to strapped trip tank volume - flow not slowing down. Shut in bleeder & monitor pressures, (ISIP= 140 psi, FSIP = 155 psi after 1 hr). MW required to handle I pressure was 10.2 -10.3 ppg MW. Consult Town ODE & decision made to bull head 40 bbls fluid. 13:00 -14:00 1.00 Pump 40 bbls 9.9ppg MW down back side to ensure well pressures stabilize, at 53gpm= 380 -400 psi. ISP =140 psi & flow back 2 bbls at 2.0 - 2.5 min /bbl. FSIP= 115 -120 psi & build to 150 psi at 15 min. 14:00 -16:00 2.00 Attempt to pump down drill string - unsuccessful despite all attempt. Bleed off annulus & open annular preventer. Flow back 8 bbls at 2.0 -3.5 min /bbl for 5 bbls & 1.5 -2.0 min /bbl for 3 bbls. Shut in I with annular prevention. ISIP= 150 psi & 190 psi at 20 min FSIP. Continue to monitor pressure & consult Town ODE. Attempt to bleed off with another 5 bbls. Open annular after bleeding through choke, but flow increasing, (oil /gas migration to surface). Shut back in with ISIP of 105 psi & continue to monitor pressures, 234 psi at 20 min. Consult with Town ODE & mix 300 bbls of 10.5 ppg heavy I mud weight. 16:00 -17:00 1.00 Pump 110 bbls of 10.5 ppg mud down back side, with 1420 strokes total at 243 gpm / 1380 psi. Monitor well for 10min FSIP= 81 psi. 17:00 -19:00 2.00 Open bleeder & bled off pressure. Open annular preventer with no fluid visible in stack. Fill stack with 11 bbls 10.5 ppg mud. Losses 16 -18 bbls /hr after 45 min. I 19:00 -24:00 5.00 Broke out TIW valve, pulled one stand & monitored well for 15min. Well took 2 bbls to fill. Actual Toss due to steel displacement 0.5 bbls. POOH from 9,280' to 7,863'. Used constant hole fill while pulling pipe. Stopped & verified well still taking fluid with pipe static at multiple areas & when hole fill not following calculated volumes. Hole showed slower loss rate when pipe was moved up than when I pipe static. Each time well checked for static losses they varied from 8 -12 bbls /hr. 04/18/2008 00:00 -06:30 6.50 POOH with BHA #15 from 7,843' to 5,528' - pull 5 stands & fill annulus with 10.5 ppg mud. Monitor well every 5 stands with 12 -16 bbls /hr losses. I 06:30 -13:30 7.00 POOH from 5,528' to 3,695', but back reaming at 100 rpm to alleviate filling problems, as pipe not taking proper hole fill. Note: At stand #51= 5,432' started seeing cottage cheese type material -later found to be Ca carbonate mud with Polymer coming out, due to exposure to high Ph of Forma -plug operation. This continued to 4,563' where Rabbit was found. Hooked up air to the mud line & blew air 111 through each stand with top drive, prior to racking back. Total losses at 12:00 pm= 69 bbls. Stand #43 was full of Forma -plug material, which continued to be blown out & bagged for disposal. At 3,695' unable to blow through DP. Consult town ODE & decision made to lay down 102 joints, as faster & DP filled solid. Losses continued to increase as more drill string pulled & at +/- 3,800', decision made to mix & fill back side with 50 bbls of 10.2 ppg 40 ppb Ca carbonate mud - losses at 18 bbls /hr. I 13:30 -19:30 6.00 Begin to lay down a total of 102 joints of plugged DP from 3,695' to 2,100'. Back ream while flow checking to get proper fluid down back side. Cap both pin & box ends to contain any loose material inside pipe, (pretty much solid plug of Forma -plug with consistency of dried silicone). Back ream every 5th single to help with hole filling - 8 -12 bbls /hr losses. At 2,100' losses quit & unable to pull 1 pipe without swabbing. 19:30 -20:30 1.00 Close ram & bull headed 15 bbls of 10.0 ppg mud at 40 spm & 450 psi. Checked for pressure, opened rams & mud fell 6 -8' in annulus, well static. Closed ram & bull headed 10 bbls of 10.0 ppg mud for at total of 25 bbls at 450 psi. Checked for pressure & opened ram. Fluid 6 -8' in annulus, rotated pipe in attempt to have mud go down. 20:30 -22:30 2.00 Pull 5 joints, rotating each - well swabbed 1.5 bbls. Closed ram bull head 15 bbls of 10.0 ppg mud at 50 spm & 525 psi. Fluid 3' down in annulus. Pulled to 1920' observed slight swab, observed well & showed slight flow on flow line. Shut in well - no pressure. Bull head 40 bbls of 10.5 ppg mud at 50 spm & 450 psi ( +/ -29 bbls annulus volume from surface to bit). Checked pressure - zero, opened ram, I well static, pulled 1 joint & fluid lowered 2' in annulus. 22:30 -23:30 1.00 Lay down 10 joints DP to 1,511' with close to normal fill up. 23:30 -24:00 0.50 Close ram, bull head 15 bbls of 10.5 ppg mud at 50 spm & 400 psi. Checked pressure & opened ram - well static. I 04/19/2008 00:00 -02:30 2.50 Continue to POOH with BHA #15 from 1,511' to 415' filling well bore every 5 joints. 02:30 -03:00 0.50 Flow check well bore for 10 min - flowing. Bull head 30 bbls 10.0 ppg mud at 5 bbls /min & 580 psi. Open bleeder & open well bore to flow check - 2 -4 bbls /hr losses. ' 03:00 -07:00 4.00 Handle BHA #15 components. Lay down 5x 4" HWDP, 4 -3/4" drilling jar, 3x NM Flex collars. PJSM & remove nuke sources from LWD tools. Plug into & down load MWD /power down. Lay down MWD tools & POOH to bit (all BHA tools were clean). Break off bit & install clamp on Geo- pilot, lay down same. Bit graded: 0- 0- WT- A- X- PN -HP. 07:00 -07:30 0.50 Well bore flowing slightly. Consult Town ODE & decision made to bull head 40 bbls 10.0 ppg 1 mud down back side. Open bleeder & check pressure, (2 -3 bbls /hr losses). Pump at 6 bbls /min & 790 psi. 07:30 -10:00 2.50 Flow check well bore, 2 -3 bbls /hr losses. Clear floor of unnecessary tools, pull wear bushing per Vetco Gray Rep. Install test plug & RILDS. Rig up kill line to OA valve, (in case needing to fill), & I bleeder for monitoring well bore. Pull & lay down mouse hole. 10:00 -13:00 3.00 Test BOPE per AOGCC requirements 1x annular preventer, (250 psi low / 2,500 psi high), 3x Rams, 4x safety valves, 1x choke line valve, 2x HCR valve & 1x kill line valve, (250psi low / 3,500 psi high). Function test accumulator system, with 3,000 psi initial pressure, 2,000 psi after functioning. Took 22 sec to reach 200 psi re- charge & 1:37 sec full charge, (5x Nitrogen bottles= 1,950psi average). All gas detection monitors were checked & logged in Nabors log book. Choke manifold had been tested on 15 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown (hrs) Time the way out of the hole= 14x valves, (250 psi low / 3,500 psi high). Mr. Bob Noble waived witness for State. 13:00 -14:00 1.00 Bull head 10 bbls mud, after opened OA valve well head to check for flow,(4 bbls /hr rate). Shut down & check for flow, but still have 1 -2 bbls /hr flow rates. Bull Head 10 more bbls at 65 spm & 590 psi. Shut down & check flow - static with no returns out of OA valve. Back off LDS & pull test plug. Re- install wear ring per Vetco Gray Rep & RILDS. Clear floor of unecessary tools & lay down test joint. 14:00 -16:00 2.00 Ensure choke manifold Tined up for drilling & RIH 17 stands DP from Derrick with cement stinger on bottom, to +/- 1,632', (1 -2 bbls /hr losses). 16:00 -18:30 2.50 Pump 10 bbls Nut plug /SAPP pill, followed by plug wiper. Displace & circ bottoms up, but gas climbed to 3,500 units, so continued to circulate until gas dropped back below 500 units. Check for flow - slight flow. Continue to circ & mix/pump 50 bbls 10.5ppg mud. Pump 16 bbls mud & check for flow - ' 3-4 bbls /hr losses. 18:30 -20:00 1.50 POOH - well taking excess hole fill. Loss rate after out of hole 8 bbls /hr. 20:00 -20:30 0.50 Observe well while rigging up to pick up BHA losing 8 bbls /hr. 20:30 -24:00 3.50 Make up new Geo -pilot BHA #16 with 6 1/8" Bit. Install nuke sources & upload MWD. Total losses for 24hr= 247 bbls. Total losses for well= 2,947 bbls. 04/20/2008 00:00 -02:30 2.50 Finish picking up BHA #16, (6 -1/8" Lateral RTSS Type), add remainder of components per HES DD /MWD Tech's & 5x HWDP & drlg jar to 427'. 02:30 -04:00 1.50 RIH with BHA #16 from 427' to 3362'. Break in Geo -pilot seals with 5 rpm & up to 60 rpm - raise 5 rpm every min. 04:00 -06:00 2.00 Once Geo -pilot seals broken in, establish circ staged to 60 spm & 213 gpm, (lost 7.5 bbls RIH). Circ bottoms up with 10.0 ppg mud & see 44 bbls losses= 14.5% pumping lost ratio. Gas seen at surface was 3,520 units & decision made to Spot 40 bbls of 10.5 ppg mud on back side to control slight flow. Saw approx 1 bbl of Forma - set -plug come across shakers, with good oil shows coming out of solution. Note: Running degasser with 30 #'s vacuum showing. 06:00 -08:00 2.00 Continue to RIH with BHA #16 from 3,322' to 7,180'. Experienced 3 bbls loss, despite running speed tried. Monitor well as RIH & check for any flow. 08:00 -09:00 1.00 Establish circ & staged rate to 60 spm= 213gpm at 1,450 psi. Rotate & work drill string. Losses continued with 42 bbls lost while circ bottoms up with 10.0 ppg mud= 13.8% loss ratio pumping. Gas climbed to 1,050 units, with break out seen at surface, (some oil). Circulated additional 500 strokes after monitoring well & slight trickle seen, (after 500 strokes, gas= 287 unit). Slight traces of Forma- set-plug seen across shakers. Monitor well - static. 09:00 -10:45 1.75 RIH with BHA #16 from 3,322' to 9,780', checking well for flow every 5 stands. Well static on checks & losses of 2.5 bbls while RIH. 10:45 -11:30 0.75 Establish circ at 9,780' & rotate at 40 rpm with 3 -5 ft -klbs off bottom torque. Circ at 190 gpm= 1,310 psi with 271 bbls /hr losses= 100% loss while pumping ratio. Unable to circ 10.0 ppg mud around, so decision made to continue to run to bottom. 11:30 -12:30 1.00 Attempt to RIH with BHA #16 from 9,780' to 9,815', where WOB increased to 10 -12 klbs. Wash /ream from 9,815' to 9,980' - some slight tight spots. Washed at 40 rpm, 5 -6 ft -klbs off bottom torque, 143 gpm= 950 psi, with 100% loss ratio at 192 bbls /hr. 12:30 -13:00 0.50 RIH with BHA #16 from 9,880' to 10,270', where saw some 10 -12 klbs WOB stacking. Experience 18 -24 bbls /hr losses & fill back side with 10.0 ppg mud (10 bbls loss). 13:00 -13:30 0.50 Wash /ream from 10,207' to 10,448' with 42 spm= 147gpm at 900 psi, (100% loss ratio at 192 bbls /hr rate). 13:30 -24:00 10.50 Commence drilling 6 -1/8" hole in lateral section, per Sperry DD from 10,448' to 10,945'. Experiencing 100% losses at 177 gpm = 250 bbls /hr Toss rate at 1,330 psi. Continue to stage up WOB to 12 -14 klbs with 120 -130 rpm & 3 -5 ft-klbs off bottom / 7 -11 ft-klbs on bottom torq. Continue to drill ahead, while lining up water pump for Mud Cap drilling procedure. Road built & holes augered in ice & found suitable supply (ran 1/32" screen on suction). Mixed & pumped 50 bbls 75 ppb (150/50 Ca carbonate sweep) without any effects on return. Note: 100% losses at 10,655'. Consulted Town ODE & made decision to MUD cap drill with sea water down DP & fill back side constantly with 10.0 ppg mud. Experienced deflection UP around 10,800', reamed to lower angle several times with minimal success. Decision made to drill ahead & found area approximately 10,900 able to drop angle. Drilling with mud cap from 21:00 hrs, at 10,948' using sea water down drill string. Total losses this 24 hours =2326 bbls. Aprox 800 bbls sea water lost to hole since 21:00 hrs. 04/21 /2008 00:00 -16:30 16.50 Continue to Mud Cap drill from 11,042' to 12,055', using various drilling parameters at surface, to try & get assembly to drop inclination, (have had problems with Geo -Pilot since +/- 11,418'). The Geo -Pilot unresponsive to data being provide at surface & indicating the Hydraulic lock mechanism is not functioning properly, (i.e. set at 80% deflection & get over 100% deflection, usually 105 - 113 %) & tool isn't design to go over 100 %. Continue to try to use drilling parameters, (usually low ROP, high RPM, min WOB), which would cause drop tendencies & 3 -4 degree /100' right hand walk, which was required for staying in Drillers Polygon. Using 2 -4 / 8 -12 klbs WOB, 80 -140 rpm on top drive, with 12 -13 ft -klbs off / 13 -15 ft-klbs on bottom torque, 213 gpm & 1,750psi, with 100% losses= 304 bbls /hr. Decision was made with Town ODE, Town Geology Representatives & Pioneer Management to attempt pulling back to 10,780' to side track into Lower Kuparuk Fm. 16:30 -20:30 4.00 Pump & rotate out of hole from 1,2055' to 10,780'. Maintain hole full on annulus side with fill pump & pumping down DP with 10.0 ppg mud - no exess drag or torque. 16 ' DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown (hrs) Time 20:30 -23:00 2.50 Begin time drill at 1 /10th of foot per 3 min from 10780' to 10784.6'. Lost power line power at 21:20 hrs. Started rig generator & restarted all equipment. Continued to time drill until 22:50 hrs MWD quit ' working. Trouble shoot MWD. Attempted to down link, hard boot system, cycle pumps, pumped 30 bbls mud & surged pipe in attempt to restart MWD - no success. Discussed with Town ODE & decision made to attempt time drill to low side well as long as some indication showed that we were seeing departure from old well bore, (ie: WOB when slack off, ROP to show in faster drilling Kuparuk formation). 1 04/22/2008 00:00 -10:30 10.50 Attempt to side track from 10,784' to 10,820' at 3 min /in, to 10,800' & 1 min /in to 10,820'. Calculations indicated assembly should be approx 1' away, so attempted to feel for a ledge. Shut down pump & rotary. Slowly stacked 15 -20 klbs (drag= same 15 -20K), but fell off into old hole. Contacted Town ODE & decision made to POOH for completion operations. 10:30 -13:30 3.00 Pump110 bbls of 10.0 ppg mud to displace inside DP as Sea Water was unbalanced in hole, (over filling pipe on connections). Once completed, slowly pumped at 20 spm, 71 gpm & 500psi, with 101 bbls /hr losses, (100%). Assembly was rotated at 40 rpm, 9 ft -klbs torque off bottom & assembly POOH from 10,820' to 9,714', with minor bobbles seen - usually 5 -10 klbs over. Total losses pumping out 263 bbls of mud, including 110 bbls to displace. 13:30 -14:00 0.50 Attempted to stage up to circ inside casing, but unable to establish circ. Losses= 48 bbls mud. 14:00 -24:00 10.00 Continue to pump out of hole at 20 spm, 71 gpm, 450 psi, 40 rpm, & 6 ft-klbs torq with 101 bbls /hr ' losses, (100 %). POOH from 9,714' to 5,262'. Total losses pumping out = 550 bbls of mud. Flow checks performed every 10 stands out of hole. Note: Well static when pipe movement halted. 04/23/2008 00:00 -03:30 3.50 POOH pumping at 20 spm, 500 psi, 50 rpm due to swabbing from 5,262' to 2,930'. Check flow every ' 1,000' for 15 min. 03:30 -04:30 1.00 Circ bottoms up at 2,939', due to swabbing while POOH. Circ at 60 spm, 1,200psi, 40 rpm & 3-4 ft-klbs off bottom torque. Gas peaked at 1,630 units while circulating. Attempt to keep well from flowing while static, but unable with 10.0 ppg mud. Shut annular preventer & monitor pressures - 40psi. 04:30 -07:30 3.00 Well bore had 50 bbls of 10.0 ppg mud. Bull head in, but still flowing when bleeder open. Decision was made to bull head another 60 bbls of 10.5 ppg mud 50spm & 600 psi. Monitor well & bleed off pressure through bleeder, but still showing slight flow after 10 min. Decision made to to shut in, where pressure built to 70 psi. Bull head another 50 bbls of 10.5 ppg mud, where pressure finally decreasing to 40 psi SIP. Another 50 bbls of 10.5 ppg mud was bull headed in at 65 spm, 800 psi & 1 monitor, where pressure bled off to zero. Open annular preventer - well bore static & static afterl0 min. 07:30 -10:30 3.00 POOH & monitor every 5 stands. Hole static, but not taking proper hole fill 2,930' to 2,453'. Bull head 10 bbls to ensure back side full. POOH with BHA #16 from 2,453 to 1,778', where again hole wasn't flowing, but also not taking proper fill . Bull head another 20 bbls of 10.5 ppg mud. Continue to POOH from 1,778' to 1,295' - slight flow. Well shut in while changing grabber dies on top drive with ISIP of 10 psi. 10:30 -11:30 1.00 Change out top drive grabber dies & service top drive. 11:30 -12:30 1.00 Bleed off FSIP of 30 psi & open annular preventer with 2 -3 bbls /hr flow rate recorded. Shut in & bull head 50 bbls of 10.5 ppg mud. Monitor pressure, (3 psi), & bleed off same. Open annular preventer - well bore static. Pump out 1,298' to 579' with 20 spm & 350 psi at 100% losses, (Well Bore static) = 71 bbls /hr loss rate. ' 04/24/2008 00:00 -00:30 0.50 Continue to make up 6 -1/8" Weatherford casing scraper, per recommendation of Representative, (all DP ran). 00:30 -01:00 0.50 RIH with casing scraper to 977'. 01:00 -02:30 1.50 PJSM. Slip & cut drilling line per Tool Pushers recommendations. 02:30 08:00 5.50 RIH with casing scraper from 977' to 9,658' without incidents. Fill pipe at 3,388', 7,250' & 9,658' with average losses at 2 -3 bbls per 5 stands ran. 08:00 -11:00 3.00 Shut in annular preventor & line up to bull head fluid down back side. Start bull heading 575 bbls of fresh 10.5 ppg mud down backside, staging to 75 spm, 277 gpm & annular at 1300 psi setting. Had some trouble with annular pressure bleeding off due to regulator valve leaking, but able to repair without shutting down. Begin to move pipe between tool joints & 75 spm &1,10 psi. At 6,800 strokes, completed operation & bled off 3 -5 psi FSIP showing no flow. Open annular preventor & monitor well bore - static. 11:00 24:00 13.0 Commence pumping out of the hole at 25 spm, 89 gpm, with 100% losses, (well bore static). Monitor ' well every 10 stands as precaution. POOH from 9,658' to 1,749'. Test choke manifold while POOH with 250 / 3,500 psi. Total lost mud this 24 hours 1270 bbls. 04/25/2008 ' 00:00 -02:00 2.00 Pump out of hole from 1749' to surface. Monitor well at 977' for 15 min - 2 bbls static loss. 02:00 -03:00 1.00 Lay down single, break & lay down bit, scraper & bit sub. Pick single back up. 03:00 -04:30 1.50 Pull mouse hole, rig up line to trip tank for filling & monitoring during BOP test. Pull wear ring, set test plug & lock same down. 04:30 -06:30 2.00 Change upper rams to 2 7/8" fixed & lower rams to 3 1/2" fixed. 06:30 -07:00 0.50 Fill stack with water & rig up lines to test. 17 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSK -33PB1 and ODSK -33 Time Elapsed Operations Breakdown ' (hrs) Time 07:00 -09:30 2.50 Test BOPE, per AOGCC, PNR & NAD guide lines & procedures. Annular 250/2500, rams, choke valves, top drive upper & lower IBOP, safety valve & IBOP valve 250/3500 psi. Performed Koomey test. ' 09:30 -10:30 1.00 Pull test plug, clear rig floor of test equipment. 10:30 -11:30 1.00 Rig up to run completion tubing. Bull head 375 bbls of 10.5 ppg brine at 1500 psi. Rig down hoses to internal annulus. 11:30 -15:30 4.00 Rig up equipment to run down hole pumps, hand ESP control sheave, pull lines to rig floor. Rig up tools & spot units. 15:30 -18:30 3.00 Held PJSM, make up down hole pump motors. 18:30 -22:30 4.00 Losses increased to170 bbls /hr with 10.5 ppg brine. Lined up on sea water after brine reserves exhausted. Pumped 77 bbls sea water & losses slowed to 1.5 bbls /hr. Prepare 200 bbls 10.2 ppg brine, clean pits & transfer to pit room from RSC. 22:30 -24:00 1.50 Finish making up motors for ESP & install control lines. 04/26/2008 00:00 -01:30 1.50 Make up down hole pumps & connect control lines. Test all for correct operation. 01:30 -12:00 10.50 Held PJSM running ESP. Run completion 2 -7/8 L -80, IBT -M, 6.5# tubing from 66' to 4,765'. Install ' Canon clamps each joint for 1 -10 joints & every other joint there after. Test ESP cable every 1,000'. 12:00 -14:00 2.00 Held PJSM for running ESP. Run completion 2 -7/8 L -80, IBT -M, 6.5# tubing from 4,765' to 5,522'. Install Canon Clamps every other joint. Test ESP cable every 1,000'. 14:00 -17:00 3.00 Pick up pups & packer cut ESP cable & change out ESP spool. Pull new ESP cable to floor. 17:00 -19:30 2.50 Slice ESP cable & test same. Connect control line & test to 5000 psi. 19:30 -21:00 1.50 Run 2 -7/8 tubing with ESP, installing Canon clamps every other connection from 5,602' to 6,042'. Note: 103 2 -7/8" clamps used. 21:00 -22:00 1.00 Change out 2 7/8" handling tools for 3 1/2" equipment. 22:00 -24:00 2.00 Run 3 1/2" tubing L -80, IBT -M, 9.3# installing Canon clamps every other connection from 6042' to ' 6704'. Install GLM & pups. Test every 1,000'. 04/27/2008 00:00 -04:00 4.00 Run completion assembly, down hole pumps with control lines from 6,704' to 8,794'. Test ESP cable ' every 1,000'. Install Canon clamps every other joint. 04:00 -05:00 1.00 Pick up ScSSSV assembly, make up control lines & test same to 5000 psi for 15 min. 05:00 -06:30 1.50 RIH with completion assembly, down hole pumps & ScSSSV install Canon clamps every other joint from 8,794 to 9,517'. 06:30 -08:30 2.00 Make up hanger assembly, cut ESP cable, made splice to penetrator. Rig down ESP sheave & running equipment. 08:30 -10:30 2.00 Splice control lines, test ESP cable for 10 min. Set TWC & land tubing . Pick up wt 115 klbs, slack off wt 75 klbs. Test hanger to 5000 psi upper & lower for 10 min. 10:30 -12:00 1.50 Change upper & lower rams in BOP back to 4 ". Observed flow at inner annulus. Shut in & monitored ' pressures, built to 10 psi. 12:00 -13:00 1.00 Finish changing rams to 4 ". 13:00 -16:00 3.00 Nipple down BOP. 16:00 -18:00 2.00 Prepare cellar & well head, move valves, cap, ball & rod assembly to well bay. 18:00 -21:00 3.00 Nipple up tree, install valves, head & Ball -rod assembly. ' 21:00 -21:30 0.50 Test tree to 250/5000 psi for 5 min each & chart same. 21:30 -24:00 2.50 Rig up high pressure lines to bull head diesel down annulus & tubing. 04/28/2008 ' 00:00 -06:00 6.00 Bull head 20 bbls viscosified sea water, followed by 285 bbls diesel down inner annulus at 2.5 bbls /min, 550 psi start with final of 1100 psi. Bull head 20 bbls viscosified sea water down tubing, followed by 64 bbls diesel at 2.5 bbls /min. Start pressure 640 psi, final 1100 psi. Drop ball & ball rod assembly. Set packer with 1000 psi over initial of 1100 psi. Test packer to 3500 psi & chart same for 30 min. Test inner annulus to 3500 psi & chart same for 30 min. ' 06:00 -07:00 1.00 Rig up slick line lubricator & sheaves. Rig down circ hoses & manifold. 07:00 -15:00 8.00 Run #1 to 3,480', unable to pass gas lift mandrel. POOH with slick line, made second run & pulled rod & ball. Ran back in hole for X -RHCM plug & retrieve same. 15:00 -16:00 1.00 Rig down wire line & remove completion equipment from rig floor. Well released from ODSK -33 at 1 16:00 hrs. 1 1 1 18 / 7' /F, i // \ a z ' / \ \ \\ �� ��, \' �\ i tom! \ \� Customer: Pioneer Natural Res. Report #: 1 I ' HALLIBURTON Well: ODSK -33 Date: 02/18/2008 -5:00 . Area: Oooguruk 05:00 Depth 0 ;. Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Moving Rig I / Job No.: AK -AM- 0005556601 Report For: Jim/Jeff Daily Charges $3,500.00 Total Charges $3,500.00 \ %, ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: y' R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) - SPP (psi) Gas (units) 0 0 0 0 Flow Rate (spm) - Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids ° Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) %'. , �\ t \\ // y / / Wi n% % , 9 ' / / : ° /6 ,:: ��.� \D°\ \ \\ \ \ \ \ \ \K�\ :4 \ : ' - �� \/ .., /f �,��,� ,� $ Vi c. g ...« r, •� � � �. ��< , . -. �� ,a,,, ,,,,,, , � .,.... .�; . ::. �� o .. moo. a�\ \... .... � � -� \\� .:a..\ . „ „4� `�, �, y „ . .. .... - � ��. >�\ .. � �... : '. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition V 1 i : i •., r a� & _: ea. \ �l`Ft \ \ / / ,. , " , ,. � % �\ ,.. ����'i " .,.��s_�.\\ ,.��Y, ,..� //'/�� .�•� .,. ': / °a�...�"vt"'r�\\\\ \�� \ \�\ 1:: . \kit°:. \\ Yt%✓y %, Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Gvl Tuff - ig (current) I Gas Breakdown j Gas (units) Chromatograph (ppm) ' Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 1 to • t0 r 1 to V y' to to to to to . 1 to to ys Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas I , 24 hr Recap: Nippled up tree. Pumped 140 bbl diesel for freeze protection. Move rig. = 4 %\ 1� 1 \ '1 Logging Engineer: Coby Marks / Wayne Hermanson * 10000 units = 100% Gas In Air I s " Customer: Pioneer Natural Res. Report #: 2 ' Well: ODSK -33 Date: 02/19/2008-5:00 Al Area: Oooguruk 05:00 Depth 463' Location: North Slope Progress 24 hrs: 463' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling I $ ;" Job No.: AK -AM- 0005556601 Report For: Jim /Jeff Daily Charges $3,500.00 Total Charges $7,000.00 ,#4 iN. i% . ,. ...< k : via,.... .... •s 3: ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data:; R.O.P. (ft/hr) 0.0 200.0 336.0 210 Flow in (66m) 443 SPP (psi) 785 Gas (units) 2 5 30 330' Flow Rate (s•m) 104 Gallons /stroke 4.2 i Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % v I 200 8.9 8.9 120 20 50 32 0.1 2.2 l .. ,,. i, ,� \ \�. ....�'a . �. �� \�, � , .., ate., r /,. ;.,, „i<,�� _ :.�. � � . :�\ y;r,\ ;1 / /�........ , .,:, � .7 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 �i'� 12.25 .699 53 -- 25 -May 60 -85 'A-4 \ j Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff -tea I (current) 90 - -- 5 5 - - - - - I Gas (units) Gas Breakdown Chromatograph (ppm) ., Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type fl 57 to 463 30 5 3123 0 0 0 0 BG I \' to to - `' a to I ,y:::.5) to iz to to to / to F to to NI i • Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ` ; ' POG - pumps off gas; TG - Trip Gas '� \'�^ / / / /rr„ ` „ te... r ,, %% /, : C ,ax' r,....... ., / �.. _ . , ..... .fq.: - °.•Y\. ;� a�� s;�,.., i, r �/, I ' , 24 hr Recap: Moved rig. Mix spud mud on rig. Mixed additional spud mud in RSC. P/U drilling assembly and drill to 277' MD • POOH to P/U flex collar and the rest of the BHA. RIH with BHA. Drill to I Logging Engineer: Coby Marks / Wayne Hermanson * 10000 units = 100% Gas In Air I ''''' it ''''''' I'''4 Customer: Pioneer Natural Res. Report #: 3 1 K ALL1BURTON Well: ODSK-33 t e: 02/20/2008-5:00 In S' '-: Area: Oooguruk 05:00 Depth 2323' .'; .;,,,‘, ,.:.A., ,,,, Location: North Slope Progress 24 hrs: 1860' ,Y Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling ' I ,: Job No.: AK-AM-0005556601 Report For: 0.., Jim/Jeff Daily Charges $3,500.00 Total Charges $10,500.00 3, ..: %-:;" '2r .--- 4" ,-- - " , ;','".k4:''''SE'' tir Zirlie. ',;;:!:,;:tikl: 7 1.: 7 "..:4;''''',, 4 i77 , ,3 , .. , , , i4gg':',41 I ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 200.0 336.0 210' Flow in (gpm) 443 SPP (psi) 785 1 I ::,s Gas (units) 2 45 168 1130 Flow Rate (spm) 104 Gallons/stroke , 4.2 , 96) k 7 - ', \ 44' ,i' ,f ; .qN , , „,r. ,., , „ , ,,,,,;.ikdreAr" , ;,,,.,: -. WirT4i2IrrqZn;tX: - . ‘ ,. iiiik7, , '''n47:46?''''''RI:;! Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) °A k, 200 9.3 9.3 80 21 47 34000 0.1 5.2 i II '''4''' ' ' -'" ' ''' . ' Q,. ,,77*N'V;;iz:5%xr'i : z' - j BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition ',, -.: I 1 MEMEIBMI 12.25 .699 14.2 153 2170 5-20 60-85 , ';'; TV, F` .:',;";;% , ,,,?'': ' '24 ' '' ' 4% , , ?-4e77:VI;,;;,*;:,,,f;'''II r; 4r4_ , ,,,,, ,, , ,,,,,,, 2,:, ,,, ,, e A ,,, .'': Lithology (%): Sd ' Sst Silt Siltst Cht Clyst Sh Lst Coal Gyl Tuff I (current) 90 10 eg I ., ,..V ,,!' ,,,' Gas (units) Gas Breakdown Chromatograph (ppm) ,:. Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type I 463' to 1130' 168 46 16352 0 0 0 0 BG 1130 to 2267 ' ' r 75 33 7632 0 0 0 0 Bg '''S' to 3'L tO 1 I (<.• tO 1 to ,, to 2 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; NV, El POG - pumps off gas; TG - Trip Gas I 't 24 hr Recap: Service rig and service top drive, change out saver sub. Drilling and sliding to 2267'. Taking gyro surveys up to 1591'.Pumped high vis sweep at 1000'. Take on 200 bbls of mud from RSC ,.. , , ,,,, „. I i — Logging Engineer: Coby Marks/Wayne Hermanson * 10000 units = 100% Gas In Air t,::..)75..Nr.',LE.:,..$N4V II , I I 1 I Customer: Pioneer Natural Res. Report #: 4 I HALLIBURTON Well: ODSK-33 Date: 02/21/2008 !! •,' Area: Oooguruk 05:00 Depth 3183 Location: North Slope Progress 24 hrs: 860' • Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling 11 , .N: Job No.: AK-AM-0005556601 Report For: Op' Jim/Jeff Daily Charges $3,500.00 Total Charges $14,000.00 \, 0 ,,,,.• I ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 93.6 375.8 2340' Flow in (gpm) SPP (psi) IN Gas (units) 0 33 48 3125' Flow Rate (spm) Gallons/stroke 4.2 4 I '' iiiiiir:S% ''r '''' '' ,•- afigVi: In*X*,,M 1 - ' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids t. ••-:, Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) % I 3183 9.5 9.5 66 , !! 17 ..., . /. 37 34000 !! 0.1 6.2 e,..:.2', 7IREk'q:f7 ,11111: ,1 4 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 1 EMZEIMIII 12.25 .699 23.6 153 3183 3030 5-20 60-85 0 ;4. ' 111 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gyl Tuff 111 " (current) 90 10 _ ,,,, „ 'lit ''''''''%, WN. ..=1 :;;Mf",',. 'r . I Gas Breakdown Gas (units) Chromatograph (ppm) A Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 2267' to 3183' 48 33 4765 0 0 0 0 BG . . II z to . 011? to '''?; I to to rt ' fr ', t o ., , to I I . r, to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 1:1„ ji POG - pumps off gas; TG - Trip Gas '14 l iN:,- iki..1.120:4‘0 . ,:.:‘,.:&‘ :m. ,, e- -.f::: ' '%,'"""41":'''''''S., 7.mse z .:,. 111 I . X 24 hr Recap: Drilled ahead to TD of 3183'.Pumped weighted sweep followed by hi vis walnut sweep, circ. B/U twice. POOH , 0 1:„ for wiper trip. RIH " el' ' 4a,4 I s'o N: v 4- . g e Logging Engineer: Coby Marks / Wayne Hermanson * 10000 units = 100% Gas In Air '4 ,,,.. II I I -\\ ? \ t '. W t \' t o a, Customer: Pioneer Natural Res. Report #: 5 - HALLIBURTON Well: ODSK -33 Date: 02/22/2008 -5:00 i Area: Oooguruk 05:00 Depth 3183 //// Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Casing I Job No.: AK -AM- 0005556601 Report For: Jim /Gus Daily Charges $3,500.00 Total Charges $17,500.00 ', ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ! R.O.P. (ft/hr) 0.0 93.6 375.8 2340' Flow in (gpm) - SPP (psi) -: Gas (units) 0 33 48 3125' Flow Rate (spm) - Gallons /stroke 4..2_ �, : . .:. � te« z ! Mil D ata: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids p ( q) ) ( ( 9) ( ) ( \c De th in out sec / t (cc /30 min cP Ib /100ft m /I Ibs /bbl Pm ) I 3183 9 3 9 3 50 12 20 34000 0 1 5 2 f k • BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 IBEIM® 12.25 .699 23.6 153 3183 3030 5 - 60 y 4)N Yom % , , w y,.,. /r 7n/. \\ \tU/ ' , <J % ` M a\ / ..... 4 :, .,, ...... r . •�\.\c \ \� / a I r Litho ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) ----- - - - \ , � O\ \ - \�\ ' //, r'r G b �\ / . `� \ �' „a: �\ � , j ., �., -:::. �r ��,� . �,< �\.:, .�? \... yip �..l,,..�� � � -�. / ,,,,,, ✓, :..,.. w /a I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 3183' to 3183' 75 35 7643 0 0 0 0 TG l I e to to I to 0 to t0 % 1 t0 t0 - ir I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; di POG - pumps off gas; TG - Trip Gas 24 hr Recap: Circulate and condition mud for casing run. POOH and laydown BHA. Rig up to run casing. Start running '4 9 5/8" casing y di dv Logging Engineer: Coby Marks / Wayne Hermanson 10000 units = 100% Gas In Air ii ' s ��r \\\mot '� c..'r: / �\��' � \�... ........ o \� r \\fly e \ .d. sr.�;,.;,<.. ,,,alt i.,? \ \ \Y \ `ri, •�. % / ;,. .......��/, e //%n s,. \ \ \\:,.�. , ,, •. ,iii ,�� \�a_. �x a�\� ��,r :477".. 6 '. III I W \� D \\ j Customer: Pioneer Natural Res. Report #: 6 I HALLIBURTON Well: ODSK -33 Date: 02/23/2008 -5:00_ Area: Oooguruk 05:00 Depth 3183 / L ocation: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Nipple up I Job No.: AK -AM- 0005556601 Report For: Jim /Jeff Daily Charges $3,500.00 Total Charges $21,000.00 I ? IN,. ' . / /, \ \�\ ... ....;,:, :HAS' \.. :10 ,.... , ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) - - -- Flow in (gpm) SPP (.si) (units) - , , (P )- :; Gas units Flow Rate s m Gallons /stroke 4 2 Pt Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids p De th in out (sec /qt) (cc /30 min) cP (lb /100ft 2 (mg /I) (lbs /bbl) (Pm) % 3183 9.7 9.7 46 13 23 34000 0.7 5.2 ' �� :._.. ..._ .. of ,. / ` BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 1 1 12.25 .699 23.6 153 3183 3030 5 -20 60 85 3 2 BT A E 1 WT TD : i �\\\ :.. /'',,, �\ ;.::. //6r,. � �„ .� \ \s <.. gin, `..n•�% „ f ,.,.�� \ \�`�`. s,c'... •• � • : ,O/ ...... .. ,� „:: ,.. = Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff v 6f current I Gas Breakdown ill Gas (units) Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type Iiir 3138 to 3138 48 5634 40 3 0 0 BG I 5 'f p to , .- to 4 to i to to F A to I to to % . to Elk Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; t l POG pumps off gas; TG Trip Gas ,;` I 24 hr Recap: Finished running casing, pumped cement. Set casing at 3172'. Built 700bbls mud in the RSC ready to drill out 4 J 11 the next interval. Finishing nippling up, preparing to test BOP. 1 / I \ r , Logging Engineer: Coby Marks /Wayne Hermanson 10000 units = 100% Gas In Air illr ii .:VN; I i Customer: Pioneer Natural Res. Report #: 7 I Well: ODSK-33 Date: 02/24/2008-5 Area: Oooguruk 05:00 Depth 3183 Location: North Slope Progress 24 hrs: 0 `\ Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH ke, I : Job No.: AK -AM- 0005556601 Report For: Jim /Jeff Daily Charges $3,500.00 Total Charges $24,500.00 • r ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: dir R.O.P. (ft/hr) - - -- low in (gpm) - SPP (psi) (units) - - -- F ▪ Gas units Flow Rate (spm) - Gallons /stroke 4 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 3183 9.7 9.7 46 13 23 34000 0.7 5.2 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition '' 2 SecFSF2463Z 8.75 0.863 - 3183 - - -- 4 1 Hughes MXL 1 12.25 0.699 23.6 153 3183 3030 5-20 60-85 3 2 BT -A E 1 -WT TD te \ \\ \ \fie - 4 . O. \ a \ i \\ \...:d \ ..... r a;r , /,�.. « a \ ii, �,, ,. *�� , «.. „ Lithology ( %): Sd Sst Silt Siltst Cht \ Clyst Sh Lst Coal Gvl Tuff _ I (current) ----- _-- - - - -� 1 ms s ... ,�'2,V , ,.:4Z2, . : ✓,rlig, ;;,, :: o31 . ,W „„ r,.....r 4...,..., 7: ,.Kat I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type to to 1. to \ ' to t0 0 % ' t0 i to to X.• 1 \ to al to I r Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG pumps off gas TG Trip Gas / e ''` '` �„ - N-tea? % \\\�\\\_ �` r>f o � � r \i „ cif, 4 ▪ 24 hr Recap: Finished nippling up. Tested BOPs. Picked up BHA, loaded MWD tools, and did shallow pulse test. ‘I H RIH with ghost reamer and single joints of drill pipe to build up drillstring. y Logging Engineer: Coby Marks /Wayne Hermanson 10000 units = 100% Gas In Air ' \, �q�a j -� Z �/„p er ,, j� Or r � �\\\\� '� \\\�� `• 5� „ Z \ II iii .�. �:. ����. �. ://,��,�. � ..w\ iii,,.. _ _._ „.�, �.., i< ,3? I I I l! //� \\ / i n ry'. / y a ii %/ j: Customer: Pioneer Natural Res. Report #: 8 ' Well: ODSK-33 Date: 02/25/2008 -5:00 A rea: O ooguruk 0 5:00 Depth 3 183 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH ' \ Job No.: AK -AM- 0005556601 Report For: Jim /Jeff A\ Daily Charges $3,500.00 Total Charges $28,000.00 \ I ' '✓ a \ \� 4,.1.1 , AdBENizAA /'., ,isf AL,���. ,Z�A.A - . .. , i,r; .a ivy ,:1.%/`� ,r , ,, ' ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) - - -- Flow in (gpm) - SPP (psi) - Il 111 Gas (units) - - -- Rate (spm) - Gallons/stroke 4.2 Flow ons s ro e Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Ai , - Depth in out (sec /qt) (cc /30 min) cP (Ib/100ft (mg /I) (Ibs /bbl) (Pm) % ; 3183 8.9 8.9 45 10 14 34000 0.8 2.1 / ::I /, M\a \ \`' \, . 1: ii,.,,; W\ \\ , , ."!( libA ;z,..._ , '. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 SecFSF2463Z 8.75 0.863 3183 3183 0 1 Hughes MXL 1 12.25 0.699 23.6 153 3183 3030 5-20 60 3 2 BT A E 1 WT - TD / / Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ai (current) ------- - - - - -' I Gas Breakdown � Gas (units) Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type to I f to - ;111:i: ri to 1 to j I to to to to to to to a Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG pumps off gas; TG Trip Gas ...... TV, 1 %,. , . .1�/�:.,, r /iii.... ,. <.7� �. x l tga .. I ' "; 24 hr Recap: Displaced with new mud. Drilled plug to 3154'. Casing test failed. POOH. RIH with packer to isolate casing problem. v I I Logg Eng Coby Marks /Wayne Hermanson * 10000 units = 100% Gas In Air IV II I AY 'i,I,P ,,OV.;t4,,,PAIII.Vlir , ,,,my 1! Customer: Pioneer Natural Res. Report 9 I 4 HALLIBURTON Well: ODSK-33 02/26/2008-5:00 :,! \'..; Area: Oooguruk 05:00 Depth 3392' ztk ',1 Location: North Slope Progress 24 hrs: 209 Sperry Drilling Services ' • 0 , 1 Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0005556601 Report For: Jim/Jeff 111111P II ,, Daily Charges $3,500.00 Total Charges $31,500.00 , ... ,t I ;A , ,, i i ; .;'7141„,,;v:,:: ; t;''''',A:e; ; -, ;, - ?;:7 'Y'''',i'llM,W:lilW Mi.lr,CEiliirfaillillilliiii;?:MVIL, ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 63.0 108.4 263.0 3389' Flow in (gpm) 513 SPP (psi) 1600 ,4 I Gas (units) 26 15 30 3340' Flow Rate (spm) 121 Gallons/stroke 4.2 ;4*;„C.:, ;,K„:T • Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I :4 Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % 8.9 8.9 44 8 16 34000 0.8 2.1 3195 ,., ::i 10 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition IL_ I lit 2rr1 SecFSF2463Z 8.75 0.863 3183 209' 7-10 80 2 SecFSF2463Z 8.75 0.863 3183 3183 0 ‘ , Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 90 10 ;:<'''''''''1;41**';"4.11'544111kz' ;:-- :4;;MIERMEIDAL:77V<OVO Q Gas Breakdown I ii Gas (units) Chromatograph (ppm) Max 3 C4 Tot C5 Tot Type Depth Average C1 C2 ill ..., 3183' to 3389' 30 15 3123 44.7 15.3 BG I A ' to A A S tO It MI tO tO to tb .e 4 I .4 'iA to to to ,'.,,,„•;,.... Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; '1 A POG - pumps off gas; TG - Trip Gas ii I '':' 24 hr Recap: RIH and test casing above shoe.Pumped pill and POOH for BHA. RIH and drilled out float. Drill 10' of rat hole for PO FIT test. FIT test to 15.92 ppg eq. MW. Drilling ahead at AVG ROP of 108 fph I r K, I iiO 10 / ." Logging Engineer: Coby Marks/Wayne Hermanson 4, * 10000 units = 100% Gas In Air :':' `;:t%.1 :ticA.11111111111INFAIMIOTIeimpumplisAirel , I I .moo rap ....,, .. �� //' , Customer: Pioneer Natural Res. Report #: 10 Well: ODSK -33 Date: 02/27/2008 -5:00 I Area: Oooguruk 05:00 Depth 5031' AL Location: North Slope Progress 24 hrs: 1639' I ':;<, Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0005556601 Report For: Jim /Jeff `' Daily Charges $3,500.00 Total Charges $35,000.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 171.9 102.4 253.0 4841' Flow in (gpm) 600 SPP 2920 Gas (units) 3 55 585 4805 s Flow Rate (spm) ,i 140 Gallons /stroke 4.2 1 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 4 I f- Depth in out (sec /qt) (cc/30 min) cP (Ib/100ft (mg /I) (lbs/bbl) (Pm) % a; � 4800 9.2 9.2 50 16 24 34000 0.3 2.1 ,': .yi, \ - z . k :. mac.. .., z : 4 m,.,: *,, , u,aP.a:. m ti ;,,,,, 75 ,.., 4 __. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 2rr1 SecFSF2463Z 8.75 0.863 - 3183 1 848 7-10 80 It �, 2 SecFSF2463Z 8.75 0.863 - 3183 3183 0 -- fg r ,t /Iii , al I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ ip (current) - -- 70 25 - - -� i \ Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type o 3300 to 4000' 94 48 9365 145 33 20 0 BG ' 4000' to 4500' 153 64 15369 473 199 84 0 BG 4500' to 5000' 585 130 23307 1380 658 258 78 BG to Ito , to gh to to to h , to •� to �• Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; j�z 4 POG pumps off gas; TG Trip Gas I 24 hr Recap: Drilled from ahead to 5031'.ECD 9.9. Drilled through fracture zone at 4809', had a spike in ECD, an increase in ``/ flow out, and a spike in background gas of 585 units. Got large pieces of shale over shakers, some 4" in diameter. Circ. 4 j until hole cleaned up. Currently drilling ahead. ,\ f' i Logging Engineer: Coby Marks / Wayne Hermanson * 10000 units = 100% Gas In Air ' • I II 'N-r. r - / \ x t r/ , , Customer: Pioneer Natural Res. Report #: 11 Well: ODSK -33 Date: 02/28/2008 -5:00 Area: Oooguruk 05:00 Depth 6860' Location: North Slope Progress 24 hrs: 1829' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling A r A Job No.: AK -AM- 0005556601 Report For: Jim /Jeff Daily Charges $3,500.00 Total Charges $35,000.00 ' 4 ..x..•.. \ \\ ::„i%::,::,;741811,,,,.. . s..: ,.Z - __. om\ 0 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 97.0 113.0 145.0 6769' Flow in (gpm) 602 SPP (.si) 4200 I Ai Gas (units) 385 80 6481 3340 Flow Rate (spm) 140 Gallons /stroke 4 2 . * Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % 3195 9.6 9.6 55 19 23 0 3 7 2 34000 / BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 I 2rrl SecFSF2463Z 8.75 0.863 30.6 3183 3677 12 80 j- 2 SecFSF2463Z 8.75 0.863 - 3183 3183 0 -- ' iiiip L ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ' '' (current) 30 30 -- 10 - -- ->, Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type '°11: 5000 to 6478 150 95 11569 520 199 84 38 BG I / 6478 to 6482 746 285 25803 1048 321 106 36 GP 6482 to 6650 108 88 10263 477 198 90 33 BG 6650 to 6720 593 372 76734 4256 1568 646 251 GP I i 6720 to 6840 779 360 89224 5091 1881 761 298 GP to ' t0 is t0 r e to to t Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG pumps off gas; TG Trip Gas r Recap: Directional !O \O 24 hr R Di drill 8.75" hole from 5074' to 6860. A ,:1 Gas peak at 6478 -6482' possible fracture gas. 111 I Last 2 gas peaks from Torok sands ' I x Logging Engineer: Eugene Payne/Wayne Hermanson * 10000 units = 100% Gas In Air r I I I li'VA , N,aslt'''',72 40"111:;. MINIIIIIRWM:'''.76111111611111111illiallittit."74111VVINIL'4W; Customer: Pioneer Natural Res. Report #: 12 I HALLIBURTON Well: ODSK-33 Date: 02/29/2008-5:00 i Area: Oooguruk 05:00 Depth 8275 ,4s, Location: North Slope Progress 24 hrs: 1415 Sperry Drilling Services I Rig: Nabors 19AC Rig Activity: Job No.: AK-AM-0005556601 Report For: Drilling Jim/Jeff 1 Daily Charges $3,500.00 Total Charges $38,500.00 S' iliZ, 4 I :;4s4iirAr'''ZiklilliN.r4fk:Stift:5;.044-1,1 11 11,111111MYSIMIP,7412111/1121iiiiilliallaillialtsElliM/ A ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: " - ; R.O.P. (ft/hr) 101.0 86.3 301.0 7167 Flow in (gpm 500 SPP (psi) 4000 Gas (units) 222 143 1198 6923 Flow Rate (spm) 120 Gallons/stroke 4.2 I :?;. , , mik - -,:,,,,,,,; , z ; : , -e ,,- 0: , , ../,4,.::'; - -)Nsoksmx* ,t4mliesk 'm.:')':\' III' 'II ,7,7glisg::-y Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids :II Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % I 7984 9.8 9.8 50 13 21 34000 8.8 „Oissii4:7ilibe1,44,44444,4].::,17Z444tU2INr7,4,6741',SpiplillinillikilifilistinlestAlta.„,4s,;*m. s1ItN,,,,v,,,,.j5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2rr1 SecFSF2463Z 8.75 0.863 47 3183 5092 15-18 140 k: I 2 SecFSF2463Z 8.75 0.863 3183 3183 0 ilirs41111111Vi'siA-;44M I pi Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 10 20 70 : •4'1111s,: - ';'Icss:044114si ii I !,:. Gas Breakdown 1.0 ' 4 nd Gas (units) Chromatograph (ppm) .,: Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type I 9! 6840 to 6910 400 310 40176 2444 947 409 205 BG ,..' 6910 to 6940 ' 1190 535 142726 8912 3832 1623 626 GP 6940 to 7255 480 is 335 86110 5049 2183 1145 578 BG � 7255 to 7660 320 235 18090 1890 852 473 260 BG 1 II 7660 to 8224 157 113 17972 1448 635 290 162 BG 1 , to il to to 'ilf F tr,•, to ''':$ 4' I k Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ""i' POG - pumps off gas; TG - Trip Gas PW' I 24 hr Recap: Directional drill 8.75" hole from 6840' to 8275'. / sms kilis Gas peak at 6910-6940' from Torok sands IF' 1 ,, :.0 ' II Logging Engineer: Eugene Payne / Wayne Hermanson * 10000 units = 100% Gas In Air !Z ;4 le ' TY.14:rla::7 9 t . ' ' '' ' llii0 1 11Kit , ;MIT17 1 MOSIL,ON I METRIPP ER F :57:01e rrZINISSIN 11 . "16 M 1777 n I Cri;i I I t' '"l',.2i".Aigl:;,M5illjkAlIllMF:7;Zil,g11EgglEB,r:tgtrn::QA;yvTiru:,,,,mliKvi Customer: Pioneer Natural Res. Report #: 13 r _ HALLIBURTON Well: ODSK-33 Date: 03/01/2008-5:00 0 Area: Oooguruk 05:00 Depth 8491' Location: North Slope Progress 24 hrs: 216' 7 For: 4 Rig Activity: Resume Drilling Report Job No.: AK-AM-0005556601 eport or: • Sperry Drilling Services Rig: Nabors 19AC Rod/Jeff Daily Charges $3,500.00 Total Charges $42,000.00 111 021040003i 1111 ROP&Gas: Current Avg 24 hr Max Max @ft Pump & Flow Data: N 5: . , R.O.P. (ft/hr) 48.0 245.0 8150 Flow in (gpm) SPP (psi) I • Gas (units) 103 953 8491 Flow Rate (spm) Gallons/stroke 4.2 0: p '110 ;:0 ‘40t011ikZ Alik.".,0' 40:' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids If Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % I 8491 10.6 10.6 50 17 26 34000 1.5 10.3 ' '',4 ''' ,,,, '''"''' '',, --'' mmo -,,,S.Alib 'wiskv 7.8.11tivemeNc>N4411k ,''i' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I A 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 5308 15-18 2 SecFSF2463Z 8.75 0.863 3183 3183 0 !'41 201117 in Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 4 I (current) 10 20 70 4.. -,,,-:,:(1:::togiliN,:,:t*,11:Alif. - a",2N2..instatuit.---zzz,,Nzynigralliffecip :i w „ . „1".„: I I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type I '.$ 8270 to 8352 255 215 19801 1906 811 339 140 BG k4 8353 to 190 16791 1492 688 309 140 CG ip 10, 8357 to 8441 483 245 20591 2095 956 426 188 BG 0): 8451 to 329 23810 2463 1089 482 211 CG 4 8474 to 8490 471 329 27501 2479 1081 443 156 BG 10 !!!! 8491 to 953 38105 4995 2097 782 278 TG 0' to A ',..A g / N% 0 tO - Alk It' !IF I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas ' 1 a g 4' 4 4'44:4; 4 :,4':401104 ''4.4Aii::rf I 24 hr Recap: Directional drill 8.75" hole from 8275' to 8491'. Packed off @ 8491 used jars to free pipe, pull out to 6700' 04 RIH to 8491, circulate bottoms up and pump sweep 0 A I , r I N . :! Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air 111 : I <i•ii,"°.;-"";,i'Z';7411ii66:0:0Z75111ii‘..44kliiig:=77)Wjl '116(C;10.,.1011;;;71191611.1r.011231finglitr*Wr):5000,w0.70,4iiiii,,:z::":, I I 1 Customer: Pioneer Natural Res. Report #: 14 Well: ODSK-33 Dat 03/02/2008 -5:00 Area: Oooguruk 05:00 Dep 8491' Location: North Slope Progress 24 hrs: 0 • Sperry Drilling Services Rig: Na bors 19AC Rig Activity: RIH � � g 9� 9 Y� Job No.: AK -AM- 0005556601 Report For: Rod /Jeff y Daily Charges $3,500.00 Total Charges $45,500.00 El ` ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: 4,.- R.O.P. (ft/hr) - - -- Flow in (gpm) - SPP (psi) a Gas (units) 46 785 8411 Flow Rate (spm) - Gallons /stroke 3 6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids r Depth in out (sec /qt) (cc /30 min) cP (lb /100ft (mg /I) (Ibs /bbl) (Pm) % I 8491 10.7 - 50 15 25 34000 - 0.5 11.4 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition SecFSF2463Z 8.75 0.863 - 8491 I 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 NI Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _•' Ill ( current) - -- 10 20 70 - - - -- W p // \, % \ . I Gas Breakdown y ' Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8402 to 692 183 17221 1579 787 376 149 TG I 8411 to 785 399 14381 1338 746 378 151 TG 6388 to 721 190 21903 1885 944 456 177 TG to to ti to to :; to I to to to 4 . I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas l \\ a -' N d r y \ ;:% 24 hr Recap: MWD tool failure. POOH. Lay down BHA, Test BOP, Make up new BHA, Prepare to RIH 1 a N r N Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air II I Customer: Pioneer Natural Res. Report #: 15 Well: ODSK -33 Date: 03/03/2008-5:00 Area: Oooguruk 05:00 Depth 8491' Location: North Slope Progress 24 hrs: 0 7 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH qvg Job No.: AK -AM- 0005556601 Report For: Rod /Jeff no Daily Charges $3,500.00 Total Charges $49,000.00 , I ' i,..j 4��� �..... ,. : . ..iii 2 1 R ' �• �, . � \ .., \ \ :NEB N ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 49.4 59.6 8492 Flow in (gpm 483 SPP (psi) 3773 ' Gas (units) 884 716 1440 8491 Flow Rate (spm) 133 Gallons /stroke 3.6 I \ ,/ 5%' COs ! %i �� " \ 9i ' �\ ;' � \\\ `.'.._ 5 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 8491 10.6 10.6 55 17 27 34000 2.5 10.8 r ;, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition SecFSF2463Z 8.75 0.863 - 8491 - - -- I 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15 -18 80 \��� \ \, r ' r �� �. sl 1 ;fi 0: .. r %r q r <r e '" tr \ > y ,c ! Lithology ( %): / Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ I % (current) - -- 10 - 20 70 - - - -- ...._ ?vas -^ ,y Gas Breakdown I y Gas (units) Chromatograph (ppm) ille Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type / gill 8491 to 1440 378 45828 3735 1383 492 158 TG I 8491 to 8500 871 716 40402 3732 1359 487 134 BG to to I to 7 to e to to I p t i. t0 N Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 24 hr Recap: Slip and cut, make up new BHA, RIH, Commence drilling r i t 4. 1440 units of gas on bottoms up 1 go PIF 1 Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air II til • I I 1 ,,z \¢ Customer: Pioneer Natural Res. Report #: 16 f U HALLIBURTON Well: ODSK -33 Date: 03/04/2008 -5:00 '\ Area: Oooguruk 05:00 Depth 9406 ow Location: North Slope Progress 24 hrs: 601? Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling U � Job No.: AK -AM- 0005556601 Report For: Rod /Jeff Daily Charges $3,500.00 Total Charges $52,500.00 j I / n ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: \ \ R.O.P. (ft/hr) 24.5 30.5 176.9 8796 Flow in (gpm) 537 SPP (psi) 4376 Gas (units) 131 448 1693 8618 Flow Rate (spm) 5 0 Gallons /stroke 3.6 ivi ;/ \\ y . ! \ mow I,. / �� Flow , \.,,� 1 e \ � , • i/ , ` ° Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % \ 9029 10.7 10.7 55 14 30 34000 -- _11.4 ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition SecFSF2463Z 8 75 0.863 - 8491 613 15-20 150 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - r (current) - -- 20 -- 80 - - - -- ilr Gas Breakdown Gas (units) Chromatograph (ppm) 1 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type i 8505 to 8570 1523 905 27420 2513 1232 535 191 BG I 11 8575 to 8608 1108 393 27034 2528 1100 453 156 BG 8610 to 8789 766 1693 35109 3994 1837 907 327 BG 8795 to 9098 375 159 11568 1122 587 248 89 BG I j 9085 to 340 220 11383 1066 589 318 110 CG to to A to l I to to iiit to U Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; % POG - pumps off gas; TG Trip Gas y / / \� j t' \\ 4 l . , . ...., 6„ .. �° / / / /// r , r. - %,�,. - J, � , „ � //// /.,.. ate✓ \,,, , ,, � � .. I 24 hr Recap: Control Drilling, Coninue drilling ahead. III I I : 0 l ; I Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air gig I j W .,rii Customer: Pioneer Natural Res. Report #: 17 I HALLIBURTON Well: ODSK -33 Date: 03/05/2008 -5:00 Area: Oooguruk 05:00 Depth 9570 r Location: North Slope Progress 24 hrs: 463 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0005556601 Report For: Rod /Jeff N Daily Charges $3,500.00 Total Charges $56,000.00 , ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ` ' R.O.P. (ft/hr) 53.0 35.4 176.9 9270 Flow in (gem) 520 SPP (psi) 4376 W I Gas (units) 338 329 1269 9537 Flow Rate (spm) 144 Gallons /stroke 3.6 Chlorides I Md C I M ud Data: D ensity (ppg) Viscosity HTHP PV YP hlorides Lime Alkal or Solids 0 Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 9471 11.0 11.0 55 18 30 32000 -2.0 11.4 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition °1; 2 rr1 d SecFSF2463Z 8.75 0.863 _ 8491 1079 15 -20 150 I SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 r Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _\` (current) - - - - - - -- � it I j Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9107 to 9180 267 161 6263 530 307 170 85 BG /• I 9180 to 9185 873 366 16852 1628 838 450 199 CG \ • 9200 to 9205 1055 241 16682 1804 854 407 181 STG 9210 to 9270 345 220 14549 1533 806 411 181 BG'.' I , 9270 to 9280 508 339 23334 2770 1410 673 277 CG \' 9280 to 9324 475 384 24491 2690 1378 663 271 BG 9324 to 9331 831 336 30736 3682 1868 848 327 PG y/ 9358 to 9370 811 475 38003 4780 2505 1153 425 CG I 9380 to 9415 9470 to 9475 395 339 26751 2899 1678 881 343 BG 929 324 29872 2810 1663 929 377 CG 9580 to 9595 1278 270 38197 4859 2681 1339 520 STG A I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas I 24 hr Recap: Coninue drilling ahead.' y:� Logging Engineer: Boyd C Pi / Eugene Payne 10000 units = 100% Gas In Air iy I Customer: Pioneer Natural Res. Report #: 18 lo Well: ODSK -33 Date: 03/06/2008 -5:00 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 160 ' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH dir J No.: A K -AM- 0005556601 R eport For: R od /Jeff v Daily Charges $3,500.00 Total Charges $59,500.00 5 r I *Ce rrA...ir1 �iY`a. .ate ,,i.S:Z.: ,,,,.. ,. Z 0-f'M:15iiiiqt%, ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 43.4 121.6 9712 Flow in (gpm) 300 SPP (psi) 1750 Gas (units) 338 345 2488 9501/TG Flow Rate (spm) 83 Gallons /stroke 36 \ \\ �r� ; ri ��� •\ ', ,,w 1 , ` r r ( ir y >: r \` r� r w - ^� \ l .. \ � ` \. \ Sri /r�,, jililli Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 4 1 Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % 9730 11.0 11.0 48 11 35 32000 1.3 12.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I r SecFSF2463Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 N 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 e; I \ Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 10 20 -- 70 - - - -- I 'I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type k / 9602 to 926 411 44156 5100 2643 1312 486 PK I 9605 to 9705 803 278 27381 2629 1456 766 295 BG f' !' 9710 to 9730 908 220 19704 2078 1257 676 275 BG 9730 to 9542 2488 910 62297 7586 3787 1777 652 TG I 9730 to 9143 851 306 39098 3565 1500 609 217 TG N " to to to ' to i . to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG pumps off gas; TG Trip Gas d I � % 24 hr Recap: Coninue drilling ahead. : ;'': I iii Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air tl I .;::iiimit iniw :',JilLit linilltvfit411411111111111111:11M111111 ' i:iiiireAllinrVWX1111111111111..? ...;,,, s-, Customer: Pioneer Natural Res. Report #: 19 I r6 HALLIBURTON Well: ODSK-33 Date: 03/07/2008-5:00 A4 Area: Oooguruk 05:00 Depth 9730 !IlliP Location: North Slope Progress 24 hrs: 0 ikA I 1 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Job No.: AK-AM-0005556601 Report For: POOH 011 Rod/Jeff .-- Daily Charges $3,500.00 Total Charges $63,000.00 IV v; 4 -9:11k Sillsi , '.. ito , :,l,'.il.K'-;;' - '774T""' , ;k1::.Mok) ;',.'4,Y;i4,%eTfi- Tnalt , &),Vilki: . :aii.,31S;l1, , aA ,, ,,N*4)..c7."?0 , 4 I ' ' ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: .,. R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 314 SPP (psi) 1503 . 0: I . Gas (units) 74 ,.., 270 1463 9145/TG Flow Rate (spm) ,,, 86 Gallons/stroke 3.6 .,.;, - -viiiiir.vvv,,,,K,,ov-Vviv, ,, ',• - Vv.. , ,r, ;' Nilliff,,Lv..:VVVV:::•h?"' ' 4i 1;007) vtg,000,02101W Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids ,V in • 14 I 0 Depth in out (sec/qt) (cc/30 min) cP (lb/100ft 2 (mg/I) (lbs/bbl) (Pm) % 9730 11.0 11.0 55 13 22 32000 1.4 12.5 % a;, Z- \faf illiiy,:,Wftci: r ' '' ', ' Fi.':ittleZ7777 111 0i '' :-: BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I lik SecFSF2463Z 8.75 0.863 42.5 8491 9730 1239 15-20 150 ig 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 i,,,i; VSNICV-NCZVV 1111 '''.' 77 ViCA ' 4)I71441111 " \ ' : • :214 V1111 I l ip Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 4 ec r. (current) 2 ' vVVV4',6:'"VVVir,V1!Y.'"?r'''''''''Aii"-olop,:-410y-3,.:,:;774.Atesit,14,,ziref,<.0. ,,;,1 I Gas Breakdown Gas (units) Chromatograph (ppm) gft:' Depth Max Average Cl 02 C3 C4 Tot C5 Tot Type 9146 to 9149 1463 1095 89986 9601 4018 1274 377 TG 9149 to 8947 1076 443 51993 5243 2016 717 230 TG IF I .% 8938 to 8908 1370 956 69464 7817 3724 1330 403 TG 4i jj 8908 to 7900 1161 348 45533 4961 2420 1160 381 TG ;:4= _ A I 11 4 7187 to 6439 to 113 47 9030 720 494 295 121 TG fill k...... -,.. to ,,,...„ ie to - A I to * to v ',..v I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas V. , OL7Trilliit2 ;'''''' ': 1 , tight sections. POOH to 6430 ., 1 I 24 hr Recap: Backream through tig --, 4, ii ip • '' 0 01 '04 ki •P, I Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air VS . SAi„ija.'rrqifb,„,,iapc,Vrabg'AMMIIDW:;Wjalrtirr,gOqllNrMllagtr I I ;l/ Customer: Pioneer Natural Res. Report #: 20 ' f) HALLIBURTON Well: ODSK-33 D ate: 0 3/08/2008 -5:00 yk Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK -AM- 0005556601 Report For: ;:. \ Daily Charges $3,500.00 Total Charges $66,500.00 r \ ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ' " r R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 278 SPP (psi) 1123 Gas (units) 270 89 452 4058 Flow Rate (spm) 76 Gallons /stroke .,,,, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 9730 11.0 11.0 55 13 25 32000 1.4 12 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition fk7 ' , SecFSF2463Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 `; 2rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15 -18 80 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - . (current) ------ - - - - -- Gas Breakdown I Gas (units) Chromatograph (ppm Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 6420 to 4213 235 46 10590 764 503 377 182 TG I :! 4214 to 3878 452 127 46254 2584 1242 647 241 TG to to F to to to to t0 I i t0 t0 \ ' \? Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas I 2 4 hr Recap: Backream and Jar through tight sections. POOH to 3878 A I V Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air III / , ^4 / K //k / pFt` • \ Customer: Pioneer Natural Res. Report #: 21 Well: ODSK -33 Date: 03/09/2008 -5:00 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH ' Job No.: AK -AM- 0005556601 Report For: Herb /Rod Daily Charges $3,500.00 Total Charges $70,000.00 gi ,ce rho ,, 4* `k. ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (.pm) 0 SPP (psi) 0 I Gas (units) : v,,,,,..,,,,,,,,: 1 ,0,, 401 3761 Flow Rate (s pm) 0 Gallons /stroke 3 6 4 ; 1 1 � ,nip +; � �,, ' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % ), : 4 9730 11.0 11.0 46 15 21 32000 - 1 4 12.5 r w BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I SecFSF2463Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 ia 2 rr1 SecFSF2463Z 8.75 0.863 51.5 3183 8491 5308 15-18 80 ' %i �� i;.... r /,,; .,, •tea Z � i .,: _. �i /u .,, i \ ' Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - 4 (current) ------ - - - - - / Gas Breakdown Gas (units) Chromatograph (ppm) e Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 3823 to 2951 401 95 40552 1441 731 542 240 TG j ' to to to !/ to to 0 to to em to i to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas 1 ^ 24 hr Recap: POOH, lay down BHA, rig maintenance, pick up clean out BHA, RIH 1 I • Logging Engineer: Boyd C Piercey / Eugene Payne " 10000 units = 100% Gas In Air j /f Sri : / ✓ / /r 3; \ U ?: I I II' ,,,,,,,,,\ r 7.77 ' T''' ;P 7f 1 „.., I Fr, \.:(./i.i.‘)1 '.;7•/,:xl.',..‘ )\'''e ' ' ''':stOr‘ri ' er : : *7‘ 'F'IOneer N;tural Res. ' ' ' - Report #: 22 ,:,' I HALLIBURTON Well: ODSK-33 e: 03/10/2008-5:00 Area: Oooguruk Location: North Slope 05:00 D I at Progress 24 hrs: 9730 • Prog 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH • Job No.: AK-AM-0005556601 Report For: Herb/Rod - ;--, Daily Charges $3,500.00 Total Charges $73,500.00 I -. ,, , ,,,,,, ,,,, 1 , -..‘, , g, // \ • air Z' \f' -11'71' W , `'." ,„,,,,- ,..L V •,..•• ."` q '$ , s .,. ',/ , -,,,, • , t/ \.\. ,-, -,,,..„ ,, ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data : ,„..., I ':,,' R . 0 . p . Gas (units) 6 17 69 (ft/hr) 0.0 0.0 0.0 0 Flow in (glim) 0 SPP (psi) 0 4305 8700 Flow Rate (spm) 0 Gallons/stroke 3.6 .., ',••., ;,, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids ,;; Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/1) (lbs/bbl) (Pm) 0 / 0 I 1. 9730 11.0 11.0 45 \ 10 20 32 0 0 0 1.4 12.5 , . ,1:, ,,$;,,, „;',= , ••: 61,A-:- _ :‘, N,h, , ,,, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I SecFM3655Z 8.75 1.116 0 ,4 % 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 150 5-7-7 ':,'''''' I L' I tholo ( ): Sd •. gY ° Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _ ,.. ,....„ „ ., „ ,,,....„.;,;;, \ ,, ,,,,,, ,,....,, , v - 2446451747 ry: '1g4:4 ......, '1....,,il , , \ , v '4g,h■ , ';, "1V : .:N i ',1„, , O; 1Ni.___,',.',.:""fPaz - , t.ww ,,,,, td 46, ------ • -'''' '''"-- , IN .. ...—_ I Gas Breakdown - ' Gas (units) Chromatograph (ppm) et 0 \ Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8420 to 8700 1898 653 22823 8547 7856 3324 259 TG I 8644 to 8696 4305 1737 15278 5109 4263 2284 172 TG ..: to to I to to to to to /4 e _ I to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas ', 1 z e - 24 hr Recap: RIH Work tight sections, swap mud and weight up, continue to RIH to 86 9 I ''''C 0Z , 'it .., 1 z, 1 g , .... :.--, 1 ‘: Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air :4! ,O 4444< , - •1:.. , z3., ,) 'Tqw7.7" . ,,,, ` . ' \:>AZ.:::,..2 0; : ' ., ,?,,\< '''' '7.g.-t 4.,&::„,a....— - ' ..—„,., , , / ..._„ „,„, . II I I Customer: Pioneer Natural Res. Report #: 23 IHALUBURTON Well: ODSK 33 Date: 03/11/2008-5:00 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 S err Drilling Services Rig: Nabors 19AC Rig Activity: RIH . 111 te Job No.: AK -AM- 0005556601 Report For: Herb /Rod : Daily Charges $3,500.00 Total Charges $77,000.00 I ' ,:i'.\ ,,Z: ;:' rZ irlr$733Ar ' .: '"?' L.411f7 ..241:5;;3777'::: "7:M7''''km:!:',: ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: " R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 Gas (units) 480 487 8060 8810 Flow Rate (spm) 0 Gallons /stroke 3.6 k Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % 9730 11.5 11.5 55 23 24 A 32000 0.1 12.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition %' I j 4 SecFM3655Z 8.75 1.116 - 0 - - -- 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 5- 7- BT- A- X- 1 -JD -TD k Il l I " Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ------ - - - - -- a.. I Gas Breakdown Gas (units) Chromatograph (ppm) '' Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8680 to 8945 513 256 15020 4651 2487 832 46 TG e 8902 to 8941 360 186 16731 4916 1704 406 41 TG ;• 8961 to 8975 2818 677 13627 3859 3154 1158 80 TG j 8809 to 8815 8060 3060 15577 3775 2812 1052 234 TG ,i 0,0, i , A : ft 8815 to 8632 1151 256 18747 7522 3704 1804 87 TG 1 to ' to to , , 1 i 4 to t0 i iaa to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas %ice /? / E \ A/ ,r %+'fie I s ; 24 hr Recap: RIH Work tight sections, weight up mud, continue to RIH to 8862, work tight spots back to 8620, weight up to 12ppg and RIH. ili M iii Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air < I Customer: Pioneer Natural Res. Report #: 24 ii N Well: ODSK -33 Date: 03/12/2008 -5:00 fl Area: Oooguruk 05:00 Depth 9730 iii Location: North Slope Progress 24 hrs: 0 t Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH 4 Job No.: AK- AM- 0005556601 Report For: Herb /Rod 4. Daily Charges $3,500.00 Total Charges $80,500.00 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: 4 4, R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 ,' Il ? Gas (units) 550 920 7980 8964 Flow Rate (spm) 0 Gallons /stroke 3.6 ' ve Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec./qt) (cc/30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % I %f 9730 12.0 12.0 48 15.3 23 24 32000 0.02 15.5 ,- .4.,,,7'' � BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition Ai; IC I 4 SecFM3655Z 8.75 1.116 0 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15-20 150 5 7 BT A - X - - JD TD Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - y ip (current) i Gas Breakdown Gas (units) Chromatograph (ppm) M Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type fitl'L 8 627 to 8716 5401 1082 16093 4580 2915 5300 148 TG 6N I 111 8728 to 8981 1001 189 12172 3749 1371 547 64 TG 8982 to 9021 7980 1608 15978 4420 3345 1440 178 TG t to I z " to g' to gi to ON to y to . . to Liti to 1 Gas Type abreviations: BG - Background Gas; G P - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas i si /P ll ii M // . / ,•'3 \ ` .ate ' \'4 24 hr Recap: RIH Work tight sections, weight up mud, continue to RIH to 9021' y 0 ' -?. Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air \ ;. W kyeuel plw iii i o 7_ 7 ,,, �\ 4.... ,34.1 \ '• 17 i .,. tt I rr 41111.4- ga / i rc \\ \z\..< r Customer: Pioneer Natural Res. Report #: 25 Well: ODSK -33 Date: 03/13/2008 -5:00 $ Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH I Job No.: AK -AM- 0005556601 Report For: Herb /Rod Daily Charges $3,500.00 Total Charges $84,000.00 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: % R.O.P. ( 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (•si) 0 % Gas (units) 522 , , , 561 4900 9088 Flow Rate (spm) 0 Gallons /stroke 3 6 7 \\� \� r ` \ i j " , ; r r i p\\ ,.. `� \ ? �. 6 \\\ Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % I 9730 12.5 12.5 50 26 22 38,000 0.10 18.3 4, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 SecFM3655Z 8.75 1.116 - 0 - - -- I 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 5 7 BT A - X - - JD TD Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ------ - - - - -- °' . ..o „. :.11, 4 <:. , fic„ ..z,L 4 Viz; . : .� 4 » i, .. ... c . .f f Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type \ �' 9026 to 9243 4900 350 13591 5107 3031 1208 125 TG I 9243 to 9320 4166 604 13867 4025 1893 690 87 TG • 9324 to 9410 4088 931 15459 4543 1821 693 110 TG to I is4 to to to to . I to to el to 5 Background Gas GP Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; Gas Type abreviations: BG p p l POG - pumps off gas; TG - Trip Gas it R 41 .\ g , \ \ \\ k..`.. \� ;',:' -.: -- :<r. .... ,; F i:5:...7 • aittM14,, , r, -'' , \ : \ 24 hr Recap: RIH Work tight sections, weight up mud to 12.5 ppg, continue to RIH to 9411' I? r O Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air -L • I \ Customer: Pioneer Natural Res. Report #: 26 Well: ODSK -33 Date: 03/14/2008 -5:00 r Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH t Job No.: AK -AM- 0005556601 Report For: Herb /Rod Daily Charges $3,500.00 Total Charges $87,500.00 kt '.;5, 4.0:::::,' I / 3'CcIr< 7 \ 1 e \„ N %, :7 ` 1, Z ' ice ;Y N i ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 yA I Gas (units) 0 359 3808 9438 Flow Rate (spm) 0 Gallons /stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 0 9730 12.5 12.5 48 17 23 38,000 0.10 18.3 \s BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 SecFM3655Z 8.75 1.116 - 0 - - -- ,. 3 SecFSF2565Z 8.75 0.863 42 5 8491 9730 1239 15 - 150 5 7 BT A X 1 JD TD � ` a /iii � \a r/ g % � Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ I (current) ------ - - - - -- Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9421 to 9442 705 321 14713 4475 1481 612 75 TG 1 9442 to 9440 3808 613 12912 3966 1297 516 83 TG 0 9440 to 9700 909 316 10070 3683 1663 491 93 TG to to LA � �` to to 1 4 to ,,, to t ri o to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas __- ,!.:s1,,,,,,,i: I j 24 hr Recap: RIH Work tight sections, weight up mud to 12.6 ppg, continue to RIH to 9700', pull back to 9472' I i I I Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air I 1 ,,,,,(:;:;,,,,,:j iil ' y. , < � /i/ ,p . �. ,y fi r ':� � ;z p'y'' ! � %' �.�o r� r , o \ ... , -.: ,:''�.,� 4 .,, n \ fir. . _ ✓- . „ ..4k, � .. 'P,,: i:: r. 4�,,'. ✓L �.� ... „ ; .. % Customer: Pioneer Natural Res. Report #: 27 I HALLIBURTON Well: ODSK -33 Date: 03/15/2008 -5:00 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 1 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH I • Job No.: AK -AM- 0005556601 Report For: Herb /Jim Daily Charges $3,500.00 Total Charges $91,000.00 • ROP &Gas. Current Avg 24 hr Max Max @ ft Pump & Flow Data: \: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 1 Gas (units) 0 46 392 9690 Flow Rate (spm) 0 Gallons /stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % 9730 12.5 12.5 54 13.3 27 27 33,000 0.20 16.5 . BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition" 4 SecFM3655Z 8.75 1.116 - 0 - - -- % 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 5 - 7 - BT A - X - 1 - JD - TD I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) ------ - - - - -- I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 92969 to 9666 392 89 1615 564 221 65 55 TG ,, 1 to r to to to to :4 to 111 to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; , FOG pumps off gas; TG Trip Gas l/r li ✓ ,,n 0 , 7 ` ,,; wN :, N't , ,,,,, Aqzfror x fir // 24 hr Recap: pull back to approx 8256', run back in for hole cleanout, circulate to condition hole, transfer mud from RSC ` {' POOH to surface fi S 11 A Logging Engineer: Boyd C Piercey /Wayne Hermanson * 10000 units = 100% Gas In Air ii \ , : `, ? :, 7 ,, y ,\ / %iii II I I 1 Customer: Pioneer Natural Res. Report #: 28 Well: ODSK -33 Date: 03/16/2008 -5:00 '/ Area: Oooguruk 05:00 Depth 9730 '. Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Fishing �, Job No.: AK -AM- 0005556601 Report For: Herb /Jim Daily Charges $3,500.00 Total Charges $94,500.00 4k ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm 0 SPP (psi) 0 I Gas (units) 0 0 0 0 Flow Rate (spm) 0 Gallons /stroke 3.6 , " •.. i o a �', , \\ rii Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids p (sec/qt) (cc/30 ) ( (mg/I) (lbs/bbl) ( ) Depth in out sec/ t cc /30 min cP Ib /100ft m /I Ibs /bbl Pm /o 9730 12.5 12.5 53 13.5 29 23 33,000 0.20 16.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ' 4 SecFM3655Z 8.75 1.116 - 0 - - -- , 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 5 - - BT A X 7 JD TD \ I , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ------ - -_ - -- I , Gas (units) Gas Breakdown Chromatograph (ppm)' Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to . I il to to I \ Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; c POG - pumps off gas; TG - Trip Gas.. '%'/ 24 hr Recap: Trip out of hole to surface, pressure test BOPs, run in hole with fishing tools to approx , 1 ,s I iLoggng Engineer: Boyd C Piercey / Wayne Hermanson 10000 units = 100% Gas In Air I I I Customer: Pioneer Natural Res. Report #: 29 ` HALLIBURTON Well: ODSK -33 Date: 03/17/2008 -5:00 e 0 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Fishing Job No.: AK -AM- 0005556601 Report For: Herb /Jim , Daily Charges $3,500.00 Total Charges $98,000.00 ; .. ,;'ms '" 0 R OP & Ga s : C ur r ent A v g 24 hr M M ax @ ft Pum & F D ata: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow i n (g.m) 0 SPP (psi 0 I t Gas (units) 45 78 1025 8488 Flow Rate (spm) m, 0 Gallons /stroke 3 6 p ✓ ' \ a \ \ 4 % , Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % , •, A 9730 12.5 12.5 60 12.5 32 34 34 000 0.20 16.5 %° BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 SecFM3655Z 8.75 1.116 - 0 - - -- 3 SecFSF2565Z 8.75 _0.863 42.5 8491 9730 1239 15-20 150 5 7 BT A X 1 JD - TD I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ' (current) - - -- - - - - -- , y'` . . , iii .. ? ,,, 4 0 a. ; G as Breakdown Gas (units) Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type y 6887 to 6795 422 216 I O 7004 to 8691 449 49 8387 to 7958 1025 148 4 to to to to • , ., to 1 to to I \\\ \\ � Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG pumps off gas; TG - Trip Gas 24 hr Recap: Run in hole with fishing tool, watched parameters while fishing, POOH to retrieve fish, work tight section @ 7977 \ a / Logging Engineer: Boyd C Piercey / Wayne Hermanson 10000 un its = 100% Gas In Air 0. Il Customer: Pioneer Natural Res. Report #: 30 I HALUBURTON Well: ODSK -33 Date: 03/18/2008 -5:00 . Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Fish s Job No.: AK-AM-0005556601 Report For: Herb /Jim Al Daily Charges $3,500.00 Total Charges $101,500.00 , ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: � R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (g•m) 0 SPP (psi) 0 I Gas (units) 0 44 168 7965 Flow Rate (spm) 0 G a ll ons / s t r o k e 3 6 f' ii// ` a i ,. f % \ Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids o I ', /o Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) 9730 12.5 12.5 58 13 30 27 34,000 n, 0.10 165 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition \ 4 SecFM3655Z 8.75 1.116 - 0 - - -- 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 :15-20_ 150 5 - - BT A X 1 JD TD Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - il , y , (cu - ----- - - - - - - �. \ VDT„ %// °; I ::: Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type i 7965 to 168 44 POG I to to to , to 1 i to to ,4 to to _;i to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I. POG - pumps off gas; TG Trip Gas II 24 hr Recap Working tight section @ 7977' , Pump Black Magic pill, combined with diesel displacement, wait for pill to work, E perform rig maintenance, Pill soaks and is bumped 1 bbl every hour with the mud pumps, 68 bbl displacement around fish with 48 bbl diesel preflush before the pill t. i '%'''' • `'', Logging Engineer: Boyd C Piercey / Wayne Hermanson ` 10000 units = 100% Gas In Air ti I 1 / %,\ 7. Customer: Pioneer Natural Res. Report #: 31 I ' , HALLIBURTON Well: ODSK -33 Date: 03/19/2008 -5:00 v . Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Fish ,, I 4 mi Job No.: AK -AM- 0005556601 Report For: Herb /Jim s Daily Charges $3,500.00 Total Charges $105,000.00 i4. ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: \. o R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP .si) 0 ' Gas (units) 0 0 0 0 Flow Rate (spm) 0 Gallons /stroke 3.6 iA ... ,, /r , ,ZL .. .. • .a, \ .., . ,<. , ... k;, ,tea Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids , Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) I \` 9730 12 1 12 1 65 13 2 32 31 34 000 0 20 15 5 r . \ ,', a i r r \ ' b \ ' \ ` \ ' ! �%/i , BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I \\ 4 SecFM3655Z 8.75 1.116 - 0 - - -- 3 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15-20 150 5 7 BT A X 1 JD - TD tea\ ,\.a r /ra�. �\ \. , �� i.� \.. � //c .:a �r•%, rir;�\. «..� �� �:.'..�/i,.., Q �» \ \ \ P;,2,': ,, I 1 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _\, (current) ------ - - - - -- \ I Gas Breakdown go D Gas (units) Chromatograph (ppm) / Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type / to el to to '' to to t0 to / to � to j to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas I „ 24 hr Recap: Working tight section @ 7977' , allowed Black Magic pill to work longer, perform rig maintenance and clean up, torque & slump pipe pump occasionally to move SFT pill up hole Try pulling, let soak, evacuate non - essential personnel pull over usual parameters without success, continue to pull with some movement, start jarring approx 03/18/2008 @ 23:00 I Logging Engineer: Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air I EISIIvkifktt‘' '':.:-':lr::,::;.M;i1111eglkig,..';"*::'j:,':7kiikg5Z<::t: Customer: Pioneer Natural Res. Report #: 32 Pr I HALLIBURTON Well: ODSK-33 Date: 03/20/2008-5:00 ..: Area: Oooguruk 05:00 Depth 9730 4, Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC 44 I Rig Activity: Tripping Fish ,Aiii Job No.: AK-AM-0005556601 Report For: Jeff/Jim .. - .1 Daily Charges $3,500.00 Total Charges $108,500.00 I A J' iI1It 4P/ JItI 11P go ii ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: A . 2 R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 I 252 VI , Gas (units) 0 128 _ , 0 ,. FlowRate cspm) 0 Gallons/stroke _ ,,3k;,6,,,, • 44,4444r%444:4t4i;i4 ' 4,4'!tt 4 ' 'ij' ,,- Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 0 I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % 9730 12.2 12.2 69 13.6 32 30 34,000 0.20 15.6 ' .V%. W'., ' ,Z110%:,:;!ir,' . . ,1Z:.::;..,:::Mk :- ;,:: .7 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition .0.1 I W 6 SecFM3655Z 8.75 1.116 9730 9730 L - I - H i 5 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15-20 150 5-7-BT-A-X-1-JD-TD A:tg;': ,VAZ:r:Wi;kNillt.rA Illiri . tiMEMII0WVJIT''' I is Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff , ill (current) I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to 252 128 POG IN I IN to .4 4 44 to to . 4 I 'Y to to 7 A to to l!'....4 I to ' '01 p to to I • Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ik POG - pumps off gas; TG - Trip Gas liank7I,:limmete '';-.' ::', Aiiit,:, A , -Litillmme '.:1;:::VZ. 4.1M5r, 1 mormasitvaxs.:401.. I 24 hr Recap: Using Jars to try and free pipe, unsuccessful, circulated SFT pill out, Unable to isolate it as it was strung out in 11 ,..‘ ,., the annulus so con det was added to emulsify oil into the mud system, cement plug, free point the drillstring, rig clean up 4.,. Oa ow I F% ...-.., II Logging Engineer: Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air 1 ' - "" m " - -. 1 :'$4" 4.— , 7 ' ' ' ''''' '' ' '' 1111101 zk " ;'/P42,:rii- A, .‘ -0 4gmosome.v I I Customer: Pioneer Natural Res. Report #: 33 I Well: ODSK -33 Date: 03/21/2008 -5:00 Area: Oooguruk 05:00 Depth 9730 Location: North Slope Progress 24 hrs: 0 A Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Fish Job No.: AK-AM-0005556601 Report For: Jeff/Jim Daily Charges $3,500.00 Total Charges $112,000.00 7; . '' t ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 v Gas (units) 0 9 247 6922 Flow Rate (spm) 0 Gallons /stroke 3.6 III y\ . Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec/qt) (cc /30 min) cP (Ib/100ft (mg /I) (Ibs /bbl) (Pm) % 9730 12.1 12.1 65 13 28 25 34,000 0.20 15.6 s. p ia, .p .�?: \ ‘ � \ i,. , .. ,, //• . - , a ,5,=:. , .. :i. _ ;&. * ,,; 0‘' .. • BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I ! 6 SecFM3655Z 8.75 1.116 - 9730 9730 - -- L - I - H 5 SecFSF2565Z 8.75 0.863 42.5 8491 9730 1239 15 -20 150 5 - 7 - BT A - X - 1 - JD - TD 0 o$.ii \.• e •• T Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff - ' (current) ------ - - - - -- I Gas Breakdown ` , Gas (units) Chromatograph (ppm) ( 0- 4 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type i. I 6922 to 247 9 POG to to to I to to to to t0 to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; • POG pumps if gas; TG - Trip Gas rj ..;.,. 24 hr Recap Unable to move stuck pipe, decision made to cut '© 6920' and POOH checking every joint for damage and 6. retorquing same. Iron roughneck repairs performed I Ii ... Loggng Engneer Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air 1 I Customer: Pioneer Natural Res. Report #: 34 HALLIBURTON Well: ODSK -33pb1 Date: 03/22/2008 - 5:00 I Area: Oooguruk 05:00 Depth 9730 V. , Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Ri Na bors 19AC Rig Activity: Tripping Fish ' err g g: 9 Y Pp 9 Job No.: AK -AM- 0005556601 Report For: Jeff /Jlm ' ; Daily Charges $3,500.0 Total Charges $115 j ......f/ ... yti ..,;, ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: /' R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (•si) 0 Gas (units) 0 0 277 6923 Flow Rate (spm) 0 Gallons /stroke 3 6 Mud Dat Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) I 9730 12.2 12.2 70 12 .8 12 25 34,000 0.20 15 6 \\ 'C, • // */' \ � \ i,, \\ . \ 2: ' '''' >' < 4 /<4 �i. ' . BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 Left in hole ' \\\ , • Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff c urrent ,, �¢.. . , .. /,i ,,. „, .1;i„ 7 ..:ham .....ii 'S .,.. ���\\ .� j Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type A 6923 to 277 147 11831 326 145 90 7 TG vii.r1:1 I \ 5990 to 189 130 4137 145 73 49 2 T to to \ \. I to to to ., to c to 0 ," to to \ I P Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas; TG - Trip Gas I LP 24 hr Recap: POOH checking and retorquing every connection to surface. RIH to approx 2900', Cut and slip drill line continue RIH past cement plug point, pump pill, circulate and condition hole for cement job, pull back 1 1/3 Stds, • pre job safety meeting for cement job, pump cement, pull back 7 stands and circulate bottoms up POOH , I > : Max gas at 277 units from bottoms up while at plug back depth 1 Logging Engineer: Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air -' I Customer: Pioneer Natural Res. Report #: 35 I HALLIBURTON Well: ODSK -33pb1 Date: 03/23/2008 -5:00 Area: O ooguruk 05:00 Depth 6240 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Nabors 19AC Rig Activity: RIH I '3 Job No.: AK -AM- 0005556601 Report For: Jeff /J Daily Charges $3,500.00 Total Charges $119,000.00 I k � \/ \ ;... :..... ... ,..... ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (•si) 0 I Gas (units) 196 19 277 6230 Flow Rate (spm) 0 Gallons /stroke 3.6 = Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth ,; in out (sec/qt) (cc/30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % i ‘' 9730 12.1 12.1 54 12.8 25 24 34,000 - 0.20 ;15.6 \. \�/ " : I:: Z, „ ,. :; c , ,..::. ., x. , .. : • , , / ii /%i'4., : BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 L eft in hole I oo o/ Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff . Lithl 9Y � o ): Y (current) ------ - - - - -- ill I G as B reakdown Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 0 to 6240 277 19 3251 114 59 32 2 TG k4 I N to to to I Ni: to to to to % 1 to to ,s, to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; � f i POG - pum off gas; TG Trip Gas 111 24 hr Recap: POOH after cement job, test BOPs, Pick up BHA and RIH to top of cement plug, prepare to drill ahead v . J Approximately 6240' @ 04:49 I Logging Engineer: Boyd C Pierce/ / Wayne Hermanson /.0:,. * 10000 units = 100% Gas In Air I z , 4, ,,%,_ 5.4 g' ' , ,. Customer: Pioneer Natural Res. Report #: 36 I W ell: O DSK -33pb1 D ate: 0 3/24/2008 -5:00 Area: Oooguruk 05:00 Depth 7110 riA Location: North Slope Progress 24 hrs: 583 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Ki I Job No.: AK-AM-0005556601 Report For: Jeff /Jim n Daily Charges $3,500.00 Total Charges $122,500.00 I ROP &Gas. Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 28.4 40.3 269.0 6812 Flow in gpm) 500 SPP (.si) 4150 I / Gas (units) 320 314 639 7003 Flow Rate (spm) 138 Gallons /stroke 3.6 ',� Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec/qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs /bbl) (Pm) % I 7002 12.2 12.2 6 \\ � � �\� � �� �� w * 2 32 ��� 26 32,000 5 6 � �\ � 70 2,000 0 20 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I BHA #8 HTC PCM506 8.75 0.778 14.4 6527 in hole 583 15-20 82 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 Left i hole , � Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - I 0 (current) 15 40 5 40 - - - -- _ '',:7?11 Gas Breakdown Gas (units) Chromatograph (ppm) y j Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 6291 to 6640 302 267 4999 313 149 100 7 BG I 6723 to 6723 517 12339 678 298 192 68 GP 6727 to 7000 503 347 12702 807 401 258 94 BG 7003 to 7003 639 36112 1885 897 558 139 BUG 7005 to 7100 397 328 7984 626 414 304 128 BG to to to u to to Nj to I ' Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG - Trip Gas , 0 I % 24 hr Recap: RIH to top of cement plug, drill into plug until hard cement is encountered then time drill to kick off of plug. ','"' Drill ahead paying special attention to all drilling parameters. Rig repairs to mud pumps Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system • I i,i ,#.; %,.: Logging Engineer: Boyd C Piercey /Wayne Hermanson * 10000 units = 100% Gas In Air I k ;,.,.42--''.,:;:f*Nr:::"1.33117,;;T'*,,V; '9"iilikiliaNLVSirmiic,,,Allqie%PirT-11,......iily, ..LiSEinitZ7rn tAr) Customer: Pioneer Natural Res. Report #: 37 ,‘ t, I 1 HALLIBURTON Well: ODSK-33pb1 Date: 03/25/2008-5:00 W,1 \ Area: Oooguruk 05:00 Depth 7687 ?. Location: North Slope Progress 24 hrs: 577 • (: Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH "N I Job No.: AK-AM-0005556601 Report For: Jeff/Jim Daily Charges $3,500.00 Total Charges $126,000.00 I, : -;,::\,ns,2,, v'',TE g „;,:g ) ,Wr'Ir''''NJ,,, XtieNdifixF:171g51711111:7; 911117,- 4.4 • V : • ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 30.0 34.4 190.5 7261 Flow in (gpm) 500 SPP (psi) 4390 . . I • Gas (units) 320 290 „, ,, , 475 , 7107 FlowRate(spnn) 138 Gallons/stroke 3.6 , ,,,,,.g.::-. , ,,- ,,,,-,,,,,, ,:4,„ \ ','', A p "•,\. ei ,, :Pdlik 4 =.'41,..AASISIZI: 'IL '02 " .1e4t ' !:y Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 1•% I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % 5, 7565 ,„, 12.2 12.2 _ 65 _ _ , 30 25 34,000 0.20 15.6 , t ;7 1,L'k , e l.,4,, g:,., 4-.1",k. 2. 7. :: Vi"" T.L. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition r I ‘ BHA #8 HTC PCM506 8.75 0.778 31.15 6527 in hole 1160 15-20 100 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 Left in hole /, \,..:,1 PA ."'N‘ \ : ,11.0% ,\, , / / 'kV ' 1 7;!'nt ' ‘:V Tri- -,Tf-w - - , n...:4, . -74t 2, I ;, Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ,.. (current) 10 20 40 30 . k..:;:<%;;''' - ' '." .„2-,„, '''', , :,',•, ,, ;':: \ '''*&';'4:„ - -4 /4,Z::::-. IA...! , ,4&&,... , ,,s0'' > );iv.m., %».4,;;4,,,., *,;1$. 1Igt&-.....d"&i,a . L'I. "'.. 'k' "? 111 Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 7107 to 475 17690 963 556 380 168 PG I ,,,;, 7110 to 7590 400 285 8352 589 405 350 184 BG \> ... :: 7600 to 7685 377 343 8108 410 305 354 211 BG .0 to .... I to . „ Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 4 I 24 hr Recap: Continue drilling ahead as per SSDD program, sliding and rotating, from 7110' on, pump high vis sweep at 7529. • Continue drilling. • Note • Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system ' \ I ) .,. I Boyd C Pi Logging Engineer: oyercey /Wayne Hermanson Ok ' :., * 10000 units = 100% Gas In Air ‘; 1 :;::: N'O'' -„,, .c: ' ' ......2\Le .asatiLw .;EiAt'' ' " I I I %,- - ,:-4;t::7r7k-,.'‘„: Customer: Pioneer Natural Res. Report #: 38 • ' HAL ,, LIBUMN I i ...., Well: ODSK-33pb1 Date: 03/26/2008-5:00 0, ,... Area: Oooguruk 05:00 Depth 8071.5 Location: North Slope Progress 24 hrs: 384.5 ',.. Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH ,. I '‘;: Job No.: AK-AM-0005556601 Report For: Jeff/Jim !;) Daily Charges $3,500.00 Total Charges $129,500.00 • ;.: *' " : T• ;" 'P::i :," Nli :::,':' 0' ,n: I z, : ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: rt R.O.P. (ft/hr) 71.5 20.5 96.8 8064 Flow in (gpm) 500 SPP esi) 4300j II .1 Gas (units) 230 , „ 266 ,,, 413 7705 Flow Rate spm) 136 Gallons/stroke 3.6 li 7 , '',:izi„...Ay./ .7, Mud Data Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) % I 7939 12.2 12.2 60 30 25 34,000 0.20 14.5 „y4 1 4 .7, -, ;ri ;;-/„., .•)',,, ff,,.,', . '.1 '.‘ 6, \ ,. :., - ' ,:- , ''''' " " — 1,,, , ,, :mtkpA,„:77.€16,,,, '''q%7:4 •'"; BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I ' BHA #8 HTC PCM506 8.75 0.778 49.91 6527 in hole 1544.5 15-20 143 , 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 Left in hole ' I i 1II ' 1 ' .,:-4 P' -;', , ,*•; 7'6, ,„,,,,--,7„: I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 10 5 10 80 )gifiv. 4ijrfar,„„„„„„:4* J:1„ ,;',4 , ,'„A:1„,„AfFt„... , Ear- ipitio ,7 I , Gas (units) Gas Breakdown Chromatograph (ppm) ..., Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 7686 to 7783 413 323 4180 277 206 230 140 BG I 1, 7785 to 8068 311 241 3389 174 108 119 55 BG to to v4 I \ - ,!. to _ to , , to I '; to to kii I , Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; f \.'. yp BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ‘.4 I 24 hr Recap: Continue drilling ahead as per SSDD program, sliding and rotating, from 7687' on, pump high vis sweep as .: required, continue drilling. f 1 A Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system rffl, kui I ' Logging Engineer: Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air ry • i ' .• ''''.1,,,, :;, 44"': ,y,:' 7 " ; , N 4Y / 7 -: : : :,;;„th, / 4:Ve ) M.L.7 4 ,%i) . ;,721 -4 14Crideii.P 3" -..:''4,1E 4 77r " :';Ii;.i:TiirP :4 1;:iti II I I 1 1 • \ Customer: Pioneer Natural Res. Report #: 39 I 0 HALLIBURTON Well: ODSK -33pb1 Date: 03/27/2008 -5:00 4. Area: Oooguruk 05:00 Depth 8190.2 1. Location: North Slope Progress 24 hrs: 118.7 \\\\� Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH 1 Job No.: AK -AM- 0005556601 Report For: Jeff /Jim Daily Charges $3,500.00 Total Charges $123,000.00 \ ' .= ROP&Gas: C urrent Avg 24 hr Max Max @ ft Pump & Flow Data: / R.O.P. (ft/hr) 0.0 25.0 140.9 8074 Flow in (gpm) 442 SPP (psi) 2578 4 Gas (units) 197 173 340 6192 Flow Rate (spm) 121 Gallons /stroke 3.6 1 \ /''' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) Iff g 7 ... 7939 12 2 12 2 60 30 25 34,000 0 0 14 5 S \ , .. \ \� 'd. \\� „moo\ � � „z` \\\ /..c.� .. , ,. ,a � � c \ y.:o\ . : \ T�''> \\ ... �� • BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I BHA #8 HTC PCM506 8.75 0.778 54.65 6527 in hole 1663 -- ° 6 SecFM3655Z 8.75 1.116 42.5 9730 9730 0 0 Left in hole I 0 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - (current) 5 5 10 80 -_ - - - ii Gas Breakdown Gas (units) Chromatograph (ppm) \ "' Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type , �\ 8072 to 8190 284 249 4130 222 107 90 34 BG I 8190 to 8068 263 203 3199 177 97 82 21 TG .\ ," 6617 to 5350 340 187 6798 441 223 157 69 TG \: to I to to to to 1 to t to \:. to 1 \ Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; el w BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 r o 24 hr Recap: Continue drilling ahead as per SSDD program, sliding and rotating, from 8071.5' on, pump high vis sweeps as required, continue drilling to 8190.2 and POOH, work tight sections at 5849' to 5842', continue to POOH to approx 5300' s I Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system :a 1 °.\ Logging Engineer: Boyd C Piercey / Wayne Hermanson * 1 0000 units = 100% Gas In Air I I Customer: Pioneer Natural Res. Report #: 40 I Well: ODSK -33pb1 Date: 03/28/2008 -5:00 Area: Oooguruk 05:00 Depth 8190.2 0., Location: North Slope Progress 24 hrs: 0 ill Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH / Job No.: AK -AM- 0005556601 Report For: Jeff /Jim F .'. Daily Charges $3,500.00 Total Charges $126,500.00 IN / ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (..m) 0 SPP (.si) 0 I 0 3 Ga s (units) 0 9 239 5 2 88 Flow Rate (spm) 0 Gallons /stroke 3.6 ;., ; �,,. , \ \, : s t: Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids / Depth in out (sec /qt) (cc /30 min) cP (Ib/100ft (mg /I) (lbs/bbl) (Pm) % A ' I I 8190 12.2 12.2 58 29 26 34,000 - 040 164 \\ . _BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 9 FMF3653R 8.75 1.035 - 8190 in hole - - - -- 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15 - 100 ` /c. , // \ ,:h +.N \ - .. /irk:. ; E , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - (current) 5 5 10 80 - - -_- / / rte.\ /:. „,. e. me ` Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 5319 to 3139 239 80 2287 206 130 90 40 TG to _ v, 3 141 to 3153 118 35 814 66 54 4 9 TG to to :,.. I to to o ; to ,. 04 , to I 1 to y to T I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 44 BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas I g 24 hr Recap: Finish POOH, lay down /rack back BHA, perform rig maintenance, pick up and RIH new BHA #9 Test MWD tools and continue running in hole. Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system 1 Logging Engineer: Boyd C Piercey / Wayne Hermanson 10000 u nits = 100% Gas In A i r may\ I ...,. 7 , ,;'",',;•,,., ec Tall Z ' Customer: Pioneer Natural Res. Report #: 41 I L'• HALLIBURTON Well: ODSK-33pb1 Date: 03/29/2008-5:00 P 1" P Area: Oooguruk 05:00 Depth 8800 ti) Location: North Slope Progress 24 hrs: 610 Sperry Drilling Services Ri Nabors 19AC Rig Activity: POOH f,1 I Job No.: AK-AM-0005556601 Report For: Jeff/Jim ' Daily Charges $3,500.00 Total Charges $130,000.00 „-• :;,,,. I �L t,';z2Y:eZZL, ' .- f:;:17,,,TkLiEtZvzt.::: V ROF&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 45.0 39.5 160.7 8570 Flow in (gpm) 520 SPP (psi) 43 73 - : I Gas (units) 7'.*.17fi,, 394 230 514 , 8685 Flow Rate (s.m) _ 143 Gallons/stroke _ , 3.6 '1 '1, \, .t;! \ K V: 1 ‘,,,, ,..) :":";"::.'f'''' 7 ;;;.>, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solid \ Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) / 3 ° I 8617 12.6 12.6 53 22 27 34,000 16 & ,Lini. PK i7.427 ::a& 4:Az TT , g , r:.n , 1 7z, TILsirla R, _ - ::j '.: n ,`, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 FMF3653R 8.75 1.035 15.4 8190 in hole 610 15-20 150 a 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15-20 100 4° "°' s t* ' 4 'r '.'41,t,...,221,I, :AZ,i;e:.seitS77%..<-201X ,,74;::,WL:;:z":', I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 4' ' (current) 20 80 r : '', '''...;* '''IiLA . ''' :, ‘!:/ ./'' • '' Gas (units) Gas Breakdown Chromatograph (ppm) ,.< .., Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 40 , . 8190 to 7208 256 118 5554 268 119 76 26 TG to -=.0 I > 8192 to 8550 118 35 9393 497 213 197 99 BG :-. 8555 to 8745 513 387 24380 1168 429 206 74 BG ' to v to to to : Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; \ I 1 -:' BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I 424 hr Recap: Finish RIH to 8190', Continue drilling ahead as per SSDD program , 0 0.‘ .= ! Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system ",, t-' 1 k A ll '/ K1 Logging Engineer: Boyd C Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air ” 1 Customer: Pioneer Natural Res. Report #: 42 ' Well: ODSK 33pb1 te: 03/30/2008 -5:00 Area: Oooguruk pth WA ::!3 rs: 4 ity: or: s $133,500.00 j`; % I ROP &Gas. Current Avg 24 hr Max Max @ ft Pump & Flow Data R.O.P. (ft/hr) 41.0 30.0 159.9 8850 Flow in (•pm) 506 SPP ('Si) 4501 Gas (units) 311 455 802 8856 Flow Rate s•m) 140 Gallons /stroke 3 6 'A4J Mud Data Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec/qt) (cc/30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % ,�_ ;\ 9271 12.5 12.5 5 -- 25 35 34,000 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 9 FMF3653R 8.75 1.035 35.6 8190 in hole 1216 1 150 8 HTC PCM506 8.75 0.778 54 65 6527 8190 1663 100 ' iii \x. Z', „ . <X\: i ii ... i . % � %% \ <4 ' k<f .' .�//' \ , .\ \\. ' Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff -c - ( current ) - -- 20 -- 80 - - - -- Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 8856 to 802 69542 3396 1076 326 160 PG 8854 to 9063 725 524 38298 2150 828 378 152 BG 9066 to 9193 485 391 22855 1297 625 341 139 BG 9195 to 9370 376 320 15976 903 453 281 131 BG to to to to to to to I ° Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; :i 1 BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ‘ , („1 I 24 hr Recap: Continue drilling ahead from 8800' as per SSDD progra I Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system C ' Logging Engineer: Boyd C Piercey / Eugene Payne " 10000 units = 100% Gas In Air i I ,i,_ , I 1 1 ://M Customer: Pioneer Natural Res. Report #: 43 Well: ODSK -33pb1 Date: 03/31/2008 -5:00 0 II Li Area: Oooguruk 05:00 Depth 9763 Location: North Slope Progress 24 hrs: 357 ' • • Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling II tri Job No.: AK -AM- 0005556601 Report For: Jeff /Rod 0 Daily Charges $3,500.00 Total Charges $137,000.00 ,\ \3: r \ �T \� /N :.:\ i / % . ;_. N 4 _ :. tea ,,. ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: f, R.O.P. (ft/hr) 9.0 18.7 81.9 9516 Flow in (gpm) 516 SPP (psi) 4330 I ; , o Gas (units) 300 352 968 9620 Flow Rate (spm) 142 Gallons /stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec./qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) %. I \ , " 9718 12.5 12.5 52 20 35 34,000 -- 17.2 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition r ,, I 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1573 20 -35 150 8 HTC PCM506 8 75 0 778 54.65 6527 8190 1663 15 -20 100 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ I 1; (current) - -- 20 -- 80 - - - - I Gas Breakdown Chromatograph (ppm) lk zo Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9397 to 9619 585 358 22429 1178 509 289 130 BG 9619 to 392 255 10708 610 303 197 112 CG / 9620 to 968 36110 1619 590 301 153 PG 9624 to 9674 392 296 17450 944 433 269 130 BG 9679 to 662 50752 1771 622 327 144 PG U 0 9692 to 9716 321 291 18167 891 407 248 119 BG 9717 to 417 338 32751 1437 563 313 162 CG 9718 to 9757 408 279 16997 856 384 230 106 BG � % I to to to i % I / Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; r47,,; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I i 24 hr Recap: Continue drilling ahead from 9406' as per SSDD program, Pump high vis sweep at 9671' I Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system \ � c Logging Engineer: Boyd C Piercey / Eugene Payne 10000 units = 100% Gas In Air kv , . n / 1,;R . - n, %i i +-: ,\ I I Customer: Pioneer Natural Res. Report #: 44 Well: ODSK-33pb1 Date: 04/01/2008-5:00 . k, Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 45 N Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling t 1 Y Job No.: AK-AM-0005556601 Report For: , Jeff /ROd Daily Charges $3,500.00 Total Charges $140,500.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 25.0 98.6 9798 Flow in (gpm) 275 SPP (psi) 800 Gas (units) 122 197 1028 9595 Flow Rate (spm) 76 Gallons /stroke 3.6 ' ` Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (lbs/bbl) (Pm) % ° 9808 12.5 12.5 47 23 26 34,000 -- 15.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 -25 150 I '` 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15-20 100 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _/_ (current) - -- 20 -- 80 - - - -- z. I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 9763 to 9808 199 166 7746 391 173 107 34 BG 9808 to 682 60480 3085 1198 503 200 BUG 9711 to 9683 248 173 9246 550 259 140 53 TG 9683 to 8734 1028 278 24500 1112 408 186 66 TG %" I 2244 to 6699 400 170 14938 650 253 127 42 TG to \ ' to ,,' to to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG - Trip Gas <.. /\ 3 / \ Ya �^g«, a te - �� �,.� rink,, r 24 hr Recap: Continue drilling ahead from 9763' to TD as per SSDD program, TD called @ 9808, observe for losses >° Observed losses approx 10 Bbls per hour added LCM to stop losses, continue POOH to approx 6650'. 4'' Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system , I Logg Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air 1 I ' ' % • '',, / .• ' 1 "°, '/- 't 'e ;` ‘\ , ' , aw ‘,' '%'‘7‘ 2 7 '',..:' f.vz-p Customer: Pioneer Natural Res. Report #: 45 I HALLIBURTON Well: ODSK-33pb1 Date: 04/02/2008-5:00 Area: Oooguruk 05:00 Depth 9808 ,, •, Location: North Slope Progress 24 hrs: 0 ., Sperry Drilling Services Rig: Nabors 19AC Rig Activity: I Fishing k Y Job No.: AK-AM-0005556601 Report For: Jeff/Rod Daily Charges $3,500.00 Total Charges $144,000.00 1 ,:f, 1„.7,4,717,17. ' • " ROP&Gas Current Avg 24 hr Max Max @ ft Pump & Flow Data: ROP&Gas: , ) ..- R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) 0 SPP (psi) 0 I 3.6 Gas (units) 1:1 — . 82 156 6275 ,,,, „-,- 6 /' •‘ F''!"7"(sP-T 0 ' '''v, G , '%”, , A, ' -,, - fy, ,_,,./, ,-, , „z,...: ,,- „/„, _ 7, ........ t:L-,.... ?A ii , a,,ia.,, : N•/,''' , v , Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids . ,Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % 9808 12.5 12.5 38 14 15 34,000 15.5 i- ...4K..„1itr.. : ' 'sx , t:% A „ \-0 sy .,,,.,-,/ 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 10 Fishin. tool 8.5 0 9 FMF3653R 8.75 ', /<,,/, )\; \”' ' ',% ''..n.:...: ' ,;., • :!:" ' ''..':::".1,... ' 71,az.:!:...-r,,,„, - v....2.__ . .. ', Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 'A I 4 (current) :4 ;', \ A c'/: :;; zVe,, ';',' - '''',•: :770 ,A: k\ '2P,"1„x,.'Lg''''tNt4,.a.y;77:aiSuo'..:f7 I Gas Breakdown Gas (units) Chromatograph (ppm) .1 Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type I 6555 to 3716 156 82 4163 212 118 78 21 TG - , to 7 o — • to 1 to — t to to — WI to ..4 0 to to r to ; \ , to 4 , , ,,,....4 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I i BUG Bottoms Up Gas: FOG - pumps off gas; TG - Trip Gas kA I `, 24 hr Recap: Continue to POOH working tight spots, pumping when necessary, continue to POOH Test BOPs, cut and slip drill line, perform rig maintenance, Prepare and RIH with Fishing tools. \',‘ 1 2'; Note: Some gas values exaggerated due to diesel and other hydrocarbon based solvents in the mud system ,N S :, Logging Engineer: Boyd C Piercey / Eugene Payne * 10000 units = 100% Gas In Air mi ''' — ' % al- IT 7 4 4 .-•',,,:',,„ ";,-, , ,, I I Customer: Pioneer Natural Res. Report #: 46 I i HALLIBURTON Well: ODSK-33pb1 Date: 04/03/2008-5:00 k Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 45 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling • Job No.: AK-AM-0005556601 Report For: ,s1 Jeff/Rod Daily Charges $3,500.00 Total Charges $147,500.00 N • ''', , -, " - ,'••• ,",,,, '1‘4,e „' ' wil '''‘Vit/ -- "m14..4', 4 c. le e<,..,, 1,; , ;$r.'L* - I / ,, ( . ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: '? R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (.pm 0 SPP (.si) 0 ",:' 1 „‘ Gas (units) 0 100 475 9808 Flow Rate (spm) 0 Gallons/stroke 3.6 . - / ' • ° ' '' - worwksfe4fr ,,, - ikk., , , ‘,•,'',,, --, , i: z ' - --k, irkw ---om :4, : z Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 4 I -, Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % t 9808 12.5 12.5 46 20 24 33,000 17.6 '`'' ' , ,,' ''• : ''% , N <0 12, , ':.':- ‘,, 7 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I : I FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20-25 150 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15 100 q I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff / (current) ,./ r'l I ' Gas (units) Gas Breakdown Chromatograph (ppm) 4, Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 6 --' '''' mi to to _ I 14 to *, to f: I :0..„''4 to J 0 6 0 . to k to I to to , •,,, I i , Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ,.. „ '" BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 24 hr Recap: RIH with fishing assembly. Grapple fish at 4295'. Work fish up hole. POH to inspect grapple. No fish. Service rig and inspect derrick. RIH with fishing assembly to try again. V , I , I , . . -, Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air ' ' ,J ‘- , „,' I A % tftw,,,,z4L;711._ \ `',Wilihrd•,,„,:kaL. tit.,—„„,. -‘ 2 ‘ :,':::.' ,=:„!i.A..._ ‘...LIt.A.., al„z-t.:1 ''„ ,-/‘ , - ,.',!, Customer: Pioneer Natural Res. Report #: 47 r I HALLIBURTON Well: ODSK -33pb1 Date: 04/04/2008 -5:00 Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 0 S perry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling ;:, Job No.: AK-AM-0005556601 Report For: Jeff /Rod Daily Charges $3,500.00 Total Charges $151,000.00 I ' \ r / \, ' � ,y ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm 0 SPP (psi) 0 • Gas (units) 0 100 135 9808 Flow Rate (spm) 0 Gallons /stroke 3.6 ' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids in out (sec /qt) (cc/30 min) cP (Ib/100ft (mg /I) (lbs/bbl) (Pm) % IDepth 9808 12.5 12.5 53 16 24 34,000 -- 18.0 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 -25 150 I 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15 - 100 N,c�, / / /;o��‘\\. %4 ,. ''.. „9TH _ 0� - ., , .... ,,. • I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff FA (current) ---- - - - - -- j , Gas Breakdown ti Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to ht \ to to I to to to to to to to ti I j Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas ''''k I ' 24 hr Recap: RIH with new fishing assembly to top of fish @ 4163'. Grab fish and work it lose. POH w fish. Lay down old BHA and break down MWD tools and read MWD tools. Begin laying down pipe racked back in the derrick Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air I 1 PI " Customer: Pioneer er N Res. Report #: 48 ,ffij' Well: ODSK -33pb1 Date: 04/05/2008 -5:00 4 Area: o 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping I N Job No.: AK -AM- 0005556601 Report For: Jeff /Rod m Daily Charges $3,500.00 Total Charges $154,500.00 e e. ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (• •m) 0 SPP (psi 0 I N Gas (units) 0 100 135 9808 Flow Rate (spm) 0 Gallons /stroke 3.6 . is >, Mud Data Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) ' 9808 12.5 12.5 53 16 24 34,000 -,, 1 .0 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 - 150 Ffl 8 HTC PCM506 8.75 0 778 54.65 6527 8190 1663 15 -20 100 I (current) Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - ------ - - - - -- sN 3 r te., `;. I 7 Gas Breakdown j Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to to to ' to to to to I to \ to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; %% BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas VF'4tos"r,‘,,,,4, a I 24 hr Recap Tripping in and out of hole to lay down old 4" drillpipe. Circulate and condition mud. TIH with singles of new drill pipe. POOH full stns and rack back in derrick. 0 , iI! I Logging Engineer: Colby Marks /Eugene Payne 10000 units = 100% Gas In Air I I I X,7.:t. 7 ,..:.:: , 24e:711:W. ',03, Customer: Pioneer Natural Res. Report #: 49 I IHALLIBURTON Well: ODSK-33pb1 Date: 04/06/2008-5:00 Area: Oooguruk 05:00 Depth 9808 ‘, . f 4 Location: North Slope Progress 24 hrs: 0 • Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK-AM-0005556601 Report For: Jeff/Rod • s:1 Daily Charges $3,500.00 Total Charges $158,000.00 I i' ACE:..›.4.a ?'..1f,,i: 2 '''::6-4r4t htz_ .. -A.Ruat • 4 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (.pm) 175 SPP (.si) 1170 I Gas (units) 0 175 549 9808 Flow Rate (spm) 47 Gallons/stroke 3.6 ,„.T: .' -' 1. .„,'A'-' ,) f..6,,' ,>? Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids of I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % '< 9808 12.5 12.5 53 _ 16 _24 , 34,000 18.0 V - '.‘ ''': ::" '!,:: \''// - ')/ 9 ' ' ,' ft '/: ''i -'..,:‘"'"": '''*, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 0 i....ff I FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 150 , 8 HTC PCM506 8.75 0.778 54.65 6527 81 ,,,,, 1663 _ _15-2 , . __1 ,,,,,„ , ,,,,,,,,„ .., 7 ,,,,, , litafl.: SkillikT .2 ' 1:attifai .11.2,17 .. . .Zfit 'A:lii,i-,11:1t:;,,... 'Lla,„ Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff , (current) II \ ,4 N'Lr, \, •k. -;;; ,,..:',°., T,.. \': \ Y s' \ ,'r ':!".4>E19Iiit Arigtitxt,thi;W.N!::j'ilw . W. >''AV I I Gas (units) Gas Breakdown Chromatograph (ppm) 1 ... C2 C3 C4 Tot C5 Tot Type I') Depth Max Average Cl 7; I 6 9000 to 9093 695 300 58035 2302 744 290 114 TG 9093 to 9205 2310 500 242154 7973 2089 161 185 GP P to to to I O. , v‘ to r I to , 111 #\'; I 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; :' . 2. BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas to I 4 24 hr Recap: POOH, picked up 103 joints of drill pipe, layed them down. Circulate and condition mud. RIH. Monitored well , Circulate bottoms 1.5 Xs so far , max gas 2310 units N: I kA 1 0. 0 I 0 Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air ',,,'4,1 I , I I Cus t ome r Pioneer r Natural Res. Report #: 50 Well: ODSK -33pb1 Date: 04/07/2008 -5:00 i Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 0 , r.J' �8l"t'y Drilling Services Rig: Nabors 19AC Rig Activity: Short Trip i Job No.: AK -AM- 0005556601 Report For: Jeff /Rod ;7, Daily Charges $3,500.00 Total Charges $165,000.00 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ' R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 548 SPP (.si) 3471 / Gas (units) 97 125 300 - Flow Rate (spm) 155 Gallons /stroke 3 6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /1) (Ibs /bbl) (Pm) % , 9808 12.5 12.5 62 -- 27 28 34,000 -- 15.5 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 - 150 ^ ; 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15 -20 100 j Lithology / (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current JY �° ° ) -- - - - -� , ;* „, , tea. a. ` ) ) ,/4, , " R " , '..: s I I. , ; Gas (units) Gas Breakdown j Chromatograph (ppm) \ Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type t to 1 to to to to to il to to 1 to to- to I \ Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas N v:0,-,,,"',' \\ I ', 24 hr Recap: Shot trip from 9669' to 8525'. Tight at 8868' and 9390'. Run in hole back to bottom.Washed and reamed tight spot.Pumped second 500bbI dilution, circulated and conditioned new mud. Continued POOH, currently working tight spot at 5727' tk I is Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air no le I 1 1 Customer: Pioneer Natural Res. Report #: 51 4 F , Well: ODSK-33pb1 Date: 04/08/2008 -5:00 Area: Oooguruk 05:00 Depth 9808 Location: N orth Slope P rogress 24 hrs: 0 I ' Sperry Drilling Ser v ces Rig: Nabors 19AC Rig Activity: Short Trip Job No.: AK- AM- 0005556601 Report For: Jeff /Rod 4 Daily Charges $3,500.00 Total Charges $165,000.00 ' `' '4,:,4".1%,%:, ; 'ISL ir , Oi, ,,, %v `F 'mod' ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: 2, ei R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 548 SPP (psi) 3471 Gas (units) 97 125 300 Flow Rate (spm) 155 Gallons /stroke 3.6 F f, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I y Depth in out (sec/qt) (cc/30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) 9808 12.5 12.5 62 27 28 34,000 15.5 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I \ 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20 - 150 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15 -20 100 \ \� .. ; . /o„ ,. �,e ..... , r .., ., ! ,. Win, �/'\ «. •'• \ I L ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - ` ;:_ ' (current) ------ - - -_ -- I Gas Breakdown G as (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 4, to to to , ' to s to to to to I to to tt to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 24 m hr Recap. Shot trip from 9669' to 8525'. Tight at 8868' and 9390'. Run in hole back to bottom.Washed and reamed tight spot.Pumped second 500bbI dilution, circulated and conditioned new mud. Continued POOH, currently working tight spot at 5727' 1 I Logging Engineer: Colby Marks/ Eugene Payne 10000 units = 100% Gas In Air 1 ;„ ''•:Zi:i'l ift '' — i Customer. . Pi oneer Natural Res. Report #: 52 I HALLIBURTON Well: ODSK-33pb1 Date: 04/09/2008-5:00 Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Run Casing C I di Job No.: AK-AM-0005556601 Report For: Jeff/Rod ri Daily Charges $3,500.00 ,. Total Charges $168,500.00 ... I rIL:OtkirAf :::::::i1F7'ff , , ',-,' • ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: OM ,v ' R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 0 SPP (psi) 0 N; Gas (units) 0 98 135 Flow Rate (spm) 0 Gallons/stroke 3.6 . r I s "!;'*Mo w 'r1111141111TAICE1:77 ,, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids 4 Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % I 9808 12.5 12.5 60 28 31 34,000 17.5 likAmaV445 -7 ';,;:iillikZ5' ''7111111111..' Ki;v1 tlXArkz,6,; BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 9 FMF3653R 8.75 1.035 54.73 8190 in hole 1618 20-25 150 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15-20 100 Allittii 7 N• EE : ,AEI,* , ' , 1fi.,);;; -'' ,t''; NAtatillOWII11111111111111011 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff vill I 0 (current) .7! ii t!! I 0 I ill'i Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average C1 02 C3 C4 Tot C5 Tot Type t„. to I to e). to tik to - kif II I k., to to to * g '1 I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; q 1 BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas iN I 24 hr Recap: POOH to shoe and monitored well at shoe. Lay down BHA, nippled up and tested BOP. R/U for casing run. Start running casing 'A A I I ;;;',-' Logging Engineer: Colby Marks / Eugene Payne 7.1 * 10000 units = 100% Gas In Air ',.--:.. , ., OM is ; . '',,:„':,,,,, zcierb,:rAM"i; ; , ':' , V::''WZIEflfltki:k4tfg7;zig;:NtIEMIISJMir:4:7til:11BBIIIIIIIIIIIIIIIIIIIIIIIIIIIIEEIIIIIIIIIIIIIIIIIIIIItilliiii II I Customer: Pioneer Natural Res. Report #: 53 1G . . Well: ODSK -33pb1 Date: 04/10/2008 -5:00 sg Area: Oooguruk 05:00 Depth 9808 I l Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Cementing Job No.: AK-AM-0005556601 Report For: Jeff /Rod Daily Charges $3,500.00 Total Charges $172,000.00 A 1 k\ : � � ,'' '' A 4 \ : w • �\ • l , E El ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 0 SPP (psi) 4 iii; 1 / Gas (units) 0 200 575 Flow Rate (spm) 0 Gallons /stroke 3 6 ; ' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % I 9808 12.5 12.5 69 27 30 34,000 16.5 i \� a , .. y .,, T , k' - .. {5,,, ,,, : • '': % %o\\\�\\:: .>) \., Mk a .\aka „G .' \\ 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition i I 9 FMF3653R 8.75 1.035 54.73 8190 I in hole 1618 20-25 150 8 HTC PCM506 8.75 0.778 54.65 6527 8190 1663 15-20 100 $ ��.. '': ,; / \ may / S"'/ \\ \ / / / % \ ,:./ y\ / Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ----- -__ - -- Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type > to II 4 to 11 1' to / %. t rl to to t w ■ to lit ■ 1 to to I II Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; gol EA BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas \ ..:�:�...��,l.vi/ /// / / %::�\ ���\. ; ., . J� t �,.., atiZoo.�\ " ` ��: \\\\� „ ✓ii i ��n\\ \'�..,�^.ri�i/y �/ �' ,......: �,&� 24 hr Recap: R/U and run casing. Lost 40 bbls of mud to hole. R/U and start cementing job. 5s y. 1' 1 Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air • \?.' o ✓ -\ / '+ c . £4 ?. o rb ��, , �, , -.; // \*? y e • II 1 1 ' % / °" f Customer: Pioneer Natural Res. Report #: 54 g Well: ODSK -33 pb 1 Date: 04/11/2008-5:00 Area: Oooguruk 05:00 Depth 9808 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: TIH I Job No.: AK -AM- 0005556601 Report For: ''' Jeff /Rod Daily Charges $3,500.00 Total Charges $175,500.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 0 SPP (psi) 0 I Gas (units) 0 0 0 Flow Rate (spm) 0 Gallons /stroke 3 6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Va Depth in out (sec/ qt) (cc/30 min) cP (Ib/100ft (mg/I) Ibs /bbl Pm 9808 12.5 12.5 62 27 29 34,000 , 16.5 d, . O\ ,: �`%i�a�,�F � \\ ,r ., � :..., a 4,„ .-_,_ o .. ii °� .,.. // ...: i c:1 iii - .dva1 � \\ : A ,, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 13 FMF3543zz 6.125 0.464 - 9808 - - -- ' tii 9 FMF3653R 8.75 1.035 54.73 8190 9808 1618 20 -25 150 I St Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) ------ - - - - -- oh I '� Gas (units) Gas Breakdown Chromatograph (ppm) . Depth M ax Average C 1 C2 C3 C4 Tot C5 Tot Type _, to ,, to el to I to to to to ,`,' to i s t0 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I 124 hr Recap: Cement 7" casing. Land casing. Dump and clean pit. Service rig. TIH with drill pipe to build stands for : ,,i,,, 4 :: ' , drilling • f ' Logging Engineer: Colby Marks / Eugene Payne 10000 units = 100% Gas In Air 99 g g Y 9 Y ,. 1 till -lieb,!:ir-:-,-nr.. • Customer: Pioneer Natural Res. Report #: 55 ;....,1 I E111:111 ,:, .. .i'i' HALUBURTON Well: ODSK-33pb1 Date: 04/12/2008-5:00 .... Area: Oooguruk 05:00 Depth 9808 4i 11 Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Freeze Protect Ila Job No.: AK-AM-0005556601 Report For: Jeff/Rod 1r Daily Charges $3,500.00 Total Charges $179,000.00 '?:t,"itZ;S.' ''Sr;,“Ii , .',,,:,„0;`,410,1111111 I ROP&Gas: Current A-A Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (gpm) 0 SPP (psi) 0 I Gas (units) 0 0 .■:) Flow Rate (s•rn) 0 Gallons/stroke 3.6 g .;af..../e's: -1111114t i; rf' 'iliMagic MIIIIIIIIIC.2 '-SAIIiitir::. 4eg, 40:t :64111LV:j-::_ffAiliMilik:N''trYfillAinniniCz;f;!' ' i' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) % 9808 12.5 12.5 62 27 29 34,000 16.5 ''7 - ' - -i-hhh; 7hf7,7'fh?ih'tihhh" , ' :::Whh::;74I''...711111diVi'f',4,ZZ: BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ' Ili I 13 FMF3543zz 6.125 0.464 9808 :1* , . 9 FMF3653R 8.75 1.035 54.73 8190 9808 1618 20-25 150 :4 Nommis„„„:1--,-, ' Ittelin: ' .., ','‘,', V'' ('4Ags:,:-,- , A :, R '' ..-,"';'- - " ' ' .".:'..- -""':-"'":''' I '- Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) — A.1111P--'' f -' 1 ,;!: 'q11110.V7 '' 1: '''411;c, Ae .';:' ':q1111111";1 I I -1 Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average 01 C2 C3 C4 Tot 05 Tot Type ,.,, I to - — to to to : !i: tO 1 '4 fa - " to A t __ M Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 01 I : BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas Illt , :4 , 0.42'+.50's's i'' 7-' ,' . '' . "..2.11Vi::. I 24 hr Recap: Finished picking up drill pipe and stand back in derrick. Make up BHA, do shallow pulse test with MWD tools I: , Loaded nuclear sources. Freeze protect well v, I P ...,. :4 1 I ' , Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air A _ I 6iii m Illillke',$?:1111174 ',, 7 icc;7,77 :5 ,,, .,,!. n:, 4:11110411rillinialiiii:e1/1,44i„ I 1 1 'MAY!':',VgiA' 4 : ,, :,:::,: Customer: Pioneer Natural Res. Report #: 56 Z I 1 HALLIBURTON Well: ODSK-33pb1 Date: 04/13/2008-5:00 Area: Oooguruk 05:00 Depth 9808 ..,,, Location: North Slope Progress 24 hrs: 0 : Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Displacing • Job No.: AK-AM-0005556601 Report For: Jeff/Rod Daily Charges $3,500.00 Total Charges $182,500.00 • 07 "Vi:;:Iii0 4, ',V.:4::gf,: :envINI k:t.K. ''''' A'* ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ....' R.O.P. (ft/hr) 0.0 0.0 0.0 9808 Flow in (glom) 0 SPP (psi 0 ; ''d Gas (units) 0 15 34 Flow Rate (spm) 0 Gallons/stroke ,4? , II ' 3.6 r, 07, .:,,z. :4, ..:, .. , Z'W::,;P:A'''' .,7 1714:777f,!; zi Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) % ',..., 9808 11.6 11.6 48 14 12 34,000 13.4 4 '1 '' A .. -": 1. U-,:' ,,, ''''''i4i , , ,,-;,''':,,, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 13 FMF3543zz 6.125 0.464 9808 rip I 9 FMF3653R 8.75 1.035 54.73 8190 9808 1618 20-25 150 KOA1''''1'. 'iV17,7,57 ,,e1 :4:':1 ,*0,„ (i I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff :,' (current) kikSF -- ,...:41.dr :.W.:50.,,:ki': 1 I I 9 4 ,,,,, Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type r:Ik to 1; to i . ;'.. to ,.,.„ 'et ,,, to I to r A to :*6 to ., i to - A? t .,;, to o ,,, •,.4. 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; .;,.., -1i BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I :-' 24 hr Recap: Change swivel pack. RIH and tag plug, circulate bottoms up, casing test to 3500 psi, no good. Tag up at 9682' and drill to shoe. Begin displacing with new mud. ki 40 1 1 ! u 01 el !---, -. I '. Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air t ; '''' V/ ;3 ,,,,,,,, .,., ''''''Ts:::' 'r ''*',4,4-‘ - :: 7 1:::"'l ' 1' ' '.':4:.'4r-..4--•\: \ 11 1 1 1 s„ Customer: Pioneer Natural Res. Report #: 57 I HALLIBURTON Well: ODSK -33pb1 Date: 04/14/2008 -5:00 Area: Oooguruk 05:00 Depth 9828 Location: North Slope Progress 24 hrs: 20 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK -AM- 0005556601 Report For: Jeff /Rod :' Daily Charges $3,500.00 Total Charges $186,000.00 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 90.0 217.0 9817 Flow in ..m) 0 SPP .si) 0 1 \' Gas (units) 0 15 153 9827 Flow Rate (s•m) 0 Gallons /stroke 3.6 it, Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec./qt) (cc /30 min) cP (Ib /1008 (mg /I) (Ibs /bbl) (Pm) % 6 I _ 9828 10.5 10.5 48 11 22 66,000 -- 8.0 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 13 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7 -10 80 0- 0- NO- A- X- I -NO -HP itiO Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I w (current) ------ - - - - -- \ A I Gas Breakdown 4 Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 0 • 9808 to 9828 153 15 19275 987 485 153 97 BG , ✓ to to j to to o to to I to t0 to Gas Type abreviations: BG Background Gas; GP - Gas Peak; CG Connection Gas; WTG -Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I 24 hr Recap: Drill out landing collar, no cement below.finished displacing new mud to hole, and then into pits. Drill to 9828' P to perform LOT. Good Test ( 10.5 ppg MW= 13.8 ppg EMW, 0.6# from LOT #1). POOH to lay down BHA and pick up RTTS '\ valve. RIH with RTTS valve to re -test casing. II y 0 I A ti Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air re Iftu , .d ''''W r . ' ' \\ :'tea .. `'� , • 1 Customer: Pioneer Natural Res. Report #: 58 ei Well: ODSK -33pb1 Date: 04/15/2008 -5:00 Area: Oooguruk 05:00 Depth 9828 L ocation: North Slope Progress 24 hrs: 0 • Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK -AM- 0005556601 Report For: Jeff/Rod Daily Charges $3,500.00 Total Charges $189,500.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 - Flow in (..m) 0 SPP (psi 0 111 f Gas (units) 0 145 774 - Flow Rate (spm) 0 Gallons /stroke 3.6 Y )X - � 7\ Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg /I) (Ibs /bbl) (Pm) % \ 9828 10 5 10.5 60 10 20 66,000 -- 8.0 \•: BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB R C ondition , 13 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7 -10 80 0- 0- NO- A- x -I -NO HP Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 1 (cu rrent) ----- _ - - - - -- 7 ' Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 7669 to 7669 774 145 72686 4242 2098 1228 511 GP 1� to to to to '' t0 to P to I to to to I • Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas I f 24 hr Recap: Set RTTS tool at 9650' and test casing to 3500 psi. Test was good. Pump slug and POOH. kii Pick up BHA and RIH, filling pipe every 25bbls. Working on saver sub on. ( Gas peaks of about 700 to 800 units everytime pipe is filled) fr is I ,:,: Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air Al 1 Customer: Pioneer Natural Res. Report #: 59 j. Well: ODSK-33pb1 Date: 04/19/2008-5:00 Area: Oooguruk 05:00 Depth 9967 iilLt Location: North Slope Progress 24 hrs: 0 Sperry drilling Services Rig: Nabors 19AC Rig Activity: Circulating 4 I i Job No.: AK -AM- 0005556601 Report For: Jim /Herb Daily Charges $3,500.00 Total Charges $193,000.00 I j- ..< >%/ . ‘. ,,;v,�\ A1 rr. r *i - F- dim„ ao\ , -, :irii :: r:1 }N ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: N . R.O.P. (ft/hr) 0.0 90.0 137.0 9960 Flow in (.pm) 156 SPP (psi) 900 Gas (units) 311 120 1228 9849 Flow Rate (spm) 44 Gallons /stroke 3.6 it Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids ga /, Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) I 9967 10 1 10.1 40 9 19 66,000 -- 6.8 s� Ilik / �@ P,i•\\_. \ •,..\ ,.. ..a., j I.`..: ;,f . °, \.:. \ . . & u4:12it •k\ o : Iii BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ' \ 1 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7 80 0 - 0 - NO - X I NO - ... �M .,, ; VAk r�� ��. .�:.• /% . .., - -- . � ; we .�.:. /i'i. 7ki •.��\ �`, .,•.: • •':?.� � �s -�. I 6 '' .: , Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff ; (current) 95 - - -- - - - - - • ,; ter. ' Gas Breakdown ` Gas (units) Chromatograph (ppm) 4 . Depth Max Average 01 C2 C3 C4 Tot C5 Tot Type 9828 to 9849 1228 120 113456 5124 2601 1285 621 BG j., I • 9849 to 9967 712 83 72456 3965 1134 986 511 BG y„ to iii to ', I to to to to , II I to to i to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; . p BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas 24 hr Recap: RIH with BHA and shallow pulse test MWD. Good test. Continue RIH,.trouble shot geospan, adjust choke size. 4 % 1 ', "' , : ::'' ' ' ' 1 \ „ up and watch \ Got to bottom and began driling. Started taking losses at around 9847' at a rate of 120 bbl /hr. Pull d for losses, then went back to drilling. Continued to take losses at approx. 120 bbl /hr. Pulled up off bottom, added 660 bbls of new mud and pumped 3 high vis lost circulation pills. Currently mixing new mud, and trying to correct hole conditions A ' Logging Engineer: Colby Marks / Eugene Payne * ` 10000 units = 100% Gas In Air \ ii 1 P v Customer: Pioneer Natural Res. Report #: 60 I HALU8URTON Well: ODSK -33pb1 Date: 04/17/2008 -5:00 :4 HALLIBURTON Area: Oooguruk 05:00 Depth 10448 Location: North Slope Progress 24 hrs: 481' Sperry Drilling Services Rig: Na bors 19AC Rig Activity: RI W /Plu I p � g 9� g Y� g /:.' Job No.: AK -AM- 0005556601 Report For: Jim /Jeff , Daily Charges $3,500.00 Total Charges $193,000.00 11111 .41 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: \ y R.O.P. (ft/hr) 0.0 90.0 137.0 9960 Flow in (gpm) 156 SPP (psi) 900 s Gas (units) 311 175 1143 10350 Flow Rate (spm) 44 Gallons /stroke 3.6 lig Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids IP Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) I 10448 9.9 9.9 44 9 18 66,000 _- 5.9 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 13 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7 80 0 - 0 - NO - X I NO - HP O I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ ; (current) 95 - - -- 5 - - - - -- ,. „ . ��.. // \ rill % a a / e \ s::r /. \ \ \ \\ \ Ok I Gas (units) Gas Breakdown 6 Chromatograph (ppm) Depth Max Average 01 C2 C3 C4 Tot C5 Tot Type 9967 to 10100 1175 710 112555 6761 3337 1704 580 CG I 10100 to 10200 1119 295 102240 6798 3504 1906 724 BG 10200 to 10300 940 355 84073 5652 3109 1772 695 CG 10300 to 10448 1142 248 103685 6625 3672 2078 831 BG 1 to to to to to ,11',1:L,,I'llrA11,1111''11:141I'Ll'il'i: to Q Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; \ p P gas; Trip BUG Bottoms Up Gas: POG pumps off asTG Tn Gas a r C fe (® / \ r /a 0 7 % I* I 24 hr Recap: Drilled from 9967- 10448' with a pump rate of 230 gpm. Contiued to take losses at a rate of about 80 -100 bbl /hr ., while pumping and 5 -10 bbl /hr while static. Lost circulation, spotted pill and pulled up into casing shoe. Mixed MI Forma- Squeeze plug (40 bbl), pumped it down hole in an attempt to heal the hole. , 1 31r 1 !iiii : At Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air 'r :;iii // it l > \ \\ to 1 1 s �� � acs 7 �� fi ...K. , r �. , :t7. , :;.,��� 'x ,,, �� � �. ... <,,, g... r,,,,, '�c¢ ... \�,,,, , ... �� < . ..... , r , , ,� , Customer: Pioneer Natural Res. Report #: 61 r/ I PI HALLIBURTON Well: ODSK -33pb1 Date: 04/18/2008 -5:00 Area: Oooguruk 05:00 Depth 10448 0 Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH j 1 M Job No.: AK -AM- 0005556601 Report For: Jim /Jeff Daily Charges $3,500.00 Total Charges $200,000.00 di ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) - SPP (psi) Gas (units) 0 - -, Flow Rate (spm) , Gallons /stroke 3.6 1 ��% i�� \\ ' ° \ \\\\ � a, ., ✓i _�% „` »�i O\\.. r \� \... ' ' ��;, . L\. \�:' - `... -;� cr' ': lUi , � \\ .. , „ . €.. / Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib/100ft (mg /I) (Ibs /bbl) (Pm) % 10448 10.5 10.5 47 11 19 66,000 _- 8.0 ;j BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 13 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7-10 80 0 0 NO A X I -NO HP 0d Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ------- - - - - - (current) 11111111111111, A Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average 01 C2 C3 C4 Tot C5 Tot Type to 1 to to : to to \,,, I to to to to I to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; Ali BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas r I a 24 hr Recap: Pumped 40bbI of Forma Plug. Pull 9298' and attempt to circulate, no circulation. Rotate out of hole to minimize iir swabbing. Attempted to circulate again, pressured up to 4500 psi. Monitored well and gained 4 bbl. Rotate and work pipe, inject 150 bbl of 10.5 mud down backside. Losing mud at 4 bbl per hr. Monitoring well every stand. Hole fill on entire time. 249 bbl loss in the past 24 hr. Still POOH li 1. k 1 Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air o 1 1 1 Customer: Pioneer Natural Res. Report #: 62 I Well: ODSK-33pb1 Date: 04/19/2008 -5:00 wl Area: Oooguruk 05:00 Dep th 10448 Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH 1 op Job No.: AK-AM-0005556601 Report For: Jim /Jeff 1. Daily Charges $3,500.00 Total Charges $203,500.00 , II \ �/ �� \�� �,� i/ 'iii \.- \ � i \\ \ \.. �� •,., � � ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: ° R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (..m) SPP (psi) - Gas (units) 0 - -- w Rate (spm s ) - allon Flow stroke 3 6 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec/ qt) cc /30 min) cP ib /100ft (mg/I Ibs/bbl) (Pm % I 10448 10.5 10.5 45 9 19 55,000 -- 8.3 / .. \ \ \ \� % �r , / i ,; r w : F ;Az \<. �� i i t � i ,,A\ \ s ,, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 13 FMF3543zz 6.125 0.464 0.6 9808 9828 20 7 - 80 0 0 NO A X i NO HP t Si,,., , .. ; % ... � «« Z • tea : , i,. � <... ':��� �. .'. i t a.. ql\ \� ill Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ kge (current) \ -- - - - - -- , I Gas Breakdown is Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to dill to , to '› to to to \' to ke 1 j ' to to - 1111 I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 24 hr Recap: Continued POOH. Began pulling singles, due to the fact that the drillstring was was filled with Forma -Plug to Oi reduce the swabbing effect. Total losses for the past 24 hr is approximately 300 bbl. Presently laying down BHA I d 1 f Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air :�..c,.._,.�/�L r�� \\s V_. �� _. /N.c�. <, s, y`� ........ � x «,. 3r,_ ��_ ___. :,. \�4�,a�... t.';040.70.11,0 s..�. d.. �4. y,F'�, 1 if ilimij 1 1 k Customer: Pioneer Natural Res. Report #: 6 3 Well: ODSK -33pb1 Date: 04/20/2008 -5:00 f Pi HALLIBURTON I I. Oooguruk 05:00 Depth 10448 ,,,! Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH I \ Job No.: AK-AM-0005556601 Report For: Jim /Jeff D aily Charges $3,500.00 Total Charges $207,000.00 y N \ \\ F \�\ ° jay!„1 \ \� I \ O4 /777 ! ,,,,, .4* , , . � `:. ,,fix ffil ROP &Gas. Current Avg 24 hr Max Max @ ft Pump & Flow Data: r"; R.O.P. (ft/hr) 0.0 0.0 0.0 0 Flow in (gpm) SPP (psi) ri Gas (units) 0 300 3530 1024 Flow Rate (spm Gallons /stroke 3.6 I ' Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc /30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) 10448 10.0 100 44 11 16 54000 8 \ r �,. . \i` �*6, c� �� h am ;: Adi�,v 41,L&. tt. .: :. �>' 6 .� BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition IP 13 FMF3543zz 6 125 0 464 0 6 9808 9828 20 10 80 0 0 NO A X I HP i ,` \\ rfe, : o f \ , \D �' > \\ - i t o\ r ' ; & / ,.,,,,,,,,,,,:7 rs rr ��. \\ \ Q� r NO , 4 i , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) � El % r ,.... %fin sL , : \ .r / r , z„ , ., //, ,7 .. �. Wt „, r, .:A:,mnv, .. .. ..•a�\ .. , ,6 I Gas Breakdown G as (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type fi to I to to 4 to to 41 to ' 0"' to to I Pe to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; il4 BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas o ci s 7s l - r � .." # "i �� _ ir. ���� y- w*, E a� ` //i I ` r �� \•. �' �yir,' �� `�i /i /r. � - ,s ' , \� \oCO t _. •. \\� �li - GEC\ ;�%J\`rir '. 24 hr Recap: Lay down BHA. Pick up new BHA. Test BOP. RIH with new BHA to drill to TD. i ii:w El I me 1 • 110 79 Or ill Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air 0 10 U:y 01 00 o...J.,,,,/ 4,;A ..z:.A00ti ..74C4; L 1 • i Q'rr 400 y,,.�jl„rT%ie.( \r.., v '` 4,4 ii II I I .pt...,tv.zs"-a,:....:;owa7racvmca:..c.n.mLAEsmaimmrvaauoimpnmp.m.n.snmzmis.,..:..7E Customer: Pioneer Natural Res. Report #: 64 PA ..,.. 3 1 HALLIBURTON Well: ODSK-33pb1 Date: 04/21/2008-5:00 . A0: • • Area: Oooguruk 05:00 Depth 11331' il Location: North Slope Progress 24 hrs: 883° 1 t. Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Jim/Jeff if I i$:Z Job No.: AK-AM-0005556601 Report For: w.4 SI Daily Charges $3,500.00 Total Charges $210,500.00 's I t)Volptillifq.aplipl.47C-41W110.1•111111111,1"enimmintionismotiffig • ,t1: ROP&Gas: • Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 98.0 419.0 10498 Flow in (. pm 215 SPP (psi) 1698 14 : 1 , 1 1 1 ri .; 1 1 : 11 1 '' ::i 1 11 1 11,1 1 1 1 l io l li1 : 1 I p Gas (units) .... . .21 ........... 30 .................... 7107' Flow Rate . 58 .. Gallons/stro . ke . ..... .3.6 AjAkiVIIIAANIEIIMMIglippilinVgKiialliig011EMPAiittaligifek:UNNOMMISEEr ,,,aipt,107A1mulef.lapfifArtion Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I . m !I 0 Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (Ibs/bbl) (Pm) % rf 10448 10.0 10 . ..... 44 ........... .. 11 18 58,000 6.5 hAvolgrodose, lammo mmg.effolaromistomNwownstimi. , :rvsb:,NI:40N ,.. .sgm.,,:,.,AN:; . , 41 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I Fio . 16 FMF3641 6.125 .331 9.1 10448' 883' 10-15 130 :4 J.. .. . loirJ7.?..lt W;7ITAtliig•giliglIllitIVJIBNPIIISEIBSIIIII.XnlgifgfgilltiriljnlrgluNgntllIlaIIVWTZZt:: o tei I 0 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal . Gvl Tuff He (current) ilir.7!ir,M10, I Gas Breakdown 1 Gas (units) Chromatograph (ppm) 10 40 Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type nO WV i !.,. to V IY' Ir:,,' to %11 to _ ip 4 Fqi in 4 to :•,‘ to II 111! to to _ I r' „...., _ l to ' to 1r I if Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; pi :k. BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 7:, * im lltit11111ManiiirlikiiiiiiMrat.32K111111111111111 1 24 e hr Recap: Continued RIH to 3322, stop to circulate gas out, did the same at 7180' and 9787'. Continued RIH to 9817' r) • from there reamed down to 10448'. Began drilling ahead, 100% losses,no returns. Pumped high vis pill at 10559', no change I in returns. Began drilling with sea water at 10895'. Drilling ahead with 100% losses. Monitoring pits and flowline for any variances I that would indicate a kick or other well control problems. Low gas reading and no samples because of 100% losses. VI: §1111 ill ;4 Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air 4 I hismosk\ommens imksmr,.....Nammmat I I ::' ;0:1S1::' ilitYrIt:iNiN:efirk4it:. 4Aiiiii:i :..i:V '.,.4Pn!,A;.1Q Customer: Pioneer Natural Res. Report #: 65 oilil III p HALLIBURION Well: ODSK-33pb1 Date: 04/22/2008-5:00 ' 1 4' Area: Oooguruk 05:00 Depth 10789 Location: North Slope Progress 24 hrs: 724' „,...., • !V Sperry Drilling Services Rig: Nabors 19AC Rig Activity: 111 A Job No.: AK-AM-0005556601 Report For: Drilling Jim/Jeff II , z ': Daily Charges $3,500.00 Total Charges $214,000.00 • tilitiell. ih : ''? f ':; : el*:* , :'jl 6 lill:' , t , •,,r'C'Z'r''',''''''aSA' , ,:f,ISZA - "Itio:',"*%''',:irrt1511tifz 4';''t3 • ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 2.0 51.6 213.0 11375' Flow in (gpm) 213 SPP (psi) 1759 AM II Gas (units) 4 5 16 11835' Flow Rate (spm) 60 Gallons/stroke 3.6 ,NlidAlik',7%,:i]':::Si: A')Wk,',:,,iY,_?„„`V74 Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids w I Depth in out (sec/qt) (cc/30 min) cP (Ib/100ft (mg/I) (lbs/bbl) (Pm) % 4 11765 10.0 10.0 44 11 20 60,000 6.3 iiL.Ni /t 7170''',,','''MO:0;,','77:,,*4 ',,,k...,,,,r,,,,,xitiimr4Iiiclem„.7', BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 16 FMF3641 6.125 .331 23.5 10448 10-15 130 ,!!! !!4.z7!; .t4 - ';i: ;. t,,a:;7Mi,;:7:ki , A4SA:*414' - ',AA:akA(''Vi;;iiii:if7:: ,I , , , ;, I ' , Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff .,.4 • (current) kr ‘';i' 0' a;7'C&r.,.:14.fft.'V 11111PNIV:WV ',A;t'IMIC:11111e* I Gas Breakdown z Gas (units) Chromatograph (ppm) l' Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type Er to I to *1 _ .,. I to .. to ,...,. .5 to to 1 i to to to I 0 /S Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; - BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas '74 . , I :,- 24 hr Recap: Drilled ahead to 12,055'. POOH due to possible deflection away from target. Side tracked and kicked off from 10,780'. Time drill the next 13'. At approx. 10,783, MWD tools quit pulsing. P/U off bottom, decided to drill blind. Currently :-. co ntrol drilling at 10,790'. Still using sea water down drill pipe and 10 ppg mud down backside. Watching for any changes in con ng ahead pit for early detection signs of well-control issues. ,,,•;. — • Al0,1 ti I ig Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air r • aglwiN7C3::i:;;:7!!'ki 1 I I fi, rZE'\\� \ \\ Ni 7� "�� ",. rtit , itn ., j ,,;.; aVf:,'; 4;' \a �y1 x,,�� , \ Customer: Pioneer Natural Res. Report #: 66 I HALLIBURTON Well: ODSK 33pb1 Date: 04/23/2008 -5:00 Area: Oooguruk 05:00 Depth 10823 k Location: North Slope Progress 24 hrs: 34 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling '\ Job No.: AK -AM- 0005556601 Report For: Jim/Jeff is Charges $3,500.00 Total Charges $217,500.00 I \ \. ��u _ . .* ... �� \ \ r, �� �'�� o., :,a . ;yam :�� �s� a.` ... v4,•kk \\\ \\� ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. (ft/hr) 0.0 7.5 -- Flow in (..m) 211 SPP (psi) 1205 di i Gas (units) 151 20 1660 2931 Flow Rate (s.m) 60 Gallons /stroke 3 6 / Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids I A Depth in out (sec/qt) (cc /30 min) cP (Ib/100ft (mg /I) (lbs/bbl) (Pm) 5800 10.0 10.0 44 11 20 60,000 6.3 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 16 FMF3641 6.125 .331 28.3 10448' -- 10-15 130 :: ///Tip \ / J ;; ;' // ,,. F / 714 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ Is (current) ------- - - -_ -\ mi I Gas (units) Gas Breakdown AA Chromatograph (ppm) Fr Depth Max Average Cl C2 C3 C4 Tot C5 Tot Type 2931 to 2931 1660 330 66362 12040 10078 7260 3210 BUG E. to ,, ,_ to I A to to ' to to • to to it to it I i Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; Ilk BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas ph 7C1 xdAGr,,:•, 7: r .,r ,,,\i -.i , , , t.. tt.:Z . ,.,oi,.:_ ...;.: ,\ ..kw 1 an,-'�'r,�rr�`Jr9ig•. 24 hr Recap: Continued time drilling until the decision was made to POOH due to the fact that the bit enter back into old hole. Displaced with 110 bbl of 10 ppg mud. Pump out of hole with 100% losses. At 2939', started getting returns and an -- increased amount of gas, stopped and circulated BU about 2.5 times. Currently swapping to 10.5 ppg mud. �. I '/: , / I Logging Engineer: Colby Marks / Eugene Payne * 10000 units = 100% Gas In Air s o 1 1 1 1 Customer: Pioneer Natural Res. Report #: 67 I HALLIBURTON Well: ODSK -33pb1 Date: 04/24/2008 -5:00 Area: Oooguruk 05:00 Depth 10823 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH 1 \ Job No.: AK -AM- 0005556601 Report For: Jitn/Jeff Daily Charges $3,500.00 Total Charges $221,000.00 , / ` A . ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: , ; R.O.P. (ft/hr) - - -- Flow in (gpm) - SPP (psi - 1 Gas (units) z - 4 30 - Flow Rate (7m) - Gallons /stroke 3 6 \ Mud Data: Density (ppg) Viscosity HTHP PV YP Chlorides Lime Alkal Md Cor Solids Depth in out (sec /qt) (cc/30 min) cP (Ib /100ft (mg /I) (Ibs /bbl) (Pm) % I 5800 10.0 10.0 44 11 20 60,000 -- 6.3 �// ,, y BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 16 FMF3641 6.125 .331 28.3 10448' -- 10 -15 130 4'0 oo/ I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff -\ `S (current) ------- - -_ - - e I ''',,i;:. A Gas Breakdown G as (units) Chromatograph (ppm) Depth M ax Average C1 C2 C3 C4 Tot C5 Tot Type 4 I to ' to i$ to to I to to t0 � to ." to j t0 , t0 t0 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; r BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 / 24 hr Recap: Contiued POOH. Circulate and condition, montioring well every 1000' for 15 minutes. While tripping and ' laying down BHA, well flowed back, shut in well and pumped 50 bbls of 11 ppg mud. Finished laying down BHA, and DP. gi Cut and slip drill line. RIH for scraper run. vi I 1 L Engineer. Colby Marks /Eugene Payne * 10000 units = 100% Gas In Air 'may= , ,. . 1 1 I MII • • MI - M = • ■I■ M■ am e• EN e• mil I me NE w HALLI U RTO N WELL NAME: ODSK -33PB1 and ODSK -33 LOCATION: Oooguruk OPERATOR: Pioneer Natural Resources AREA: Noth Slope CONTRACTOR: Nabors 19AC STATE: Alaska Sperry Drilling Services PIONEER BIT RECORD BHA Bit Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM PUMP PUMP Bit Grade Remarks # # Type Size IN OUT Hours ROP Press GPM Oooguruk ODSK -33PB1 1 1 Hughes MXL -1 12.25 153 3183 3030 23.62 0.699 12 8.3 5 -25 40 -80 3150 700 3- 2- BT- A- E- 1 -WT -TD Spud Well @ 53' and Drill Surface Hole to TD 2 2 SEC DBS FSF2463Z 8.75 3183 3183 0 0.00 0.863 0- 0- NO- A- X- 1 -NO -HP Drill float & cmt to 3161', failed csg test 3 RTTS Packer 3183 3183 Run RTTS packer to test 9 518" casing 4 2rr1 SEC DBS FSF2463Z 8.75 3183 8491 5308 51.44 0.863 10 3.2 3 -20 80 -140 4200 600 4- 2- BT- C- X -I -ER -DTF Stuck in hole 5 3 SEC DBS FSF2565Z 8.75 8491 9730 1239 42.52 0.982 29.1 12 -21 140 -151 4600 550 5- 7- BT- A- X- 1 -JD -TD TD Section 6 4 SEC DBS FM3655Z 8.75 9730 9730 0 0.00 1.116 - - - LI -H - - Clean out run Left in hole 7 Fishing assembly 9730 9730 Attempt to fish BHA, but severed at 6920' Oooguruk ODSK - Set cement plug at 6920' 8 5 Hughes HCM506Z 8.75 6527 8190 1663 54.84 0.778 30.3 2 -15 80 -100 4600 500 0- 1- WT- G- X -0 -ER -BHA Kick -off cmt plug at 6527' • 9 6 SEC DBS FMF3653R 8.75 8190 9808 1618 56.60 1.035 28.6 15 - 25 150 4000 515 1 - 1 - HC G - X - 1 - NO - TD TD 8 3/4" Hole; lost 2026' DP & BHA in hole 10 Fishing assembly Pulled fish out 45' before grape) detached 11 Fishing assembly Successfully retreived fish from 4163' 12 5rr1 Hughes HCM506Z 8.75 9808 9808 0 0.00 1.178 - - -- 0 130 4550 500 1- 1- CT- G- X- 1 -ER -TD Clean out run prior to running 7" casing 13 7 SEC DBS FMF35443ZZ 6.13 9808 9828 20 0.55 0.464 36.4 12 80 2100 250 0- 0- NO- A- X- 1 -NO -HP Failed Casing Test. Drill 20' for LOT. POOH. 14 RTTS Packer RIH to test for leaks in 9-5/8" casing 15 7rr1 SEC DBS FMF35443ZZ 6.13 9828 10448 620 8.48 0.464 73.1 5 -12 8o 2200 270 0- 0- PN- A- X- 1 -NO -HP Problems with GeoPilot & lost circ 16 8 SEC DBS FMF 3641 6.13 10448 12055 1607 17.13 0.331 93.8 4 - 14 130 1750 210 6- 3- BT- A- X -I -WT -DTF TD ODSK - 33 (TIME CONSTRAINTS) 17 Attempted sidetrack with BHA 16 from 10780' to 10815' Side track failed POOH call 12055' TD 18 9n1 Hughes XR2 6.13 9700.0 9700.0 2.3560 2- 2- WT- A- 0- I -NO -TD Scraper run MO NM MI MN - - O - - - - NM • ' - - - i HALLIBURTON Company: Pioneer Natural Res. Area North Slope, Alaska Casing Record Sperry Drilling Services Well ODSK -33PB1 Job No: AK -AM- 005556601 16" Conductor @ 153.0' Rig Nabors 19AC Spud Date 18 Feb 2008 9 5/8" Surface @ 3172.00 Water -based Mud Record Mud Co Baroid TD Date: 21 Mar 2008 Date Depth Wt Vis PV YP Gels Filt R600 /R300 Cake Solids Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft - MD ppg sec lb /100 lb /100ft` m /30m 32nds % % % ppm(k) Ca ++ 18 -Feb 200 8.90 120 20 50 23/25/- 20.0 90/70 4/- 2.2 96.0 0.00 0.10 8.5 2.0 0.05/0.4 32.0 1200 Move rig/ spud 19 -Feb 1784 9.30 70 16 42 21/24/- 12.5 74/58 4/- 5.2 93.3 2.00 0.10 8.5 8.0 0.05/0.70 34.0 1200 Drill from 200' -1800' 20 -Feb 3183 9.50 66 17 37 24/36/- 12.0 71/54 4/- 6.2 92.0 2.00 0.10 8.0 15.0 0.05/0.70 34.0 1200 TD at 3183' 21 -Feb 3183 9.50 60 16 35 19/30/- 12.0 67/51 4/- 5.2 93.0 2.00 0.10 8.0 15.0 0.05/0.70 34.0 1200 Run 9 5/8" casing 22 -Feb 3183 9.70 46 13 23 10/18/23 12.0 49/36 4/- 5.2 93.0 2.00 0.70 8.0 18.0 0.05/0.70 34.0 1200 Cement casing & Nipple up 23 -Feb 3183 9.60 46 13 23 10/18/23 12.0 49/36 4/- 6.2 92.0 2.00 0.10 8.0 18.0 0.05/0.70 34.0 1200 Test BOP's 24 -Feb 3183 8.90 45 10 14 7/08/11 4.6 34/24 2/- 2.1 96.0 0.80 8.0 0.04/3.20 34.0 1200 RIH; Drill float & cement; POOH 25 -Feb 3183 8.90 44 9 15 5/07/11 4.5 33/24 2/- 2.1 96.0 0.80 8.5 0.04/3.20 34.0 1200 RIH packer; test csg; POOH; RIH 26 -Feb 4800 9.20 50 16 24 6/8/- 4.5 36/27 2/- 2.1 96.0 0.50 8.6 4.0 0.06/1.40 34.0 1400 Drill out of shoe, Drill 8 3/4" Section 27 -Feb 6500 9.30 47 12 23 9/15/20 7.0 47.0/35.0 2/- 5.0 93.0 0.30 8.3 16.0 0.06/1.70 34.0 1400 drilled to 6500' 28 -Feb 8020 9.60 47 12 21 8/17/20 8.0 45.0/33.0 2/- 7.2 91.0 8.5 17.5 0.05/1.25 34.0 1380 drilled to 8020 29 -Feb 8194 10.60 50 17 26 14/28/34 8.0 60.0/43.0 2/- 10.3 86.0 0.10 1.50 8.5 18.0 0.05/1.30 34.0 1380 drilled to 8194 packed off 1 -Mar 8194 10.70 50 15 25 12/24/30 8.0 55/40 2/- 11.4 85.0 0.10 0.50 8.5 20.0 0.05/2.00 34.0 1380 Tool failure, POOH to replace BHA 2 -Mar 8194 10.60 55 17 27 15/21/23 8.0 61/44 2/- 10.8 85.5 0.10 8.3 20.0 -/2.50 34.0 1380 Test BOP's, cut/slip, RIH, Drill 3 -Mar 9029 10.70 55 14 30 19/27/36 9.0 58/44 2/- 11.4 85.0 0.10 8.3 20.5 -/2.30 34.0 1380 Finish RIH, Ream to 8491, Drill 4 -Mar 9471 11.00 52 18 30 22/32/36 9.5 66/48 3/- 11.4 85.1 0.10 8.1 20.0 -/2.10 32.0 1280 Drilling 5 -Mar 9730 11.00 47 9 24 19/29/- 12.0 42/33 3/- 12.5 84.0 0.10 7.8 20.0 -/1.25 32.0 1480 TD at 9730 6 -Mar 9730 11.00 55 13 22 19/26/29 12.5 48/35 3/- 12.5 84.1 0.25 7.9 21.0 -/1.35 32.0 1480 POOH 7 -Mar 9730 11.00 55 13 25 24/31/35 12.5 51/38 3/- 12.5 84.2 0.25 8.1 22.0 -/1.35 32.0 1480 POOH 8 -Mar 9730 11.00 46 15 21 18/24/- 12.5 51/36 3/- 12.5 84.1 0.25 8.0 22.0 -/1.35 32.0 1480 POOH 9 -Mar 9730 11.00 45 10 20 16/19/- 12.5 40/30 3/- 12.5 84.0 0.25 8.0 24.0 -/1.35 32.0 1480 RIH Reaming 10 -Mar 9730 11.50 55 23 24 12/24/30 5.6 70/47 2/- 12.5 84.1 0.25 0.20 8.1 12.5 0.10/0.30 32.0 1360 RIH Reaming 11 -Mar 9730 12.00 48 23 24 20/35/37 4.2 70/47 2/3 15.5 84.2 0.25 0.02 8.3 15.0 0.03/1.90 32.0 600 RIH Reaming 12 -Mar 9730 12.50 50 26 22 19/33/- 8.0 74/48 2/- 18.3 84.3 0.25 0.10 8.4 18.0 0.10/3.00 38.0 1350 RIH Reaming 13 -Mar 9730 12.50 48 17 23 20/41/- 8.0 57/40 3/- 18.3 84.4 0.25 0.10 8.2 0.3 0.15/3.30 38.0 1400 Reaming 14 -Mar 9730 12.50 54 27 27 11/16/19 5.2 81/54 2/4 16.5 80.1 0.25 0.20 8.8 12.0 0.07/2.00 33.0 1120 POOH 15 -Mar 9730 12.50 53 93 23 9/14/- 6.0 81/21 2/3 16.5 80.2 0.20 8.6 12.0 0.10/3.00 33.0 1120 POOH, test BOP, fishing 16 -Mar 9730 12.50 60 32 34 10/16/- 5.0 98/66 2/3 16.5 80.0 0.20 8.6 13.0 0.10/2.30 34.0 1140 Fishing 17 -Mar 9730 12.50 58 30 27 9/14/- 4.8 87/57 2/3 16.5 80.1 0.10 8.6 13.0 0.05/2.60 34.0 1200 Working tight section 18 -Mar 9730 12.10 65 32 31 9/15/- 4.0 95/63 2/3 15.5 80.2 0.20 8.2 13.0 0.05/2.20 34.0 1200 Working tight section 19 -Mar 9730 12.20 69 32 30 9/17/- 3.8 94/62 2/3 15.6 73.0 0.20 8.3 13.0 0.50/2.50 34.0 1200 Working tight section 20 -Mar 9730 12.10 65 28 25 9/15/- 3.8 81/53 2/3 15.6 73.1 0.20 8.0 12.0 0.50/2.50 34.0 1200 POOH 21 -Mar 9730 12.20 70 12 25 7/15/18 3.7 49/37 2/3 15.6 73.2 0.20 8.5 13.0 0.05/3.50 34.0 1160 Plug back I MI 1 MI MN • M - = r- MI • s- S MN - HALLIBURTON Company: Pioneer Natural Res. Area North Slope, Alaska Casino Record Sperry Drilling Services Well ODSK -33 Job No: AK -AM- 005556601 16" Conductor @ 153.0' Rig Nabors 19AC Spud Date 18 Feb 2008 9 5/8" Surface @ 3172.7' Water -based Mud Record Mud Co Baroid TD Date: 21 Apr 2008 7 " Intermediate @ 9793.4' Date Depth Wt Vis PV YP Gels Filt R600 /R300 Cake Solids Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft - MD ppg sec lb /100 lb /100ft1 m /30m 32nds % % % ppm(k) Ca ++ 22 -Mar 6920 12.10 54 25 24 10/15/- 3.8 74/49 2/3 15.6 73.3 0.20 8.8 13.0 0.05/3.30 34.0 1160 RIH to Kick Off 23 -Mar 7020 12.20 70 32 26 15/22/- 6.0 73/48 2/3 15.6 70.0 0.20 8.9 16.0 0.05/3.80 32.0 1200 Drilling 24 -Mar 7565 12.20 65 30 25 14/42/- 5.2 85/55 2/3 15.6 70.1 0.20 9.0 16.2 0.05/2.75 34.0 1200 Drilling 25 -Mar 7939 12.20 60 30 25 7/9/- 4.8 85/55 2/3 14.5 70.2 0.20 8.8 14.2 0.05/3.00 34.0 1600 Drilling 26 -Mar 8190 12.10 62 19 28 13/31/42 4.5 66/47 2/3 14.5 76.0 0.05 8.8 16.2 0.05/2.10 34.0 1520 Finish Drilling /POOH 27 -Mar 8190 12.20 58 29 26 15/40/- 4.0 84/55 2/3 16.4 74.0 0.40 9.3 18.0 0.07/2.30 34.0 1620 POOH /Rig maintenance /RIH 28 -Mar 8617 12.60 53 22 27 14/28/36 4.8 71/49 2/3 16.2 77.3 8.5 11.2 0.05/2.30 34.0 1480 Drilling 29 -Mar 9271 12.50 57 25 35 29/40/49 6.3 85/60 3/3 16.0 77.5 8.4 15.3 -/2.40 34.0 640 Drilling 30 -Mar 9718 12.50 52 20 35 29/40/50 7.1 75/55 3/- 17.2 76.0 8.0 16.4 -/2.70 34.0 800 Drilling 31 -Mar 9808 12.50 47 23 26 13/26/29 5.5 72/49 3/- 15.5 78.0 8.1 11.5 -/2.30 34.0 1360 POOH 1 -Apr 9808 12.50 38 14 15 10/19/24 9.1 43/29 2/- 15.5 - 78.0 8.6 15.0 -/2.40 34.0 1400 POOH 2 -Apr 9808 12.50 46 20 24 19/31/35 7.5 64/44 3/- 17.6 76.0 8.5 15.0 -/3.40 33.0 1400 Service Rig 3 -Apr 9808 12.50 53 16 24 20/34/36 10.6 56/40 3/- 18.1 76.5 8.3 16.0 -/3.60 32.0 800 UD BHA 4 -Apr 9808 12.50 53 16 24 20/34/37 11.6 56/41 3/- 19.1 76.6 8.3 16.0 -/3.70 32.0 800 5 -Apr 9808 12.50 62 19 26 18/45/- 8.4 64/45 3/- 18.0 76.6 0.05 8.5 15.0 0.03/3.70 34.0 880 POOH 6 -Apr 9808 12.50 61 21 38 27/43/- 10.6 80/59 3/- 19.5 76.0 0.25 0.10 8.5 18.0 0.05/3.50 34.0 1100 RIH ream /wash 7 -Apr 9808 12.50 62 22 26 15/31/- 4.6 70/48 2/- 15.5 77.0 0.05 8.2 10.0 -/2.30 34.0 560 POOH /Dilution 8 -Apr 9808 12.50 60 28 31 25/36/41 5.4 87/59 2/- 17.5 75.0 0.25 8.4 13.0 0.05/2.50 34.0 800 POOH/Test BOP 9 -Apr 9808 12.50 69 27 30 18/31/40 5.0 85/58 2/- 16.5 76.0 0.25 8.3 13.0 -/4.00 34.0 800 Run 7" casing 10 -Apr 9808 12.50 62 27 29 16/28/- 5.2 83/56 2/- 16.5 76.0 8.2 13.0 -/4.00 34.0 800 Test BOP/ Clean pits 11 -Apr 9808 12.50 62 27 29 16/28/- 6.2 83/57 2/- 17.5 77.0 8.2 13.0 -/5.00 34.0 800 12 -Apr 9808 11.60 48 14 12 7/13/- 6.8 40/26 2/- 13.4 81.0 0.20 9.5 0.25/4.50 34.0 1360 Displacing 13 -Apr 9828 10.50 48 11 22 7/11/- 2.6 44/33 1/- 8.0 84.0 0.20 9.5 0.10/.60 66.0 1400 Laying down BHA 14 -Apr 9828 10.50 60 10 20 7/10/- 2.6 40/30 1/- 8.0 84.0 0.20 9.4 0.10/0.50 66.0 1320 RIH 15 -Apr 9967 10.10 40 9 19 7/11/- 3.0 41/31 1/- 6.8 85.0 0.20 9.3 0.10/0.50 66.0 800 RIH. Test MWD tools 16 -Apr 10448 9.90 44 9 18 6/11/- 3.0 36/27 1/- 5.9 86.0 0.01 8.8 0.50/1.00 66.0 800 Drilled to 10448' 17 -Apr 10448 10.50 47 12 19 7/11/- 2.8 43/31 1/- 7.9 85.0 0.25 0.10 9.2 0.05/0.60 66.0 800 POOH for hole problems 18 -Apr 10448 10.50 45 9 19 7/11/- 3.0 38/27 1/- 8.3 85.5 0.25 1.00 9.0 0.07/1.00 55.0 800 POOH 19 -Apr 10448 10.00 44 9 18 7/12/- 3.2 36/27 1/- 6.7 87.0 0.40 9.0 0.20/1.00 55.0 800 POOH to lay down plugged DP 20 -Apr 11085 10.00 44 11 18 6/8/- 2.8 40/29 1/- 6.5 87.0 0.10 9.0 0.20/1.10 58.0 800 Drilling 21 -Apr 11765 10.00 44 11 20 7/9/- 2.8 42/31 1/- 6.3 87.0 0.10 8.8 0.15/0.80 60.0 640 POOH to 10780 to side track 22 -Apr 12055 10.00 44 11 20 7/9/- 3.0 42/31 1/- 6.3 87.0 0.10 0.40 9.0 0.15/1.00 60.0 640 Attempting Sidetrack @10700' 23 -Apr 12055 10.50 48 19 24 8/15/- 3.8 62/43 1/- 8.7 85.5 0.10 8.8 0.10/1.10 50.0 720 Tripping out of hole 24 -Apr 12055 10.50 48 17 23 8/14/- 4.0 57/40 1/- 6.8 87.0 0.10 8.6 0.10/1.00 54.0 800 Perform Scraper run 25 -Apr 12055 10.50 30 20 2 4.2 42/22 1/- 4.7 87.0 148.0 POOH, Test BOPs, Bullhead brine 26 -Apr 12055 10.20 38 13 14 40/27 5.0 87.0 142.0 Completions I I III: SPERRY Well Name: ODSK 33 Depth (MD) 9850 to 9875 ft IIII Location: 000GURUK (TVD) 6076 to 6078 ft II:I !!!!! DRILLING SERVICES Operator: PIONEER Show Report No. 1 IIII IIII! Show Report Report Prepared By: Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 _ I IL Report Delivered To Tavia Jackson I HO Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. I 1 I ! Formation: Sandstone- off white to light brown, clear to transparent, medium to coarse grain, angular to subangular, well sorted, 1111 predominately loose quartz grains, occasional nodular pyrite, occasional nodular glauconite, dull yellow natural fluorescence, slow pale ti pp yellow cut fluorescence. I "" I LI Hydrocarbon Ratios ft MI Depth 9849 Gas Units 1526 Mud Chlorides (1000's) , na C1 C1 C1 C1 1111 III: Flowline Background Show C2 C3 C4 C5 1111 I ppm ppm ppm Hydrocarbon Ratios 1000.0 1 0 Cl 119917 - 0 = 119917 C1/C2 = 18.8 MI C2 6377 - 0 = 6377 C1/C3 = 37.4 I 1111 C3 3209 - 0 = 3209 C1/C4 = 68.8 II!! C4 1742 - 0 = 1742 C1/C5 = 183 NPH pp C5 657 - 0 = 657 2 ... ._ 1 Production 100.0 - Analysis 1 , 1 r 7 iGas nod nWater n Non-Producible Hydrocarbons I:I LI% ... — Depth 9854 ft Gas [ j, Units 910 Mud Chlorides (1000's) , na Gas __ 1 I 1111 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10.0 - ------------ 0 Cl 68714 - 0 = 68714 C1/C2 = 19.2 I 1111 C2 3572 - 0 = 3572 Cl/C3 = 37.9 I C3 1813 - 0 = 1813 C1/C4 = 67.6 Oil I C4 1016 - 0 = 1016 C1/C5 = 168 - — - — 1111 ipl C5 408 - 0 = 408 NPH .... 1 .... , - ... 1 I VV Production 1.0 .. , .. , iFt Analysis MGas foil nWater nNon-Producible Hydrocarbons . , !III 3 W% Hydrocarbon Ratios III: Depth 9864 ft Gas NUnits 114 Mud Chlorides (1000's) , na Cl Cl Cl Cl I 1111 Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm Hydrocarbon Ratios 1000.0 1111 Cl 11999 - 0 = 11999 C1/C2 = 18.0 111 1111 C2 665 - 0 = 665 C1/C3 = 28.9 C3 415 - 0 = 415 C1/C4 = 49.0 NPH 111! C4 245 - 0 = 245 C1/C5 = 92 _._ I - IIII C5 131 - 111 Production 0 = 131 — — ip Analysis Gas foil nWater nNon-Producible Hydrocarbons 100.0 .. .. — FI j -- I IR: Depth 9876 ft Gas NUnits 94 Mud Chlorides (1000's): na Gas Flowline Background Show - - im ppm ppm ppm .- Hydrocarbon Ratios 10.0 I HI , Cl 7510 - 0 = 7510 C1/C2 = 15.8 C2 475 - 0 = 475 C1/C3 = 21.7 Oil _ C3 346 - 0 = 346 C1/C4 = 30.9 C4 243 - 0 = 243 C1/CS= 160 C5 47 - 0 = 47 NPH I 4 111: Production 1.0 :IP Analysis rxiGas nOil nWater nNon-Producible Hydrocarbons Riamonmignill111111111IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIINIIIMINNIIIIIIIIIIIIIIIIIIIIIIMIRIMINIMMINUMINEMENNUNERVIIHREMENNWORMIMMIIMM I I I I SPERRY Well Name: ODSK 33 Depth (MD) 9900 to 9940 ft 11111 Location: 000GURUK (TVD) 6079 to 6080 ft IV 11111 DRILLING SERVICES Operator: PIONEER Show Report No 2 1111' I igil Show Report Report Prepared By Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 Report Delivered To Tavia Jackson IN I !III! Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. 11111 Formation: Sandstone- off white to light brown, clear to transparent, medium to coarse grain, angular to subangular, well sorted, lip predominately loose quartz grains, occasional nodular pyrite, occasional nodular glauconite, dull yellow natural fluorescence, slow pale 11111 yellow cut fluorescence. ., .., I I 11 Depth 9900 ft Gas Un its Chlorides (1000 Cl Cl 's) na Hydrocarbon Ratios Cl Cl 10 —......------Er 192 Mud Flow line Background Show C2 C3 C4 C5 1111. I 1111 ppm ppm ppm Hydrocarbon Ratios 1000.0 Cl 18898 - 0 = 18898 C1/C2 = 19.2 0 C2 984 - 0 = 984 C1/C3 = 33.8 I 1111 C3 559 - 0 = 559 C1/C4 = 52.6 1111 C4 359 - 0 = 359 C1/C5= 128 NPH .,.. C5 148 - 0 = 148 ... ■ ... 1 1111 2 Production 100.0 - plc — ..-- -- MI Analysis Gas foil nWater fl Non Hydrocarbons _, • ..="----- ■II NI MI Depth 9920 ft Gas NUnits 99 Mud Chlorides (1000's) . na Gas II 1111 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios 10.0 -- — — — — — — — — — — — — C1 8094 - 0 = 8094 C1/C2 = 14.7 I IIII C2 550 - 0 = 550 C1/C3 = 22.2 110 C3 364 - 0 = 364 C1/C4 = 32.5 Oil 1111 C4 249 - 0 = 249 C1/C5 = 123 — — MI C5 66 - 0 = 66 NPH I 01 Production 1.0 1111 Analysis FiGas foil nWater nNon-Producible Hydrocarbons 1111 3 _ % Hydrocarbon Ratios Depth 9931 ft Gas x Units 181 Mud Chlorides (1000's) , na Cl C1 Cl Cl 11111 I 1111 Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm Hydrocarbon Ratios 1000.0 111 C1 16598 - 0 = 16598 C1/C2 = 21.4 I IM C2 774 - 0 = 774 C1/C3 = 38.3 [1111 C3 433 - 0 = 433 C1/C4 = 58.2 NPH IIII C4 285 - 0 = 285 C1/C5 = 152 I 111 C5 109 - 0 = 109 .... _ ... -- !!!! '01 Production 100.0 — — . all Analysis 131Gas foil nWater n Non-Producible Hydrocarbons 1-- .- __ LI 1111 4 I % I 1111 Depth 9940 ft Gas I2_1( Units 623 Mud Chlorides (1000's) , na Gas Flowline Background Show — -- PPm PPm PPm Hydrocarbon Ratios 10.0 1111 Cl 65213 - 0 = 65213 C1/C2 = 21.1 ifil I C2 3096 - 0 = 3096 C1/C3 = 45.5 Oil 11 1111 C3 1433 - 0 = 1433 C1/C4 = 87.4 111 C4 746 - 0 = 746 C1/C5 = 229 MI I 1111 C5 285 - 0 = 285 NPH 1111 Production 1.0 III Analysis Gas foil nWater pNon-Producible Hydrocarbons I 1 I I SPERRY Well Name: ODSK 33 Depth (MD) 9990 to 10020 ft III Location: 000GURUK (TVD) 6082 to 6083 ft IIII MI DRILLING SERVICES Operator: PIONEER Show Report No. 3 Show Report Report Prepared By: Boyd Piercey / Doug Wilson Date/Time: 25- Apr -08 Report Delivered To Tavia Jackson II II Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. . Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subangular, moderately sorted, very ? friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, III dull yellow sample fluorescence, streaming dull yellow to milkywhite cut fluorescence, dull yellow ring cut fluorescence. I 11111_11 ,;. ;; : :: / Hydrocarbon Ratios HO Depth 9990 ft Gas L_I Units 299 Mud Chlor (1000's) na C1 C1 C1 C1 MI Flowline Background Show C2 C3 C4 C5 ii ppm ppm ppm Hydrocarbon Ratios 1000.0 `' C1 29571 - 0 = 29571 C1 /C2 = 18.2 iiii C2 1627 - 0 = 1627 C1 /C3 = 39.5 I VII C3 748 - 0 = 748 C1 /C4 = 76.0 Mil C4 389 0 = 389 C1 /C5 = 229 NPH "11 Illi C5 129 - 0 = 129 Production 100.0 - J -- .-- I ' � Analysis nGas foil nWater f Non- Producible Hydrocarbons - (I IIII Depth 10000 ft Gas HUnits 375 Mud Chlorides (1000's) na Gas I io!- Flowline Background Show -- - - - - - - - - - - - - ppm ppm ppm Hydrocarbon Ratios 10.0 - 1111. C1 40990 - 0 = 40990 C1 /C2 = 20.6 I 11111 C2 1987 - 0 = 1987 C1 /C3 = 46.5 Ng C3 882 0 = 882 C1 /C4 = 96.9 Oil C4 423 - 0 = 423 C1 /C5 = 295 C5 139 - 0 = 139 NPH I Production 1.0 IN Analysis nGas f Oil (Water f Non- Producible Hydrocarbons 3 _ % Hydrocarbon Ratios Depth 10010 ft Gas x Units 565 Mud Chlorides (1000's) na C1 C1 C1 C1 Flowline Background Show PP m ppm C2 C3 C4 C5 m pP Hydrocarbon Ratios 1000.0 1111 - C1 55139 - 0 = 55139 C1 /C2 = 19.2 _ C2 2869 - 0 = 2869 C1 /C3 = 40.3 III C3 1367 0 = 1367 C1 /C4 = 75.6 NPH lil C4 729 - 0 = 729 C1 /C5 = 205 C5 269 - 0 = 269 _ -7-7 I Production 100.0 _� —�� MI Analysis Gas foil f Water f Non- Producible Hydrocarbons Q' I U ___ J Depth 10019 ft Gas I 577 Mud Chlorides (1000's) , na Flowline Background Show - -- ppm ppm ppm Gas Hydrocarbon Ratios 10.0 1 1 C1 60995 - 0 = 60995 C1 /C2 = 17.3 C2 3534 - 0 = 3534 C1 /C3 = 35.4 Oil — C3 1722 - 0 = 1722 C1 /C4 = 64.6 C4 944 - 0 = 944 C1 /C5 = 170 - - - - iii ' C5 358 0 = 358 NPH iiiii Production 1.0 ' ° ' Analysis © Gas II Oil I Water I Non - Producible Hydrocarbons I 1 .......................,,,,..,....................,...................._....„.....,....................................._,,,,,,,,,,_:...,.............................................._,,,,....,.............................................., Iv I SPERRy Well Name: ODSK 33 Depth (MD) 10030 to 10060 ft Location: 000GURUK (ND) 6083 to 6084 ft IIII IIIII DRILLING SERVICES Operator: PIONEER Show Report No 4 11111 1 1 lir Show Report Report Prepared By: Boyd Piercey / Doug Wilson DateiTime: 25-Apr-08 Report Delivered To Tavia Jackson 33, 111 !III! Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. .3 pi Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subangular, moderately sorted, very IIII: friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, OM dull yellow sample fluorescence, streaming dull yellow to milkywhite cut fluorescence, dull yellow ring cut fluorescence. .... I 1111 1 x % Hydrocarbon Ratios 11111 1111 Depth 10030 ft Gas Units 694 Mud Chlorides (1000's) , na Cl Cl Cl Cl !III! Ili Flowline Background Show C2 C3 C4 C5 IIII' I ppm ppm ppm Hydrocarbon Ratios 1000.0 ...3 IIII Cl 70539 - 0 = 70539 C1/C2 = 17.0 MI C2 4139 - 0 = 4139 C1/C3 = 34.6 I OH C3 2038 - 0 = 2038 C1/C4 = 65.6 NI C4 1076 - 0 = 1076 C1/C5 = 177 NPH II:I C5 399 - 0 = 399 - - - -- 1 1111 Production 100.0 - Fir 2 110 Analysis Gas foil nWater nNon-Producible Hydrocarbons ... .. ... - - _ IIII IIII Depth 10040 ft Gas 12d Units 645 Mud Chlorides (1000's) , na Gas I 1111 Flowline Background Show PPm PPm PPm - - - - - - - -- --- Hydrocarbon Ratios 10.0 - :.,.: .., IIII C1 64716 - 0 = 64716 C1/C2 = 16.6 I HI! C2 3894 - 0 = 3894 C1/C3 = 33.1 IN C3 1955 - 0 = 1955 C1/C4 = 61.1 Oil 1111 C4 1060 - 0 = 1060 C1/C5 = 168 - - — — - IIII C5 385 - 0 = 385 NPH I 1.0 1111 Production IIII Analysis rxiGas nOil nWater nNon-Producible Hydrocarbons 1111 3 H% Hydrocarbon Ratios IN Depth 10051 Gas Units 662 Mud Chlorides (1000's) , na Cl Cl Cl Cl 0111 I Hil ft Flowline Background Show P C2 C3 C4 C5 Pm ppm PPm Hydrocarbon Ratios 1000.0 Cl 67120 - 0 = 67120 C1/C2 = 17.2 I C2 3913 - 0 = 3913 C1/C3 = 34.2 T!, 1111 C3 1965 - 0 = 1965 C1/C4 = 63.5 NPH PI C4 1057 - 0 = 1057 C1/C5 = 181 I !III C5 370 - 0 = 370 _ _ _ 11111 RR Production 100 „, .0 ----' -- IIIII .... -;... Oil Analysis rxiGas foil nWater nNon-Producible Hydrocarbons - - :III I:I LI% I IIII Depth 10061 ft Gas N Units 697 Mud Chlorides (1000's) , na Gas 1111 Flowline Background Show ----- PPm PPm PPm Hydrocarbon Ratios 10.0 MI Cl 72268 - 0 = 72268 c1ic2 = 17.1 1111 1 1111 C2 4229 - 0 = 4229 C1/C3 = 34.0 Oil IIII C3 2123 - 0 = 2123 C1/C4 = 65.3 IIII C4 1107 - 0 = 1107 C1/C5 = 178 lir, III: C5 407 - 0 = 407 NPH io I 1111 Production 1.0 ... Analysis nr Gas foil nWater fl Non-Producible Hydrocarbons I !p kmiligiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiimiiiiiimiliiiiiiiiiiiimoiniiiiiimigniiiiiiik 1 I I 11111 SPERRY Well Name: ODSK 33 Depth (MD) 10070 to 10100 ft IIII Location: 000GURUK (TVD) 6085 to 6086 ft 11111 DRILLING SERVICES Operator: PIONEER Show Report No. 5 PI: 01 Show Report Report Prepared By Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 I lig Report Delivered To Tavia Jackson .4 :., ,..............„......,.. .,...................,,,,,....,...,,.......... ............................. ...„.............,.,„.............,................,....„.. .......... ........ ....,. 0111 In terpre t at i on I aherpreL ati on: Chromatograph gas in air analysis from gas trap at possum belly. 11111 Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subangular, moderately sorted, very friable, predorr illi !!!!1 friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, dull yellow sample fluorescence, streaming dull yellow to milky white cut fluorescence, dull yellow-gold ring cut fluorescence. lill LI , H a Hydrocarbon Ratios 1111 c't i Depth 10070 ft Gas Units 1170 Mud Chlorides (1000's) : na Cl Cl Cl Cl IIII Flowline Background Show C3 C4 I ppm ppm ppm Hydrocarbon Ratios 1000.0 11111 Cl 112123 - 0 = 112123 C1/C2 = 16.8 C2 6683 - = 6683 C1/C3 = 33.9 I P C3 3304 - 0 6 0 = 3304 C1/C4 = 66.5 IIII C4 1687 - 0 = 1687 C1/C5 = 194 NPH IIII C5 579 - 0 = 579 roduction 100.0 - ... .,_ .... ••••• mi I My P roduction .- 1 --..— — In Analysis rxi Gas foil Water nNon-Producible Hydrocarbons — — 121 H Ili i!!! Depth 10080 ft Gas Units 937 Mud Chlorides (1000's) : na Gas I IIIII Flowline Background Show PPm PPm PPm -------------- IM Hydrocarbon Ratios 10.0 - IIIII Cl 96273 - 0 = 96273 C1/C2 = 16.5 I C2 5841 - IIII. C3 2930 - 0 = 5841 C1/C3 = 32.9 0 = 2930 C1/C4 = 64.5 Oil IIIII C4 1492 - 0= 1492 C1/CS= 180 -- C5 MI C5 536 - 0 = 536 NPH I 0 Production 1.0 1111 Analysis FclGas nail nWater nNon-Producible Hydrocarbons 12_1 1_1% Hydrocarbon Ratios 1111 Depth 10090 Gas 1 21 Units 317 Mud Chlorides (1000's) , na Cl Cl I NI, ft Flowline Background Show Cl Cl I C4 C5 1111 ppm ppm ppm Hydrocarbon Ratios 1000.0 IIM Cl 32673 - 0 = 32673 C1/C2 = 14.3 I Illi C2 2286- III C3 1309 - 0 = 2286 C1/C3 = 25.0 0 = 1309 C1/C4 = 40.8 NPH III: :IT C4 801 - 0 = 801 C1/C5= 105 MI I — MIr C5 311 - 0 = 311 .- IIII Production 100 .. .0 — — __ pli Analysis 151( Gas foil nWater nNon-Producible Hydrocarbons ____.,.. ._. - IIIM l I HI(' Depth 10100 ft Gas LI( Units 182 Mud Chlorides (1000's) : na Gas MI Flowline Background Show -- ppm ppm ppm 1-- — -- Hydrocarbon Ratios 10.0 I MI C1 15050 - 0 = 15050 C1/C2 = 11.5 III: C2 1304 - 0 = 1304 C1/C3 = 16.8 Oil ily C3 895 - 0 = 895 C1/C4 = 25.3 IIII• C4 594 - 0= 594 C1/CS= 62 ------ — — — — I C5 243 - 0 = 243 NPH 1.0 III!: Production ... 114 Analysis fl Gas 9 011 ['Water nNon-Producible Hydrocarbons I 1 I :!:::::::::::::::::::::::::::::::!::::::::::::em::::::::: I Pr SPERRY Well Name: ODSK 33 Depth (MD) 10110 to 10140 ft Mil 1111: Location: 000GURUK (TVD) 6086 to 6087 ft Rill 0III DRILLING SERVICES Operator: PIONEER Show Report No 6 011. 1111= Show Report Report Prepared By: Boyd Piercey / Doug Wilson DatefTime: 25-Apr-08 I 1111 Report Delivered To Tavia Jackson Br I NI Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. .., . ,.,., Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subangular, moderately sorted, very IIII1 . . . . .. . . . . . • friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, 1111 dull yellow sample fluorescence, streaming dull yellow to milky white cut fluorescence, dull yellow-gold ring cut fluorescence. 1 11„_11 H,' Ra Hydrocarbon Rat . . . Depth 10112 ft Gas Units 1080 Mud Chlorides (1000's) ' na Cl Cl Cl Cl 11111 Flowline Background Show C2 C3 C4 C5 1111 I 1111 ppm ppm ppm Hydrocarbon Ratios 1000.0 :III Cl 94528 - 0 = 94528 C1/C2 = 15.6 Ili C2 6062 - 0 = 6062 C1/C3 = 31.1 I I ii i C3 3042 - 0 = 3042 C1/C4 = 58.6 C4 1614 - 0 = 1614 C1/C5 = 165 NPH IN: C5 574 - 0 = 574 - -- -- "• .- .- 1111: 11111 Production 100.0 - --- I IIIII Analysis RGas noil nWater nNon-Producible Hydrocarbons - - ... - MILLI 1111 Depth 10120 ft Gas I2_1( Units 992 Mud Chlorides (1000's) , na !!!!; Gas I 1 Flow Background Show - - - - - - - - - - - - - - Hydrocarbon Ratios 10.0 - fill Cl 90841 - 0 = 90841 C1/C2 = 15.3 MI I NI C2 5936 - 0 = 5936 C1/C3 = 29.9 11111 C3 3039 - 0 = 3039 C1/C4 = 55.4 Oil 1:11 C4 1640 - 0 = 1640 C1/C5 = 144 - C5 633 - 0 = 633 NPH 1.0 II IIII Pr iii Gas f oil nWater n Non-Producible Hydrocarbons MIL31 % Hydrocarbon Ratios Depth 10130 ft Gas NUnits 1113 Mud Chlorides (1000's): na Cl Cl Cl Cl MI I NI Flowline Background Show C2 C3 C4 C5 II; ppm ppm ppm Hydrocarbon Ratios 1000.0 MI Cl 102324 - 0 = 102324 C1/C2 = 15.1 I IIII. C2 6796 - IN C3 3508 - 0 = 6796 C1/C3 = 29.2 0 = 3508 C1/C4 = 53.8 NPH C4 1903 - 0 = 1903 C1/C5 = 142 C5 721 - 0 = 721 - ;." I 1111, Production 100.0 .... - - -- "' -- -.- NI Analysis fl Gas nOil nWater nNon-Producible Hydrocarbons ......- -- - I W II Depth 10140 ft Gas NUnits 877 Mud Chlorides (1000's) : na Gas Mi Flowline Background Show - - - - - m. - - - ppm ppm ppm - - - - - Hydrocarbon Ratios 10.0 I 11 C C2 1 9 6 35 1 6 54 9 - 0 = 93569 C1/C2 = 15.2 - Oil 0 = 6154 C1/C3 = 29.4 II: C3 3181 - 0 = 3181 C1/C4 = 53.7 C4 1743 - 0 = 1743 C1/C5 = 143 NPH H11; 0 II 1111 C5 653 653 - = 653 1.0 MI Analysis la Gas I Oil I Water I Non-Producible Hydrocarbons I I I I I 1111i SPERRY Well Name: ODSK 33 Depth (MD) 10160 to 10220 ft !III: Location: 000GURUK (TVD) 6088 to 6090 ft IIII IIIIi DRILLING SERVICES Operator: PIONEER Show Report No 7 I Show Report Report Prepared By Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 IL IIII Report Delivered To Tavia Jackson :!!!!': I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. !III Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subrounded, moderately sorted, very MI friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, Il dull yellow sample fluorescence, streaming green yellow milky white cut fluorescence, milky white ring cut fluorescence. I LI ::„„„,„„„,,,„„:„„„„„„„,.,:::::,.:.,„,„,,,,,,,,,,,,,,,„:„,,,,,,,,,,,,,,,.,,,,,,,,,,,,,,,,,,,,,,,,,„:„,:„„,„::::::,:„,:,:_,_,:,„„„„„„*,„„„„_„,„..,:,:,...........,.,.,.,.,.,,,.,.,.,.,.,,,,,_,,......................................................,,,z,,,,:,..................„...,...............,...; :::: /0 Hydrocarbon Ratios 1111: Depth 10160 ft Gas 12dUnits 756 Mud Chlorides (1000's) : na Cl Cl Cl Cl VIII NI Flowline Background Show C2 C3 C4 C5 0 i I 1111: ppm ppm ppm Hydrocarbon Ratios 1000.0 .., C1 63222 - 0 = 63222 C1/C2 = 14.6 C2 4325 - 0 = 4325 c1ic3 = 26.9 I C3 2351 - 0 = 2351 C1/C4 = 45.8 IIIIi C4 1381 - 0 = 1381 Cl/C5 = 110 NPH III,Il C5 576 - 0 = 576 I Production 100 FI .0 . ...„ - - - ........ IIIII Analysis Gas foil nWater fl Non Hydrocarbons - - '-- - --.. .- Analysis IN Depth 10179 ft Gas x Units 197 Mud Chlorides (1000's) , na Gas I I T : Flowline Background Show --- ppm ppm ppm --------- Hydrocarbon Ratios 10.0 IIIII ci 17078 - 0 = 17078 Cl/C2 = 11.8 I M: c2 1448 - 0 = 1448 Cl/C3 = 18.2 1111 C3 939 - 0 = 939 C1/C4 = 26.4 Oil IlIt C4 648 - 0 = 648 C1/C5 = 57 — .., IIII= C5 300 - 0 = 300 NPH 1.0 I il Production ..... MI Analysis 131( Gas foil nWater n Non-Producible Hydrocarbons 1 3 I _ % Hydrocarbon Ratios .1.. IIIII Depth 10201 ft Gas x Units 330 Mud Chlorides (1000's) , na Cl Cl Cl Cl IIIII I IN Flowline Background Show C2 C3 C4 C5 IIIII ppm ppm ppm Hydrocarbon Ratios 1000.0 _ III: Cl 29396 - 0 = 29396 C1/C2 = 14.0 .., I C2 2107 - - IT' 0 = 2107 C1/C3 = 22.6 C3 1302 0 = 1302 C1/C4 = 33.8 NPH C4 869 - 0 = 869 C1/C5 = 68 IIII, C5 430 fl Gas 0= 430 _ - - - I 11111 Production 100.0 • -- - _ 1111. ii Analysis Gas foil nWater f Non-Producible Hydrocarbons ,- -- — ... 1 11!1 Depth 10220 ft Gas Units 380 Mud Chlorides (1000's) : na Gas Flowline Background Show _ - - - - -- ____.- - - - 11111 PPm PPm PPm Hydrocarbon Ratios 10.0 IIII I 11 C1 33451 - 0 = 33451 C1/C2 = 13.6 101 C2 2467 - 0 = 2467 C1/C3 = 22.9 Oil II C3 1460 - 0 = 1460 C1/C4 = 34.6 IIIII C4 967 - 0 = 967 C1/C5 = 71 MI C5 468 - 0 = 468 NPH . . Production I 1.0 1,111,1; .., MI Analysis nGas nOil nWater nNon-Producible Hydrocarbons I I I 5 I :11:1 1 " 1111 SPERRY Well Name: ODSK 33 Depth (MD) 10240 to 10301 ft iiiii Location: 000GURUK (TVD) 6090 to 6091 ft DRILLING SERVICES Operator: PIONEER Show Report No 8 ill: I Show Report Report Prepared By Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 Report Delivered To Tavia Jackson I 1111: Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subrounded, moderately sorted, very .., friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, i dull yellow sample fluorescence, streaming green yellow milky white cut fluorescence, milky white ring cut fluorescence. IIIII I 1111 L11 H, Hydrocarbon Ratios 11111 11111 Depth 10240 ft Gas Units 403 Mud Chlorides (1000's) , na Cl Cl Cl Cl NI fill Flowline Background Show C2 C3 C4 C5 I ppm ppm ppm Hydrocarbon Ratios 1000.0 .., III: Cl 34936 - 0 = 34936 C1/C2 = 13.0 1111 C2 2680 - 0 = 2680 C1/C3 = 21.6 .., .., I C3 1615 - 0 = 1615 C1/C4 = 32.7 C4 1070 - 0 = 1070 C1/C5 = 67 NPH .., 1111 C5 523 - 0 = 523 ... Production 100.0 - ..... ....- -- 1 " I 1111: Analysis FIGas nOil nWater nNon-Producible Hydrocarbons - iiiiL2 1_1% RI Depth 10260 ft Gas NUnits 820 Mud Chlorides (1000's) : na Gas I Flowline Background Show ---- gi ppm ppm ppm --------- Hydrocarbon Ratios 10.0 - Cl 78795 - 0 = 78795 C1/C2 = 14.7 I fill C2 5360 - 0 = 5360 C1/C3 = 26.5 III' C3 2968 - 0 = 2968 C1/C4 = 46.0 Oil 1111 C4 1712 - 0 = 1712 C1/C5 = 114 - 1111. C5 692 - 0 = 692 NPH I 1111 Production 1.0 IN Analysis plc Gas nOil nWater n Non-Producible Hydrocarbons Hydrocarbon Ratios MI Depth 10280 ft Gas NUnits 302 Mud Chlorides (1000's) : na Cl Cl Cl Cl I HD. Flowline Background Show C2 C3 C4 C5 _ ppm ppm ppm Hydrocarbon Ratios 1000.0 Pi Cl 24681 - 0 = 24681 C1/C2 = 11.0 I III C2 2238 - 0 = 2238 C1/C3 = 16.0 .. , 1:11 C3 1542 - 0 = 1542 C1/C4 = 22.7 NPH C4 1088 - 0 = 1088 C1/C5 = 52 1111 C5 479 - 0 = 479 _ -- - II ;Or Production 100.0 - -- ---,-- ' :111Y Analysis [ - xi Gas foil n Water n Non-Producible Hydrocarbons ._ - - - - - - HILL! LI% HQ; I 1111 Depth 10301 ft Gas p_cl Units 248 Mud Chlorides (1000's) : na Gas Flowline Background Show — - .., ppm ppm PPm ;711;iliSil.. Hydrocarbon Ratios 10.0 1 1 ll li: IIIii Cl 15970 -11: C2 1721 - 0 = 15970 C1/C2 = 9.3 0 = 1721 C1/C3 = 11.5 Oil HO. 0 = 1389 C1/C4 = 15.6 1 C3 1389 .„, 0 = 1024 C1/C5 = 34 - - - - I 111I1 C5 476 - 0 = 476 NPH iiiii Production 1.0 .., .., VV. Analysis nGas fl Oil nWater nNon-Producible Hydrocarbons I I I Depth (MD) 10320 to 10380 ft iiii I SPERRY Well t N i I 0 0 D 0 S 0 K G 3 u 3 RuK (TVD) 6091 to 6092 ft il DRILLING SERVICES Operator: PIONEER Show Report No 9 IIII I il Show Report Report Prepared By Boyd Piercey / Doug Wilson Date/Time: 25-Apr-08 Report Delivered To Tavia Jackson .., I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. -.- Formation: Sandstone- off white to brown, clear to transparent, medium to coarse grain, angular to subrounded, poor-moderately sorted, iiii very friable, predominately siderite and siliceously cemented quartz grains, loose quartz grains, bituminous, occasional nodular glauconite, 1111 dull yellow sample fluorescence, streaming green yellow milky white cut fluorescence, milky white ring cut fluorescence. I ! ! !!! ! =;1 .: : : : :....,—,„„.„„„ : :„.„.„„..„„„ : „:„....:..,„:„ : „„:„ : „„„„„: : :....„ [1 : : : : : : : : : : : : : : : : : : „„„...„„::„:::::::::„.::::::::::::::::: : „:„„ : „„„:„ : „„„„:„:::::::::::::::::::::::::„...:.::::::::::::::::::„„„„„„„„„„„„:„:„„:::::::::::::„...............::::„:::„„.......„....„„:„:„„:„......:::::::::::::::::::„.........„„::„....::::::„.....:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::„:::::::::::::::—............... „ ..iiii % Hydrocarbon Ratios 11 Depth 10320 ft Gas uj Units 1011 Mud Chlorides (1000's) : na Cl Cl Cl Cl Ili Flowline Background Show C2 C3 C4 C5 I 1111 ppm ppm ppm Hydrocarbon Ratios 1000.0 - trill 51163 - 0 = 51163 C1/C2 = 10.6 . 1111 C2 4832 - 0 = 4832 C1/C3 = 20.2 I 11111 C3 2530 - 0 = 2530 C1/C4 = 31.5 111 C4 1626 - 0 = 1626 C1/C5 = 77 NPH Hi C5 666 - 0 = 666 - •- .,., -. -- 1 :ill'd Production 100.0 - ., .. Analysis FIGas nOil nWater nNon-Producible Hydrocarbons ., W% It Depth 10340 ft Gas N Units 1098 Mud Chlorides (1000's) : na Gas 011111 11111111111.."1- I Flowline Background Show ___________ ppm ppm ppm Hydrocarbon Ratios 10.0 Cl 94773 - 0 = 94773 C1/C2 = 14.5 1 I pH C2 6525 - 0 = 6525 C1/C3 = 25.7 C3 3686 - 0 = 3686 C1/C4 = 45.6 Oil C4 2080 - 0 = 2080 C1/C5 = 117 NI C5 810 - 0 = 810 NPH I Production iiiii Analysis FlGas nOil nWater nNon-Producible Hydrocarbons 1.0 MILLI 1_1% Hydrocarbon Ratios I Depth 10353 ft Gas NUnits 984 Mud Chlorides (1000's) , na Cl Cl Cl Cl IN iiii ... Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm 1111 Hydrocarbon Ratios 1000.0 gill Cl 70160 - 0 = 70160 C1/C2 = 14.9 I C2 4702 - :I. C3 2762 - 0 = 4702 C1/C3 = 25.4 0 = 2762 Cl/C4 = 42.2 !.•'-: .,. NPH C4 1661 - 0 = 1661 C1/C5 = 102 I ::... C5 688 - !ir. iiii Production 0 = 688 - - _. 1111 Analysis FIGas foil I nNon-Producible Hydrocarbons 100 0 - _ -.- - . _,_.-- - .... .- Li% I Depth 10378 ft Gas N Units 304 Mud Chlorides (1000's) : na RIII Flowline Background Show Gas - - _ - 111 ppm ppm ppm ___ - - Hydrocarbon Ratios 10.0 I C1 22694 - III C2 2139 - 0 = 22694 C1/C2 = 10.6 0 = 2139 C1/C3 = 14.9 Oil III: C3 1524 - 0 = 1524 C1/C4 = 20.8 1111 C4 1091 - 0= 1091 Cl/C5= 46 --------i_ 1 I :III C5 497 - 0 = 497 NPH MI Production 1.0 Analysis nGas nOil nWater nNon-Producible Hydrocarbons 1 I Sperry Drilling Services I ° INSITE . DIRECTIONAL SURVEY REPORT Pioneer Natural Resources AK ODSK -33PB1 I Oooguruk North Slope Borough Alaska U.S.A. AK -MW- 000555644 I Measured Original hole which was plugged back due to fish in the hole. Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) I 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE -IN 100.00 0.23 201.27 100.00 0.19 S 0.07 W 0.19 0.23 169.00 0.40 223.51 169.00 0.49 S 0.29 W 0.52 0.30 I 263.00 0.36 329.39 263.00 0.47 S 0.67 W 0.54 0.65 356.00 0.23 179.30 356.00 0.41 S 0.81 W 0.49 0.61 447.00 0.50 335.84 447.00 0.23 S 0.97 W 0.32 0.79 539.00 0.78 269.96 538.99 0.14 N 1.76 W 0.03 0.80 I 631.00 2.23 282.39 630.96 0.52 N 4.14 W -0.12 1.61 723.00 3.96 280.67 722.82 1.49 N 9.01 W -0.63 1.88 815.00 5.28 272.22 814.52 2.24 N 16.36 W -0.68 1.61 I 905.00 5.36 274.56 904.13 2.74 N 24.69 W -0.38 0.26 0.61 1003.00 4.85 271.03 1001.74 3.18 N 33.39 W 0.01 1044.41 5.09 269.67 1043.00 3.20 N 36.98 W 0.33 0.65 1140.79 6.36 280.00 1138.90 4.10 N 46.51 W 0.34 1.69 I 1236.05 7.23 285.41 1233.49 6.61 N 57.49 W -1.12 1.13 1333.71 8.05 285.96 1330.28 10.12 N 69.99 W -3.43 0.84 1429.22 10.60 281.60 1424.52 13.73 N 85.03 W -5.59 2.77 1526.00 14.13 279.28 1519.04 17.42 N 105.41 W -7.33 3.68 I 1622.24 17.14 281.26 1611.71 22.09 N 130.92 W -9.56 3.18 1719.50 19.77 283.59 1703.96 28.75 N 160.97 W - 13.34 2.81 1816.14 19.52 285.35 1794.98 36.87 N 192.42 W -18.43 0.66 I 1913.06 19.97 284.01 1886.20 45.16 N 224.10 W -23.67 0.66 1.86 2009.74 19.20 279.16 1977.29 51.69 N 255.81 W -27.16 2106.45 18.21 277.49 2068.89 56.19 N 286.49 W 28.73 1.16 2202.12 17.93 277.68 2159.85 60.11 N 315.91 W -29.83 0.30 I 2298.77 18.21 277.12 2251.73 63.97 N 345.64 W -30.85 0.34 2394.74 18.27 277.16 2342.88 67.70 N 375.44 W -31.74 0.06 2491.96 18.79 281.69 2435.06 72.77 N 405.90 W -33.89 1.57 2586.99 18.73 282.57 2525.04 79.20 N 435.78 W -37.45 0.30 2683.95 20.23 282.65 2616.45 86.26 N 467.33 W -41.48 1.55 2780.25 22.79 281.22 2706.04 93.53 N 501.88 W -45.44 2.71 2877.02 25.44 280.16 2794.35 100.85 N 540.73 W -49.03 2.77 2973.87 27.96 278.88 2880.87 108.02 N 583.64 W -52.10 2.67 I 3069.17 30.84 278.49 2963.89 115.08 N 629.88 W -54.73 3.03 3118.50 31.62 278.71 3006.07 118.90 N 655.17 W - 56.14 1.60 3216.14 33.44 280.52 3088.39 127.69 N 706.93 W -59.97 2.11 3260.08 33.11 280.40 3125.12 132.07 N 730.64 W -62.08 0.77 I 3356.84 33.01 281.34 3206.22 142.02 N 782.47 W -67.06 0.54 3453.54 33.96 280.56 3286.87 152.15 N 834.85 W - 72.17 1.08 3549.51 35.50 281.37 3365.74 162.56 N 888.52 W -77.43 1.68 I 3646.09 35.84 283.07 3444.20 174.48 N 943.56 W -84.08 1.09 0.31 3743.12 35.54 283.02 3523.01 187.26 N 998.71 W -91.56 3839.50 36.70 282.21 3600.86 199.66 N 1054.15 W 98.64 1.30 3936.26 38.23 281.79 3677.66 211.89 N 1111.72 W - 105.35 1.60 I 4029.91 38.59 282.95 3751.04 224.36 N 1168.55 W - 112.36 0.86 I Page 1 of 3 I Sperry Drilling Services I ODSK 33PB1 Measured Vertical Vertical I Depth (feet) Inclination Direction Depth Latitude Departure Section Dogleg (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) I 4129.17 41.82 282.48 3826.84 238.45 N 1231.04 W - 120.45 3.27 0.47 4222.30 42.25 282.36 3896.01 251.87 N 1291.94 W -128.02 4322.96 43.36 280.08 3969.87 265.16 N 1359.03 W - 134.88 1.89 4418.57 47.23 279.30 4037.11 276.58 N 1426.00 W - 139.89 4.09 4514.44 50.18 280.70 4100.38 289.10 N 1496.92 W - 145.62 3.27 I 4612.33 51.19 280.66 4162.40 303.14 N 1571.34 W - 152.53 1.03 4709.56 54.56 281.69 4221.07 318.18 N 1647.38 W - 160.27 3.57 4803.27 58.08 282.56 4273.03 334.57 N 1723.61 W - 169.35 3.83 I 4903.51 60.73 282.96 4324.05 353.63 N 1807.75 W -180.33 2.67 4998.70 61.54 282.86 4370.00 372.25 N 1889.01 W -191.15 0.86 5095.36 61.12 282.37 4416.37 390.77 N 1971.77 W - 201.73 0.62 5191.96 61.08 282.19 4463.06 408.76 N 2054.40 W - 211.79 0.17 I 5287.35 62.20 280.59 4508.37 425.33 N 2136.69 W -220.47 1.89 5384.70 64.46 279.00 4552.07 440.12 N 2222.40 W - 227.05 2.74 5481.31 65.47 279.34 4592.95 454.07 N 2308.82 W - 232.73 1.09 I 5578.11 66.24 277.31 4632.55 466.85 N 2396.21 W - 237.15 2.07 1.25 5672.39 66.61 276.09 4670.26 476.93 N 2482.03 W - 239.04 5771.61 67.01 273.24 4709.33 484.35 N 2572.92 W - 237.78 2.67 5868.46 67.68 270.93 4746.64 487.59 N 2662.23 W - 232.53 2.31 5963.54 68.13 268.61 4782.41 487.24 N 2750.32 W - 223.81 2.31 I 6059.41 68.63 265.06 4817.74 482.31 N 2839.29 W - 210.46 3.48 6158.03 68.94 261.97 4853.44 471.93 N 2930.62 W - 191.45 2.94 6254.69 69.29 257.88 4887.91 456.13 N 3019.52 W - 167.28 3.97 I 6351.35 69.47 255.47 4921.95 435.28 N 3107.54 W -138.16 2.34 6446.33 68.60 253.30 4955.94 411.41 N 3192.95 W - 106.29 2.32 6542.75 67.44 250.70 4992.03 383.80 N 3277.98 W -70.72 2.77 6639.92 67.36 247.94 5029.38 352.12 N 3361.90 W -31.22 2.62 I 6735.97 67.67 246.05 5066.12 317.44 N 3443.58 W 11.06 1.85 6831.27 66.95 243.29 5102.89 279.83 N 3523.05 W 56.05 2.78 6929.34 66.54 239.56 5141.62 236.75 N 3602.16 W 106.45 3.52 I 7025.73 66.75 234.89 5179.85 188.86 N 3676.53 W 161.19 4.45 7122.87 67.03 230.70 5217.99 134.85 N 3747.67 W 221.71 3.98 7219.81 66.75 225.53 5256.06 75.35 N 3814.02 W 287.24 4.91 7313.48 66.35 223.35 5293.34 14.00 N 3874.19 W 354.03 2.18 7410.60 66.09 221.18 5332.50 51.76 S 3933.96 W 425.17 2.06 I 7508.63 66.77 218.27 5371.71 120.86 S 3991.37 W 499.41 2.81 7605.08 66.31 213.98 5410.12 192.30 S 4043.52 W 575.48 4.11 7700.80 65.72 210.88 5449.04 266.10 S 4090.42 W 653.40 3.02 I 7795.77 66.19 207.27 5487.75 341.89 S 4132.55 W 732.85 3.51 7892.05 66.67 203.23 5526.26 421.69 S 4170.18 W 815.86 3.88 7992.03 66.89 199.20 5565.69 507.32 S 4203.41 W 904.26 3.71 8087.82 67.09 194.48 5603.15 591.68 S 4228.95 W 990.66 4.54 I 8184.95 67.24 190.12 5640.86 679.11 S 4248.01 W 1079.51 4.14 8281.39 67.53 186.19 5677.96 767.21 S 4260.63 W 1168.41 3.77 8377.45 67.96 181.90 5714.35 855.87 S 4266.89 W 1257.26 4.16 ' 8472.71 68.25 176.64 5749.90 944.21 S 4265.76 W 1345.10 5.13 8569.61 68.04 174.09 5785.98 1033.84 S 4258.50 W 1433.64 2.45 8665.61 68.03 170.85 5821.89 1122.09 S 4246.83 W 1520.38 3.13 8762.35 68.75 165.60 5857.54 1210.10 S 4228.48 W 1606.24 5.10 8859.64 69.73 161.09 5892.04 1297.22 S 4202.40 W 1690.50 4.45 8956.12 72.38 156.83 5923.37 1382.35 S 4169.63 W 1772.13 5.00 9053.48 75.26 154.64 5950.50 1467.57 S 4131.20 W 1853.31 3.66 9149.87 77.85 150.74 5972.92 1550.84 S 4088.18 W 1932.12 4.76 I 9245.34 80.12 148.77 5991.16 1631.78 S 4040.98 W 2008.21 3.12 9341.99 81.19 146.27 6006.86 1712.22 S 3989.77 W 2083.43 2.78 I Date Printed:03 May 2008 Page 2 of 3 I Sperry Drilling Services I ODSK 33PB1 Measured Vertical Vertical I Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) Dogleg I 9439.18 79.67 143.71 6023.02 1790.71 S 3934.80 W 2156.34 3.03 4.14 9535.88 81.32 140.01 6038.99 1865.70 S 3875.90 W 2225.40 9632.05 79.57 136.69 6054.96 1936.56 S 3812.89 W 2289.95 3.86 9697.58 80.19 134.95 6066.48 1982.82 S 3767.94 W 2331.73 2.78 9730.04 80.19 134.95 6072.01 2005.42 S 3745.30 W 2352.07 0.00 I CALCULATION BASED ON MINIMUM CURVATURE METHOD I SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD I VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 185.45 DEGREES (TRUE) A TOTAL CORRECTION OF 22.67 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED I HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 9730.04 FEET IS 4248.41 FEET ALONG 241.83 DEGREES (TRUE) I I I I I I I I I I I Date Printed:03 May 2008 Page 3 of 3 I Sperry Drilling Services I ''IN9ITE DIRECTIONAL SURVEY REPORT Pioneer Natural Resources, AK ODSK -33 Oooguruk I North Slope Borough Alaska U.S.A. AK -MW- 000555644 Sidetrack from Original hole whick kicked off at 6527' MD I Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/100ft) I 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE -IN 100.00 0.23 201.27 100.00 0.19 S 0.07 W 0.19 0.23 169.00 0.40 223.51 169.00 0.49 S 0.29 W 0.52 0.30 I 263.00 0.36 329.39 263.00 0.47 S 0.67 W 0.54 0.65 356.00 0.23 179.30 356.00 0.41 S 0.81 W 0.49 0.61 447.00 0.50 335.84 447.00 0.23 S 0.97 W 0.32 0.79 539.00 0.78 269.96 538.99 0.14 N 1.76 W 0.03 0.80 I 631.00 2.23 282.39 630.96 0.52 N 4.14 W -0.12 1.61 723.00 3.96 280.67 722.82 1.49 N 9.01 W -0.63 1.88 815.00 5.28 272.22 814.52 2.24 N 16.36 W -0.68 1.61 I 905.00 5.36 274.56 904.13 2.74 N 24.69 W -0.38 0.26 0.61 1003.00 4.85 271.03 1001.74 3.18 N 33.39 W 0.01 1044.41 5.09 269.67 1043.00 3.20 N 36.98 W 0.33 0.65 1140.79 6.36 280.00 1138.90 4.10 N 46.51 W 0.34 1.69 1236.05 7.23 285.41 1233.49 6.61 N 57.49 W -1.12 1.13 I 1333.71 8.05 285.96 1330.28 10.12 N 69.99 W -3.43 0.84 1429.22 10.60 281.60 1424.52 13.73 N 85.03 W -5.59 2.77 1526.00 14.13 279.28 1519.04 17.42 N 105.41 W -7.33 3.68 I 1622.24 17.14 281.26 1611.71 22.09 N 130.92 W -9.56 3.18 1719.50 19.77 283.59 1703.96 28.75 N 160.97 W -13.34 2.81 1816.14 19.52 285.35 1794.98 36.87 N 192.42 W -18.43 0.66 1913.06 19.97 284.01 1886.20 45.16 N 224.10 W -23.67 0.66 I 2009.74 19.20 279.16 1977.29 51.69 N 255.81 W -27.16 1.86 2106.45 18.21 277.49 2068.89 56.19 N 286.49 W - 28.73 1.16 2202.12 17.93 277.68 2159.85 60.11 N 315.91 W -29.83 0.30 I 2298.77 18.21 277.12 2251.73 63.97 N 345.64 W -30.85 0.34 0.06 2394.74 18.27 277.16 2342.88 67.70 N 375.44 W -31.74 2491.96 18.79 281.69 2435.06 72.77 N 405.90 W - 33.89 1.57 2586.99 18.73 282.57 2525.04 79.20 N 435.78 W -37.45 0.30 2683.95 20.23 282.65 2616.45 86.26 N 467.33 W -41.48 1.55 I 2780.25 22.79 281.22 2706.04 93.53 N 501.88 W -45.44 2.71 2877.02 25.44 280.16 2794.35 100.85 N 540.73 W -49.03 2.77 2973.87 27.96 278.88 2880.87 108.02 N 583.64 W -52.10 2.67 I 3069.17 30.84 278.49 2963.89 115.08 N 629.88 W -54.73 3.03 3118.50 31.62 278.71 3006.07 118.90 N 655.17 W - 56.14 1.60 3216.14 33.44 280.52 3088.39 127.69 N 706.93 W -59.97 2.11 3260.08 33.11 280.40 3125.12 132.07 N 730.64 W -62.08 0.77 I 3356.84 33.01 281.34 3206.22 142.02 N 782.47 W -67.06 0.54 3453.54 33.96 280.56 3286.87 152.15 N 834.85 W - 72.17 1.08 3549.51 35.50 281.37 3365.74 162.56 N 888.52 W -77.43 1.68 I 3646.09 35.84 283.07 3444.20 174.48 N 943.56 W -84.08 1.09 0.31 3743.12 35.54 283.02 3523.01 187.26 N 998.71 W -91.56 3839.50 36.70 282.21 3600.86 199.66 N 1054.15 W - 98.64 1.30 3936.26 38.23 281.79 3677.66 211.89 N 1111.72 W - 105.35 1.60 4029.91 38.59 282.95 3751.04 224.36 N 1168.55 W - 112.36 0.86 I 1 Page 1 of 3 I Sperry Drilling Services III ODSK 33 Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) Dogleg I 4129.17 41.82 282.48 3826.84 238.45 N 1231.04 W - 120.45 3.27 0.47 4222.30 42.25 282.36 3896.01 251.87 N 1291.94 W - 128.02 4322.96 43.36 280.08 3969.87 265.16 N 1359.03 W 134.88 1.89 4418.57 47.23 279.30 4037.11 276.58 N 1426.00 W - 139.89 4.09 4514.44 50.18 280.70 4100.38 289.10 N 1496.92 W - 145.62 3.27 I 4612.33 51.19 280.66 4162.40 303.14 N 1571.34 W - 152.53 1.03 4709.56 54.56 281.69 4221.07 318.18 N 1647.38 W - 160.27 3.57 4803.27 58.08 282.56 4273.03 334.57 N 1723.61 W - 169.35 3.83 ' 4903.51 60.73 282.96 4324.05 353.63 N 1807.75 W -180.33 2.67 4998.70 61.54 282.86 4370.00 372.25 N 1889.01 W -191.15 0.86 5095.36 61.12 282.37 4416.37 390.77 N 1971.77 W - 201.73 0.62 5191.96 61.08 282.19 4463.06 408.76 N 2054.40 W - 211.79 0.17 I 5287.35 62.20 280.59 4508.37 425.33 N 2136.69 W -220.47 1.89 5384.70 64.46 279.00 4552.07 440.12 N 2222.40 W - 227.05 2.74 5481.31 65.47 279.34 4592.95 454.07 N 2308.82 W - 232.73 1.09 I 5578.11 66.24 277.31 4632.55 466.85 N 2396.21 W - 237.15 2.07 1.25 5672.39 66.61 276.09 4670.26 476.93 N 2482.03 W - 239.04 5771.61 67.01 273.24 4709.33 484.35 N 2572.92 W 237.78 2.67 5868.46 67.68 270.93 4746.64 487.59 N 2662.23 W - 232.53 2.31 5963.54 68.13 268.61 4782.41 487.24 N 2750.32 W - 223.81 2.31 I 6059.41 68.63 265.06 4817.74 482.31 N 2839.29 W - 210.46 3.48 6158.03 68.94 261.97 4853.44 471.93 N 2930.62 W - 191.45 2.94 6254.69 69.29 257.88 4887.91 456.13 N 3019.52 W - 167.28 3.97 I 6351.35 69.47 255.47 4921.95 435.28 N 3107.54 W -138.16 2.34 6446.33 68.60 253.30 4955.94 411.41 N 3192.95 W - 106.29 2.32 6527.00 70.14 250.12 4984.37 387.72 N 3264.62 W -75.89 4.15 6559.05 70.76 248.87 4995.09 377.14 N 3292.91 W -62.68 4.15 I 6652.96 71.12 245.88 5025.77 342.99 N 3374.82 W -20.91 3.03 6746.88 70.80 245.40 5056.41 306.37 N 3455.70 W 23.23 0.59 6847.03 70.51 241.07 5089.60 263.83 N 3540.05 W 73.59 4.09 I 6944.63 69.96 238.64 5122.61 217.71 N 3619.47 W 127.04 2.41 1.92 7041.68 69.47 236.72 5156.25 169.05 N 3696.40 W 182.79 7137.55 69.27 232.47 5190.05 117.09 N 3769.51 W 241.46 4.15 7233.36 68.27 229.47 5224.75 60.86 N 3838.88 W 304.02 3.10 7330.95 68.30 224.49 5260.87 0.97 S 3905.14 W 371.87 4.74 I 7427.75 68.05 220.89 5296.87 67.01 S 3966.06 W 443.39 3.46 7524.34 66.74 217.82 5334.00 135.93 S 4022.60 W 517.38 3.23 7620.87 68.23 215.05 5370.97 207.67 S 4075.54 W 593.82 3.07 I 7716.66 69.87 210.23 5405.24 282.98 S 4123.76 W 673.37 5.00 7813.96 68.91 204.10 5439.52 363.95 S 4165.32 W 757.92 5.98 7909.52 68.04 199.99 5474.59 446.32 S 4198.69 W 843.09 4.10 8005.52 66.14 195.74 5511.98 530.45 S 4225.83 W 929.42 4.53 I 8101.66 66.51 189.89 5550.61 616.26 S 4245.34 W 1016.69 5.59 8191.91 67.18 186.25 5586.11 698.40 S 4256.98 W 1099.56 3.78 8236.29 67.02 185.25 5603.38 739.07 S 4261.08 W 1140.44 2.11 I 8333.30 67.27 180.81 5641.07 828.31 S 4265.80 W 1229.73 4.23 4.42 8429.27 67.33 176.21 5678.12 916.79 S 4263.50 W 1317.58 8526.51 67.47 172.06 5715.51 1006.07 S 4254.32 W 1405.59 3.94 8623.82 68.00 167.45 5752.39 1094.65 S 4238.31 W 1492.25 4.42 8719.01 68.26 164.50 5787.86 1180.35 S 4216.90 W 1575.53 2.89 I 8815.69 68.06 159.12 5823.85 1265.56 S 4188.90 W 1657.70 5.17 8912.66 67.80 154.62 5860.30 1348.18 S 4153.61 W 1736.59 4.31 9007.89 69.32 150.89 5895.12 1426.96 S 4113.03 W 1811.16 3.98 9105.70 72.49 147.94 5927.12 1506.50 S 4066.00 W 1885.87 4.32 I 9202.41 75.05 144.99 5954.15 1583.87 S 4014.70 W 1958.02 3.95 I Date Printed:03 May 2008 Page 2 of 3 I Sperry Drilling Services ODSK -33 Measured Vertical Vertical I Depth Inclination Direction Depth Latitude Departure Section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) Dogleg I 9299.01 76.57 141.89 5977.84 1659.08 S 3958.91 W 2027.59 3.49 4.00 9395.25 78.80 138.68 5998.37 1731.38 S 3898.84 W 2093.86 9491.55 78.47 138.32 6017.34 1802.09 S 3836.28 W 2158.31 0.50 9588.08 78.97 138.50 6036.22 1872.89 S 3773.44 W 2222.82 0.55 9685.23 80.05 137.59 6053.91 1943.93 S 3709.58 W 2287.47 1.44 I 9779.84 82.37 136.17 6068.37 2012.17 S 3645.67 W 2349.33 2.87 9834.63 84.61 137.70 6074.58 2051.94 S 3608.51 W 2385.39 4.94 9930.64 88.84 139.42 6080.06 2123.78 S 3545.09 W 2450.88 4.75 I 10026.87 87.59 137.11 6083.06 2195.55 S 3481.06 W 2516.25 2.73 10123.19 88.27 135.23 6086.54 2264.98 S 3414.41 W 2579.04 2.07 10219.86 88.21 135.04 6089.51 2333.47 S 3346.24 W 2640.74 0.21 10316.26 90.19 136.64 6090.86 2402.61 S 3279.10 W 2703.19 2.64 I 10427.92 87.16 132.25 6093.44 2480.75 S 3199.43 W 2773.41 4.78 10524.37 87.59 129.98 6097.86 2544.10 S 3126.85 W 2829.59 2.39 10620.26 89.76 131.22 6100.07 2606.49 S 3054.07 W 2884.77 2.61 I 10717.59 89.81 132.93 6100.44 2671.70 S 2981.83 W 2942.83 1.76 4.11 10813.81 92.05 136.19 6098.88 2739.19 S 2913.29 W 3003.51 10910.20 98.52 141.70 6090.00 2811.49 S 2850.29 W 3069.49 8.80 11007.96 96.41 138.62 6077.29 2885.90 S 2788.20 W 3137.67 3.80 11102.59 94.87 138.07 6067.99 2956.26 S 2725.61 W 3201.77 1.73 I 11199.97 92.64 132.68 6061.61 3025.38 S 2657.38 W 3264.10 5.98 11296.06 89.67 127.74 6059.67 3087.38 S 2584.04 W 3318.85 6.00 11391.00 90.31 128.94 6059.69 3146.27 S 2509.58 W 3370.40 1.43 I 11489.43 90.55 129.03 6058.95 3208.19 S 2433.07 W 3424.78 0.26 11585.92 90.80 132.24 6057.81 3271.02 S 2359.86 W 3480.36 3.34 11682.47 90.61 136.54 6056.63 3338.54 S 2290.89 W 3541.03 4.46 11779.02 91.30 139.11 6055.02 3410.07 S 2226.08 W 3606.09 2.76 I 11874.76 89.99 141.73 6053.94 3483.85 S 2165.09 W 3673.74 3.06 11971.30 90.00 142.16 6053.95 3559.87 S 2105.58 W 3743.76 0.45 12055.00 90.00 142.16 6053.95 3625.97 S 2054.23 W 3804.68 0.00 I CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT I ND VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 185.45 DEGREES (TRUE) I A TOTAL CORRECTION OF 22.67 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD. I HORIZONTAL DISPLACEMENT(CLOSURE) AT 12055.00 FEET IS 4167.43 FEET ALONG 209.53 DEGREES (TRUE) I I I Date Printed:03 May 2008 Page 3 of 3 I i - PB1 and ODSK -33 1 Oooguruk ODSK 33 Days -vs- Depth 1 , This Chart covers ODSK -33PB1 and ODSK- • 33. The BHA from clean out run at 9730' �I I and part of the fishing assembly was left in 1000 I , original hole, designated ODSK- 33PB1. - -- -�- - Pipe was severed at 6920'. The well was Drill 12 1/." Hole to plugged back and sidetracked from 6527' to 3183' MI / 3060.6' TVD a final total depth of 12055' for ODSK -33. PIONEER i 2000 -- -- —,—,---- - -- --------------—------ • . ■■■■ ■ ■■■ ■■ . ■■ S : 9`5/8" C t 3172' �� ■ ■ ■ ■■EN _ _ ■■ - -- - -- — 3000 I1 III ' M ■ ■■■ _ ■■ ' 111. ' 1 4000 ; - -- - -- D : ■ ' _ - -- -C 5000 - ---,=— -; . — -- 1 in Kick Off and Side 0 ■ I ■■ Track @ 6527' MD/ d 6000 - -- ___________4:n_. --- - -- U) ■ ■■ ■ ■■ ■ ■ ■= 7000 NM ■■ _ -- 1 ■ ■ ■ ■■ _ I i , I ME 11111111111.1.11 Stuck i 1fole ■_ ■■ @84.1'MD III 1 8000 — 5767.7 TVD IlS it 1.1 _ Pump MIME Drill 8 3/4 Hole II ■ Ceme •t & t— + +to 9808' MD / rQ' T"b iid" F-le I I 9000 ■■ 1 — 8072 T\'D - -- — `to I Ups' -- M■ Drill 8 3/4" Ho - ■■ to • 30' MD ■ 1 N 111 ■ 61 1.9 TV ■ Attempt to stem ■■■ 11111111 to uses with — 10000 ■ ■■ �� 111111 �� — — — Fprrri A lug Er= 1 ■■ Lost Cle:_ •ut BHA 1 leanout BHA a . Casing Shoe Set Drill 6-1/8" hole ■■ and 2 Jt • of 4" DP • ishing Tool Stull( at • , @ 9: 93' MD tc 12055' Downho e 976' MD. Sever "ire.__ 11000 -. •• "� III -- - - - ' - RIM POOH, Mud Losses attemfiti sidetrack — ■ ■_ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■■ ■■ ! 11111111111111111111111111.1111111 — from 100-300 bbl: /hr & se'.t up or production _ : EMI ■ ■ ■ ■ ■ ■ ■ ■■ ■ ■I1 ` 12000 ' 1111111.111111.1.111 �_ , I 0 10 20 30 40 50 60 70 80 Rig Days 1 s P1 1 E E CD DATA EOWR ASCII DATA EMF and PDF LOGS HALLIBURTON Sperry Drilling Services
